Cover Page
Cover Page - shares | 6 Months Ended | |
Jun. 30, 2024 | Jul. 26, 2024 | |
Entity Information [Line Items] | ||
Document Type | 10-Q | |
Document Quarterly Report | true | |
Document Period End Date | Jun. 30, 2024 | |
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 | 90,200,384 | |
Entity Central Index Key | 0001108426 | |
Document Fiscal Year Focus | 2024 | |
Current Fiscal Year End Date | --12-31 | |
Document Fiscal Period Focus | Q2 | |
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 | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Electric Operating Revenues | $ 488,102 | $ 477,156 | $ 924,979 | $ 1,021,233 |
Operating Expenses: | ||||
Administrative and general | 59,581 | 54,039 | 115,008 | 109,149 |
Regulatory disallowances | 0 | 3,731 | 4,459 | 3,731 |
Depreciation and amortization | 94,413 | 79,139 | 187,600 | 157,213 |
Transmission and distribution costs | 25,051 | 25,465 | 47,815 | 47,661 |
Taxes other than income taxes | 24,084 | 24,401 | 50,018 | 49,963 |
Total operating expenses | 382,419 | 384,826 | 738,706 | 829,812 |
Operating income (loss) | 105,683 | 92,330 | 186,273 | 191,421 |
Other Income and Deductions: | ||||
Interest income | 4,470 | 5,359 | 9,050 | 10,202 |
Gains on investment securities | 558 | 3,777 | 18,556 | 10,219 |
Other income | 7,688 | 5,600 | 12,599 | 8,693 |
Other (deductions) | (1,636) | (3,515) | (18,158) | (6,008) |
Net other income and deductions | 11,080 | 11,221 | 22,047 | 23,106 |
Interest Charges | 55,828 | 45,899 | 109,590 | 86,822 |
Earnings before Income Taxes | 60,935 | 57,652 | 98,730 | 127,705 |
Income Taxes (Benefits) | 8,971 | 8,229 | (3,600) | 18,009 |
Net Earnings | 51,964 | 49,423 | 102,330 | 109,696 |
(Earnings) Attributable to Valencia Non-controlling Interest | (3,783) | (3,987) | (6,827) | (9,114) |
Preferred Stock Dividend Requirements of Subsidiary | (132) | (132) | (264) | (264) |
Net Earnings Available for PNM Common Stock | $ 48,049 | $ 45,304 | $ 95,239 | $ 100,318 |
Net Earnings Attributable to PNMR per Common Share: | ||||
Basic (in dollars per share) | $ 0.53 | $ 0.53 | $ 1.05 | $ 1.17 |
Diluted (in dollars per share) | 0.53 | 0.53 | 1.05 | 1.16 |
Dividends Declared per Common Share (in dollars per share) | $ 0.3875 | $ 0.3675 | $ 0.7750 | $ 0.7350 |
Energy | ||||
Electric Operating Revenues | $ 488,102 | $ 477,156 | $ 924,979 | $ 1,021,233 |
Operating Expenses: | ||||
Energy costs | 154,706 | 172,452 | 287,010 | 414,138 |
Energy Production | ||||
Operating Expenses: | ||||
Energy costs | $ 24,584 | $ 25,599 | $ 46,796 | $ 47,957 |
Condensed Consolidated Statem_2
Condensed Consolidated Statements of Comprehensive Income - PNMR - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Statement of Comprehensive Income [Abstract] | ||||
Net Earnings | $ 51,964 | $ 49,423 | $ 102,330 | $ 109,696 |
Unrealized Gains on Available-for-Sale Debt Securities: | ||||
Net increase in unrealized holding gains arising during the period, net of income tax (expense) benefit of $274, $(99), $149, and $(1,158) | (804) | 291 | (438) | 3,402 |
Reclassification adjustment for (gains) included in net earnings, net of income tax expense of $421, $477, $3,192, and $655 | (1,235) | (1,401) | (9,374) | (1,925) |
Pension Liability Adjustment: | ||||
Reclassification adjustment for amortization of experience losses recognized as net periodic benefit cost, net of income tax (benefit) of $(309), $(303), $(618), and $(606) | 908 | 891 | 1,815 | 1,782 |
Fair Value Adjustment for Cash Flow Hedges: | ||||
Change in fair market value, net of income tax (expense) of $1,111, $(949), $1,094, and $(906) | (3,263) | 2,786 | (3,213) | 2,661 |
Reclassification adjustment for gains (losses) included in net earnings, net of income tax (expense) benefit of $(716), $(869), $(1,413), and $(304) | 2,102 | 2,552 | 4,150 | 893 |
Total Other Comprehensive Income (Loss) | (2,292) | 5,119 | (7,060) | 6,813 |
Comprehensive Income | 49,672 | 54,542 | 95,270 | 116,509 |
Comprehensive (Income) Attributable to Valencia Non-controlling Interest | (3,783) | (3,987) | (6,827) | (9,114) |
Preferred Stock Dividend Requirements of Subsidiary | (132) | (132) | (264) | (264) |
Comprehensive Income Attributable to PNM | $ 45,757 | $ 50,423 | $ 88,179 | $ 107,131 |
Condensed Consolidated Statem_3
Condensed Consolidated Statements of Comprehensive Income - PNMR (Parenthetical) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Statement of Comprehensive Income [Abstract] | ||||
Unrealized holding gains (losses) arising during the period, income tax (expense) benefit | $ 274 | $ (99) | $ 149 | $ (1,158) |
Reclassification adjustment for (gains) losses included in net earnings, income tax expense (benefit) | 421 | 477 | 3,192 | 655 |
Pension liability adjustment, income tax expense (benefit) | (309) | (303) | (618) | (606) |
Change in fair market value, income tax (expense) benefit | 1,111 | (949) | 1,094 | (906) |
Reclassification adjustment for (gains) losses included in net earnings, income tax expense (benefit) | $ (716) | $ (869) | $ (1,413) | $ (304) |
Condensed Consolidated Statem_4
Condensed Consolidated Statements of Cash Flows - PNMR - USD ($) $ in Thousands | 6 Months Ended | |
Jun. 30, 2024 | Jun. 30, 2023 | |
Cash Flows From Operating Activities: | ||
Net earnings | $ 102,330 | $ 109,696 |
Adjustments to reconcile net earnings to net cash flows from operating activities: | ||
Depreciation and amortization | 206,365 | 173,851 |
Deferred income tax expense | 15,385 | 17,132 |
(Gain) on sale of NMRD | (4,449) | 0 |
(Gains) losses on investment securities | (18,556) | (10,219) |
Stock based compensation expense | 6,676 | 4,343 |
Regulatory disallowances | 4,459 | 3,731 |
Allowance for equity funds used during construction | (8,130) | (5,309) |
Other, net | 2,039 | 742 |
Changes in certain assets and liabilities: | ||
Accounts receivable and unbilled revenues | (10,120) | 56,725 |
Materials, supplies, and fuel stock | (17,110) | (14,283) |
Other current assets | (19,479) | (18,399) |
Other assets | (16,382) | (6,407) |
Accounts payable | (17,502) | (23,569) |
Accrued interest and taxes | (6,935) | (8,000) |
Other current liabilities | (28,350) | (23,360) |
Other liabilities | (20,717) | (14,231) |
Net cash flows from operating activities | 169,524 | 242,443 |
Cash Flows From Investing Activities: | ||
Additions to utility plant and non-utility plant | (581,818) | (537,004) |
Proceeds from sale of plant assets (Note 13) | 2,840 | 28,372 |
Proceeds from sales of investment securities | 412,750 | 274,777 |
Purchases of investment securities | (417,599) | (281,662) |
Proceeds from sale of NMRD | 116,936 | 0 |
Investments in NMRD | (12,550) | (14,750) |
Other, net | (57) | 4 |
Net cash flows used in investing activities | (479,498) | (530,263) |
Cash Flows From Financing Activities: | ||
Revolving credit facilities borrowings | 1,584,300 | 1,265,600 |
Revolving credit facilities repayments | (1,519,800) | (1,171,100) |
Long-term borrowings | 1,065,000 | 960,000 |
Repayment of long-term debt | (737,000) | (685,000) |
Awards of common stock | (6,248) | (9,618) |
Dividends paid | (70,169) | (63,353) |
Valencia’s transactions with its owner | (7,853) | (10,755) |
Transmission interconnection and security deposit arrangements | 64,752 | 29,362 |
Refunds paid under transmission interconnection and security deposit arrangements | (28,702) | (18,004) |
Debt issuance costs and other, net | (17,929) | (5,750) |
Net cash flows from financing activities | 326,351 | 291,382 |
Change in Cash, Cash Equivalents, and Restricted Cash | 16,377 | 3,562 |
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period | 3,943 | 4,078 |
Cash, Cash Equivalents, and Restricted Cash at End of Period | 20,320 | 7,640 |
Restricted Cash Included in Other Current Assets and Other Deferred Assets on Consolidated Balance Sheets: | ||
At beginning of period | 1,728 | 0 |
At end of period | 17,085 | 0 |
Supplemental Cash Flow Disclosures: | ||
Interest paid, net of amounts capitalized | 97,747 | 82,947 |
Income taxes paid (refunded), net | (395) | 1,400 |
Supplemental schedule of noncash investing activities: | ||
Decrease in accrued plant additions | $ 47,369 | $ 44,547 |
Condensed Consolidated Balance
Condensed Consolidated Balance Sheets - PNMR - USD ($) $ in Thousands | Jun. 30, 2024 | Dec. 31, 2023 |
Current Assets: | ||
Cash and cash equivalents | $ 3,235 | $ 2,215 |
Accounts receivable, net of allowance for credit losses of $3,032 and $3,388 | 121,757 | 126,291 |
Unbilled revenues | 76,793 | 64,072 |
Other receivables | 103,721 | 76,509 |
Materials, supplies, and fuel stock | 115,144 | 98,034 |
Regulatory assets | 59,397 | 73,046 |
Prepaid assets | 30,278 | 19,759 |
Income taxes receivable | 5,741 | 6,697 |
Other current assets | 21,588 | 8,920 |
Total current assets | 537,654 | 475,543 |
Other Property and Investments: | ||
Investment securities | 441,230 | 444,408 |
Equity investment in NMRD | 0 | 119,570 |
Other investments | 229 | 171 |
Non-utility property, net | 27,116 | 29,367 |
Total other property and investments | 468,575 | 593,516 |
Utility Plant: | ||
Plant in service, held for future use, and to be abandoned | 10,028,222 | 9,701,180 |
Less accumulated depreciation and amortization | 2,855,197 | 2,755,823 |
Net plant in service and plant held for future use | 7,173,025 | 6,945,357 |
Construction work in progress | 727,130 | 589,834 |
Nuclear fuel, net of accumulated amortization of $31,652 and $35,840 | 74,782 | 74,671 |
Net utility plant | 7,974,937 | 7,609,862 |
Deferred Charges and Other Assets: | ||
Regulatory assets | 929,893 | 914,381 |
Goodwill | 278,297 | 278,297 |
Operating lease right-of-use assets, net of accumulated amortization | 177,285 | 182,201 |
Other deferred charges | 216,769 | 198,805 |
Total deferred charges and other assets | 1,602,244 | 1,573,684 |
Total assets | 10,583,410 | 10,252,605 |
Current Liabilities: | ||
Short-term debt | 326,400 | 261,900 |
Current installments of long-term debt (includes $5,935 and $2,529 related to ETBC I) | 240,770 | 280,169 |
Accounts payable | 140,304 | 205,175 |
Customer deposits | 6,454 | 6,237 |
Accrued interest and taxes | 90,763 | 98,655 |
Regulatory liabilities | 76,131 | 140,005 |
Operating lease liabilities | 10,834 | 12,267 |
Dividends declared | 132 | 35,085 |
Transmission interconnection arrangement liabilities | 132,505 | 96,870 |
Other current liabilities | 114,344 | 94,397 |
Total current liabilities | 1,138,637 | 1,230,760 |
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs (includes $335,172 and $338,521 related to ETBC I) | 4,596,994 | 4,241,642 |
Deferred Credits and Other Liabilities: | ||
Accumulated deferred income taxes | 854,174 | 845,280 |
Regulatory liabilities | 776,424 | 771,317 |
Asset retirement obligations | 247,653 | 245,531 |
Accrued pension liability and postretirement benefit cost | 16,168 | 21,429 |
Operating lease liabilities | 159,592 | 167,000 |
Other deferred credits | 330,559 | 319,066 |
Total deferred credits and other liabilities | 2,384,570 | 2,369,623 |
Total liabilities | 8,120,201 | 7,842,025 |
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 |
PNMR common stockholders’ equity: | ||
Common stock (no par value; 120,000,000 shares authorized; issued and outstanding 90,200,384 shares) | 1,625,251 | 1,624,823 |
Accumulated other comprehensive income (loss), net of income taxes | (69,900) | (62,840) |
Retained earnings | 847,397 | 787,110 |
Total PNM common stockholder’s equity | 2,402,748 | 2,349,093 |
Non-controlling interest in Valencia | 48,932 | 49,958 |
Total equity | 2,451,680 | 2,399,051 |
Total liabilities and stockholders' equity | $ 10,583,410 | $ 10,252,605 |
Condensed Consolidated Balanc_2
Condensed Consolidated Balance Sheets - PNMR (Parenthetical) - USD ($) $ in Thousands | Jun. 30, 2024 | Dec. 31, 2023 |
Allowance for uncollectible accounts | $ 3,032 | $ 3,388 |
Accumulated depreciation, nuclear fuel | 31,652 | 35,840 |
Current installments of long-term debt (includes $5,935 and $2,529 related to ETBC I) | 240,770 | 280,169 |
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs (includes $335,172 and $338,521 related to ETBC I) | $ 4,596,994 | $ 4,241,642 |
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) | 90,200,384 | 90,200,384 |
Common stock, shares outstanding (in shares) | 90,200,384 | 90,200,384 |
ETBC 1 | ||
Current installments of long-term debt (includes $5,935 and $2,529 related to ETBC I) | $ 5,935 | $ 2,529 |
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs (includes $335,172 and $338,521 related to ETBC I) | $ 335,172 | $ 338,521 |
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, 2022 | $ 2,244,926 | $ 2,191,932 | $ 1,429,102 | $ (66,048) | $ 828,878 | $ 52,994 |
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||
Net earnings before subsidiary preferred stock dividends | 109,696 | 100,582 | 100,582 | 9,114 | ||
Total other comprehensive income (loss) | 6,813 | 6,813 | 6,813 | |||
Subsidiary preferred stock dividends | (264) | (264) | (264) | |||
Dividends declared on common stock | (31,545) | (31,545) | (31,545) | |||
Awards of common stock | (9,618) | (9,618) | (9,618) | |||
Stock based compensation expense | 4,343 | 4,343 | 4,343 | |||
Valencia’s transactions with its owner | (10,755) | (10,755) | ||||
Ending balance at Jun. 30, 2023 | 2,313,596 | 2,262,243 | 1,423,827 | (59,235) | 897,651 | 51,353 |
Beginning balance at Mar. 31, 2023 | 2,264,802 | 2,212,191 | 1,424,198 | (64,354) | 852,347 | 52,611 |
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||
Net earnings before subsidiary preferred stock dividends | 49,423 | 45,436 | 45,436 | 3,987 | ||
Total other comprehensive income (loss) | 5,119 | 5,119 | 5,119 | |||
Subsidiary preferred stock dividends | (132) | (132) | (132) | |||
Awards of common stock | (1,224) | (1,224) | (1,224) | |||
Stock based compensation expense | 853 | 853 | 853 | |||
Valencia’s transactions with its owner | (5,245) | (5,245) | ||||
Ending balance at Jun. 30, 2023 | 2,313,596 | 2,262,243 | 1,423,827 | (59,235) | 897,651 | 51,353 |
Beginning balance at Dec. 31, 2023 | 2,399,051 | 2,349,093 | 1,624,823 | (62,840) | 787,110 | 49,958 |
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||
Net earnings before subsidiary preferred stock dividends | 102,330 | 95,503 | 95,503 | 6,827 | ||
Total other comprehensive income (loss) | (7,060) | (7,060) | (7,060) | |||
Subsidiary preferred stock dividends | (264) | (264) | (264) | |||
Dividends declared on common stock | (34,952) | (34,952) | (34,952) | |||
Awards of common stock | (6,248) | (6,248) | (6,248) | |||
Stock based compensation expense | 6,676 | 6,676 | 6,676 | |||
Valencia’s transactions with its owner | (7,853) | (7,853) | ||||
Ending balance at Jun. 30, 2024 | 2,451,680 | 2,402,748 | 1,625,251 | (69,900) | 847,397 | 48,932 |
Beginning balance at Mar. 31, 2024 | 2,404,730 | 2,355,731 | 1,623,991 | (67,608) | 799,348 | 48,999 |
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||
Net earnings before subsidiary preferred stock dividends | 51,964 | 48,181 | 48,181 | 3,783 | ||
Total other comprehensive income (loss) | (2,292) | (2,292) | (2,292) | |||
Subsidiary preferred stock dividends | (132) | (132) | (132) | |||
Awards of common stock | (808) | (808) | (808) | |||
Stock based compensation expense | 2,068 | 2,068 | 2,068 | |||
Valencia’s transactions with its owner | (3,850) | (3,850) | ||||
Ending balance at Jun. 30, 2024 | $ 2,451,680 | $ 2,402,748 | $ 1,625,251 | $ (69,900) | $ 847,397 | $ 48,932 |
Condensed Consolidated Statem_6
Condensed Consolidated Statements of Earnings - PNM - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Electric Operating Revenues | $ 488,102 | $ 477,156 | $ 924,979 | $ 1,021,233 |
Operating Expenses: | ||||
Administrative and general | 59,581 | 54,039 | 115,008 | 109,149 |
Regulatory disallowances | 0 | 3,731 | 4,459 | 3,731 |
Depreciation and amortization | 94,413 | 79,139 | 187,600 | 157,213 |
Transmission and distribution costs | 25,051 | 25,465 | 47,815 | 47,661 |
Taxes other than income taxes | 24,084 | 24,401 | 50,018 | 49,963 |
Total operating expenses | 382,419 | 384,826 | 738,706 | 829,812 |
Operating income (loss) | 105,683 | 92,330 | 186,273 | 191,421 |
Other Income and Deductions: | ||||
Interest income | 4,470 | 5,359 | 9,050 | 10,202 |
Gains on investment securities | 558 | 3,777 | 18,556 | 10,219 |
Other income | 7,688 | 5,600 | 12,599 | 8,693 |
Other (deductions) | (1,636) | (3,515) | (18,158) | (6,008) |
Net other income and deductions | 11,080 | 11,221 | 22,047 | 23,106 |
Interest Charges | 55,828 | 45,899 | 109,590 | 86,822 |
Earnings before Income Taxes | 60,935 | 57,652 | 98,730 | 127,705 |
Income Taxes | 8,971 | 8,229 | (3,600) | 18,009 |
Net Earnings | 51,964 | 49,423 | 102,330 | 109,696 |
(Earnings) Attributable to Valencia Non-controlling Interest | (3,783) | (3,987) | (6,827) | (9,114) |
Preferred Stock Dividend Requirements | (132) | (132) | (264) | (264) |
Net Earnings Available for PNM Common Stock | 48,049 | 45,304 | 95,239 | 100,318 |
Energy | ||||
Electric Operating Revenues | 488,102 | 477,156 | 924,979 | 1,021,233 |
Operating Expenses: | ||||
Energy costs | 154,706 | 172,452 | 287,010 | 414,138 |
Energy Production | ||||
Operating Expenses: | ||||
Energy costs | 24,584 | 25,599 | 46,796 | 47,957 |
PNM | ||||
Electric Operating Revenues | 333,671 | 338,242 | 641,786 | 768,407 |
Operating Expenses: | ||||
Administrative and general | 54,876 | 48,745 | 106,612 | 97,718 |
Regulatory disallowances | 0 | 3,731 | 4,459 | 3,731 |
Depreciation and amortization | 54,230 | 44,064 | 107,517 | 87,750 |
Transmission and distribution costs | 15,350 | 14,755 | 29,700 | 28,642 |
Taxes other than income taxes | 11,768 | 13,324 | 25,477 | 26,828 |
Total operating expenses | 275,580 | 283,827 | 532,745 | 636,088 |
Operating income (loss) | 58,091 | 54,415 | 109,041 | 132,319 |
Other Income and Deductions: | ||||
Interest income | 4,443 | 5,370 | 8,970 | 10,219 |
Gains on investment securities | 558 | 3,777 | 18,556 | 10,219 |
Other income | 4,224 | 2,721 | 7,642 | 5,172 |
Other (deductions) | (913) | (2,803) | (1,783) | (4,663) |
Net other income and deductions | 8,312 | 9,065 | 33,385 | 20,947 |
Interest Charges | 25,880 | 20,766 | 50,996 | 38,888 |
Earnings before Income Taxes | 40,523 | 42,714 | 91,430 | 114,378 |
Income Taxes | 5,821 | 7,411 | 11,632 | 19,240 |
Net Earnings | 34,702 | 35,303 | 79,798 | 95,138 |
(Earnings) Attributable to Valencia Non-controlling Interest | (3,783) | (3,987) | (6,827) | (9,114) |
Net Earnings Attributable to PNM | 30,919 | 31,316 | 72,971 | 86,024 |
Preferred Stock Dividend Requirements | (132) | (132) | (264) | (264) |
Net Earnings Available for PNM Common Stock | 30,787 | 31,184 | 72,707 | 85,760 |
PNM | Energy | ||||
Operating Expenses: | ||||
Energy costs | 114,772 | 133,609 | 212,184 | 343,462 |
PNM | Energy Production | ||||
Operating Expenses: | ||||
Energy costs | $ 24,584 | $ 25,599 | $ 46,796 | $ 47,957 |
Condensed Consolidated Statem_7
Condensed Consolidated Statements of Comprehensive Income - PNM - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Net Earnings | $ 51,964 | $ 49,423 | $ 102,330 | $ 109,696 |
Unrealized Gains on Available-for-Sale Debt Securities: | ||||
Net increase in unrealized holding gains arising during the period, net of income tax (expense) benefit of $274, $(99), $149, and $(1,158) | (804) | 291 | (438) | 3,402 |
Reclassification adjustment for (gains) included in net earnings, net of income tax expense of $421, $477, $3,192, and $655 | (1,235) | (1,401) | (9,374) | (1,925) |
Pension Liability Adjustment: | ||||
Reclassification adjustment for amortization of experience losses recognized as net periodic benefit cost, net of income tax (benefit) of $(309), $(303), $(618), and $(606) | 908 | 891 | 1,815 | 1,782 |
Total Other Comprehensive Income (Loss) | (2,292) | 5,119 | (7,060) | 6,813 |
Comprehensive Income | 49,672 | 54,542 | 95,270 | 116,509 |
Comprehensive (Income) Attributable to Valencia Non-controlling Interest | (3,783) | (3,987) | (6,827) | (9,114) |
Comprehensive Income Attributable to PNM | 45,757 | 50,423 | 88,179 | 107,131 |
PNM | ||||
Net Earnings | 34,702 | 35,303 | 79,798 | 95,138 |
Unrealized Gains on Available-for-Sale Debt Securities: | ||||
Net increase in unrealized holding gains arising during the period, net of income tax (expense) benefit of $274, $(99), $149, and $(1,158) | (804) | 291 | (438) | 3,402 |
Reclassification adjustment for (gains) included in net earnings, net of income tax expense of $421, $477, $3,192, and $655 | (1,235) | (1,401) | (9,374) | (1,925) |
Pension Liability Adjustment: | ||||
Reclassification adjustment for amortization of experience losses recognized as net periodic benefit cost, net of income tax (benefit) of $(309), $(303), $(618), and $(606) | 908 | 891 | 1,815 | 1,782 |
Total Other Comprehensive Income (Loss) | (1,131) | (219) | (7,997) | 3,259 |
Comprehensive Income | 33,571 | 35,084 | 71,801 | 98,397 |
Comprehensive (Income) Attributable to Valencia Non-controlling Interest | (3,783) | (3,987) | (6,827) | (9,114) |
Comprehensive Income Attributable to PNM | $ 29,788 | $ 31,097 | $ 64,974 | $ 89,283 |
Condensed Consolidated Statem_8
Condensed Consolidated Statements of Comprehensive Income - PNM (Parenthetical) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Unrealized holding gains (losses) arising during the period, income tax (expense) benefit | $ 274 | $ (99) | $ 149 | $ (1,158) |
Reclassification adjustment for (gains) losses included in net earnings, income tax expense (benefit) | 421 | 477 | 3,192 | 655 |
Pension liability adjustment, income tax expense (benefit) | (309) | (303) | (618) | (606) |
PNM | ||||
Unrealized holding gains (losses) arising during the period, income tax (expense) benefit | 274 | (99) | 149 | (1,158) |
Reclassification adjustment for (gains) losses included in net earnings, income tax expense (benefit) | 421 | 477 | 3,192 | 655 |
Pension liability adjustment, income tax expense (benefit) | $ (309) | $ (303) | $ (618) | $ (606) |
Condensed Consolidated Statem_9
Condensed Consolidated Statements of Cash Flows - PNM - USD ($) $ in Thousands | 6 Months Ended | |
Jun. 30, 2024 | Jun. 30, 2023 | |
Cash Flows From Operating Activities: | ||
Net earnings | $ 102,330 | $ 109,696 |
Adjustments to reconcile net earnings to net cash flows from operating activities: | ||
Depreciation and amortization | 206,365 | 173,851 |
Deferred income tax expense | 15,385 | 17,132 |
(Gains) losses on investment securities | (18,556) | (10,219) |
Regulatory disallowances | 4,459 | 3,731 |
Allowance for equity funds used during construction | (8,130) | (5,309) |
Other, net | 2,039 | 742 |
Changes in certain assets and liabilities: | ||
Accounts receivable and unbilled revenues | (10,120) | 56,725 |
Materials, supplies, and fuel stock | (17,110) | (14,283) |
Other current assets | (19,479) | (18,399) |
Other assets | (16,382) | (6,407) |
Accounts payable | (17,502) | (23,569) |
Accrued interest and taxes | (6,935) | (8,000) |
Other current liabilities | (28,350) | (23,360) |
Other liabilities | (20,717) | (14,231) |
Net cash flows from operating activities | 169,524 | 242,443 |
Cash Flows From Investing Activities: | ||
Utility plant additions | (581,818) | (537,004) |
Proceeds from sale of plant assets (Note 13) | 2,840 | 28,372 |
Proceeds from sales of investment securities | 412,750 | 274,777 |
Purchases of investment securities | (417,599) | (281,662) |
Other, net | (57) | 4 |
Net cash flows used in investing activities | (479,498) | (530,263) |
Cash Flows From Financing Activities: | ||
Revolving credit facilities borrowings | 1,584,300 | 1,265,600 |
Revolving credit facilities repayments | (1,519,800) | (1,171,100) |
Long-term borrowings | 1,065,000 | 960,000 |
Repayment of long-term debt | (737,000) | (685,000) |
Dividends paid | (70,169) | (63,353) |
Valencia’s transactions with its owner | (7,853) | (10,755) |
Transmission interconnection and security deposit arrangements | 64,752 | 29,362 |
Refunds paid under transmission interconnection and security deposit arrangements | (28,702) | (18,004) |
Debt issuance costs and other, net | (17,929) | (5,750) |
Net cash flows from financing activities | 326,351 | 291,382 |
Change in Cash, Cash Equivalents, and Restricted Cash | 16,377 | 3,562 |
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period | 3,943 | 4,078 |
Cash, Cash Equivalents, and Restricted Cash at End of Period | 20,320 | 7,640 |
Restricted Cash Included in Other Current Assets and Other Deferred Assets on Consolidated Balance Sheets: | ||
At beginning of period | 1,728 | 0 |
At end of period | 17,085 | 0 |
Supplemental Cash Flow Disclosures: | ||
Interest paid, net of amounts capitalized | 97,747 | 82,947 |
Income taxes paid (refunded), net | (395) | 1,400 |
Supplemental schedule of noncash investing activities: | ||
Decrease in accrued plant additions | 47,369 | 44,547 |
PNM | ||
Cash Flows From Operating Activities: | ||
Net earnings | 79,798 | 95,138 |
Adjustments to reconcile net earnings to net cash flows from operating activities: | ||
Depreciation and amortization | 120,385 | 100,225 |
Deferred income tax expense | 12,049 | 19,240 |
(Gains) losses on investment securities | (18,556) | (10,219) |
Regulatory disallowances | 4,459 | 3,731 |
Allowance for equity funds used during construction | (6,476) | (4,299) |
Other, net | 1,935 | 1,800 |
Changes in certain assets and liabilities: | ||
Accounts receivable and unbilled revenues | (2,654) | 54,666 |
Materials, supplies, and fuel stock | (10,671) | (11,334) |
Other current assets | (28,462) | (21,778) |
Other assets | (3,324) | (2,961) |
Accounts payable | (12,753) | (20,197) |
Accrued interest and taxes | 10,619 | 762 |
Other current liabilities | (6,113) | (7,199) |
Other liabilities | (22,576) | (11,643) |
Net cash flows from operating activities | 117,660 | 185,932 |
Cash Flows From Investing Activities: | ||
Utility plant additions | (311,475) | (284,037) |
Proceeds from sale of plant assets (Note 13) | 2,840 | 28,372 |
Proceeds from sales of investment securities | 412,750 | 274,777 |
Purchases of investment securities | (417,599) | (281,662) |
Other, net | (57) | 3 |
Net cash flows used in investing activities | (313,541) | (262,547) |
Cash Flows From Financing Activities: | ||
Revolving credit facilities borrowings | 737,900 | 599,300 |
Revolving credit facilities repayments | (804,800) | (653,600) |
Long-term borrowings | 398,000 | 330,000 |
Repayment of long-term debt | (198,000) | (185,000) |
Equity contribution from parent | 55,000 | 0 |
Dividends paid | (264) | (264) |
Valencia’s transactions with its owner | (7,853) | (10,755) |
Transmission interconnection and security deposit arrangements | 58,002 | 18,362 |
Refunds paid under transmission interconnection and security deposit arrangements | (23,852) | (14,504) |
Debt issuance costs and other, net | (3,734) | (3,333) |
Net cash flows from financing activities | 210,399 | 80,206 |
Change in Cash, Cash Equivalents, and Restricted Cash | 14,518 | 3,591 |
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period | 2,586 | 2,985 |
Cash, Cash Equivalents, and Restricted Cash at End of Period | 17,104 | 6,576 |
Restricted Cash Included in Other Current Assets and Other Deferred Assets on Consolidated Balance Sheets: | ||
At beginning of period | 1,728 | 0 |
Supplemental Cash Flow Disclosures: | ||
Interest paid, net of amounts capitalized | 32,905 | 34,293 |
Income taxes paid (refunded), net | (1,707) | 0 |
Supplemental schedule of noncash investing activities: | ||
Decrease in accrued plant additions | $ 26,848 | $ 26,570 |
Condensed Consolidated Balanc_3
Condensed Consolidated Balance Sheets - PNM - USD ($) $ in Thousands | Jun. 30, 2024 | Dec. 31, 2023 |
Current Assets: | ||
Cash and cash equivalents | $ 3,235 | $ 2,215 |
Accounts receivable, net of allowance for credit losses of $3,032 and $3,388 | 121,757 | 126,291 |
Unbilled revenues | 76,793 | 64,072 |
Other receivables | 103,721 | 76,509 |
Materials, supplies, and fuel stock | 115,144 | 98,034 |
Regulatory assets | 59,397 | 73,046 |
Prepaid assets | 30,278 | 19,759 |
Income taxes receivable | 5,741 | 6,697 |
Other current assets | 21,588 | 8,920 |
Total current assets | 537,654 | 475,543 |
Other Property and Investments: | ||
Investment securities | 441,230 | 444,408 |
Other investments | 229 | 171 |
Non-utility property, net | 27,116 | 29,367 |
Total other property and investments | 468,575 | 593,516 |
Utility Plant: | ||
Plant in service, held for future use, and to be abandoned | 10,028,222 | 9,701,180 |
Less accumulated depreciation and amortization | 2,855,197 | 2,755,823 |
Net plant in service and plant held for future use | 7,173,025 | 6,945,357 |
Construction work in progress | 727,130 | 589,834 |
Nuclear fuel, net of accumulated amortization of $31,652 and $35,840 | 74,782 | 74,671 |
Net utility plant | 7,974,937 | 7,609,862 |
Deferred Charges and Other Assets: | ||
Regulatory assets | 929,893 | 914,381 |
Goodwill | 278,297 | 278,297 |
Operating lease right-of-use assets, net of accumulated amortization | 177,285 | 182,201 |
Other deferred charges | 216,769 | 198,805 |
Total deferred charges and other assets | 1,602,244 | 1,573,684 |
Total assets | 10,583,410 | 10,252,605 |
Current Liabilities: | ||
Short-term debt | 326,400 | 261,900 |
Current installments of long-term debt (includes $5,935 and $2,529 related to ETBC I) | 240,770 | 280,169 |
Accounts payable | 140,304 | 205,175 |
Customer deposits | 6,454 | 6,237 |
Accrued interest and taxes | 90,763 | 98,655 |
Regulatory liabilities | 76,131 | 140,005 |
Operating lease liabilities | 10,834 | 12,267 |
Dividends declared | 132 | 35,085 |
Transmission interconnection arrangement liabilities | 132,505 | 96,870 |
Other current liabilities | 114,344 | 94,397 |
Total current liabilities | 1,138,637 | 1,230,760 |
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs (includes $335,172 and $338,521 related to ETBC I) | 4,596,994 | 4,241,642 |
Deferred Credits and Other Liabilities: | ||
Accumulated deferred income taxes | 854,174 | 845,280 |
Regulatory liabilities | 776,424 | 771,317 |
Asset retirement obligations | 247,653 | 245,531 |
Accrued pension liability and postretirement benefit cost | 16,168 | 21,429 |
Operating lease liabilities | 159,592 | 167,000 |
Other deferred credits | 330,559 | 319,066 |
Total deferred credits and other liabilities | 2,384,570 | 2,369,623 |
Total liabilities | 8,120,201 | 7,842,025 |
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) | 1,625,251 | 1,624,823 |
Accumulated other comprehensive income (loss), net of income taxes | (69,900) | (62,840) |
Retained earnings | 847,397 | 787,110 |
Total PNM common stockholder’s equity | 2,402,748 | 2,349,093 |
Non-controlling interest in Valencia | 48,932 | 49,958 |
Total equity | 2,451,680 | 2,399,051 |
Total liabilities and stockholders' equity | 10,583,410 | 10,252,605 |
PNM | ||
Current Assets: | ||
Cash and cash equivalents | 19 | 858 |
Accounts receivable, net of allowance for credit losses of $3,032 and $3,388 | 82,403 | 94,879 |
Unbilled revenues | 60,123 | 46,925 |
Materials, supplies, and fuel stock | 92,243 | 81,572 |
Regulatory assets | 49,791 | 72,996 |
Prepaid assets | 19,415 | 9,941 |
Income taxes receivable | 6,391 | 7,682 |
Other current assets | 16,404 | 1,756 |
Total current assets | 436,272 | 377,837 |
Other Property and Investments: | ||
Investment securities | 441,230 | 444,408 |
Other investments | 127 | 69 |
Non-utility property, net | 11,831 | 13,538 |
Total other property and investments | 453,188 | 458,015 |
Utility Plant: | ||
Plant in service, held for future use, and to be abandoned | 6,364,995 | 6,151,510 |
Less accumulated depreciation and amortization | 2,038,251 | 1,976,657 |
Net plant in service and plant held for future use | 4,326,744 | 4,174,853 |
Construction work in progress | 509,898 | 490,178 |
Nuclear fuel, net of accumulated amortization of $31,652 and $35,840 | 74,782 | 74,671 |
Net utility plant | 4,911,424 | 4,739,702 |
Deferred Charges and Other Assets: | ||
Regulatory assets | 852,057 | 838,727 |
Goodwill | 51,632 | 51,632 |
Operating lease right-of-use assets, net of accumulated amortization | 175,363 | 180,370 |
Other deferred charges | 180,215 | 166,782 |
Total deferred charges and other assets | 1,259,267 | 1,237,511 |
Total assets | 7,060,151 | 6,813,065 |
Current Liabilities: | ||
Short-term debt | 70,600 | 137,500 |
Current installments of long-term debt (includes $5,935 and $2,529 related to ETBC I) | 109,844 | 200,222 |
Customer deposits | 6,454 | 6,237 |
Accrued interest and taxes | 50,666 | 41,337 |
Regulatory liabilities | 75,443 | 134,846 |
Operating lease liabilities | 9,963 | 11,371 |
Dividends declared | 132 | 132 |
Transmission interconnection arrangement liabilities | 132,505 | 96,870 |
Other current liabilities | 88,015 | 52,587 |
Total current liabilities | 668,281 | 839,194 |
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs (includes $335,172 and $338,521 related to ETBC I) | 2,351,460 | 2,061,558 |
Deferred Credits and Other Liabilities: | ||
Accumulated deferred income taxes | 707,479 | 684,037 |
Regulatory liabilities | 554,517 | 565,021 |
Asset retirement obligations | 246,717 | 244,633 |
Accrued pension liability and postretirement benefit cost | 14,965 | 19,949 |
Operating lease liabilities | 158,609 | 166,191 |
Other deferred credits | 227,135 | 220,178 |
Total deferred credits and other liabilities | 1,909,422 | 1,900,009 |
Total liabilities | 4,929,163 | 4,800,761 |
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) | 1,602,918 | 1,547,918 |
Accumulated other comprehensive income (loss), net of income taxes | (74,502) | (66,505) |
Retained earnings | 542,111 | 469,404 |
Total PNM common stockholder’s equity | 2,070,527 | 1,950,817 |
Non-controlling interest in Valencia | 48,932 | 49,958 |
Total equity | 2,119,459 | 2,000,775 |
Total liabilities and stockholders' equity | 7,060,151 | 6,813,065 |
PNM | Nonrelated Party | ||
Current Assets: | ||
Other receivables | 98,441 | 51,975 |
Current Liabilities: | ||
Accounts payable | 102,102 | 141,704 |
PNM | Related Party | ||
Current Assets: | ||
Other receivables | 11,042 | 9,253 |
Current Liabilities: | ||
Accounts payable | $ 22,557 | $ 16,388 |
Condensed Consolidated Balanc_4
Condensed Consolidated Balance Sheets - PNM (Parenthetical) - USD ($) $ in Thousands | Jun. 30, 2024 | Dec. 31, 2023 |
Allowance for uncollectible accounts | $ 3,032 | $ 3,388 |
Accumulated depreciation, nuclear fuel | 31,652 | 35,840 |
Current installments of long-term debt (includes $5,935 and $2,529 related to ETBC I) | 240,770 | 280,169 |
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs (includes $335,172 and $338,521 related to ETBC I) | $ 4,596,994 | $ 4,241,642 |
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) | 90,200,384 | 90,200,384 |
Common stock, shares outstanding (in shares) | 90,200,384 | 90,200,384 |
ETBC 1 | ||
Current installments of long-term debt (includes $5,935 and $2,529 related to ETBC I) | $ 5,935 | $ 2,529 |
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs (includes $335,172 and $338,521 related to ETBC I) | 335,172 | 338,521 |
PNM | ||
Allowance for uncollectible accounts | 3,032 | 3,388 |
Accumulated depreciation, nuclear fuel | 31,652 | 35,840 |
Current installments of long-term debt (includes $5,935 and $2,529 related to ETBC I) | 109,844 | 200,222 |
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs (includes $335,172 and $338,521 related to ETBC I) | $ 2,351,460 | $ 2,061,558 |
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) | 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 |
PNM | ETBC 1 | ||
Current installments of long-term debt (includes $5,935 and $2,529 related to ETBC I) | $ 5,935 | $ 2,529 |
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs (includes $335,172 and $338,521 related to ETBC I) | $ 335,172 | $ 338,521 |
Condensed Consolidated State_10
Condensed Consolidated Statements of Changes in Equity - PNM - USD ($) $ in Thousands | Total | Total PNM Common Stockholder’s Equity | Common Stock | AOCI | Retained Earnings | Non- controlling Interest in Valencia | PNM | PNM Total PNM Common Stockholder’s Equity | PNM Common Stock | PNM AOCI | PNM Retained Earnings | PNM Non- controlling Interest in Valencia |
Beginning balance at Dec. 31, 2022 | $ 2,244,926 | $ 2,191,932 | $ 1,429,102 | $ (66,048) | $ 828,878 | $ 52,994 | $ 1,960,324 | $ 1,907,330 | $ 1,547,918 | $ (74,335) | $ 433,747 | $ 52,994 |
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||
Net earnings | 109,696 | 100,582 | 100,582 | 9,114 | 95,138 | 86,024 | 86,024 | 9,114 | ||||
Total other comprehensive income (loss) | 6,813 | 6,813 | 6,813 | 3,259 | 3,259 | 3,259 | ||||||
Dividends declared on preferred stock | (264) | (264) | (264) | |||||||||
Valencia’s transactions with its owner | (10,755) | (10,755) | (10,755) | (10,755) | ||||||||
Ending balance at Jun. 30, 2023 | 2,313,596 | 2,262,243 | 1,423,827 | (59,235) | 897,651 | 51,353 | 2,047,702 | 1,996,349 | 1,547,918 | (71,076) | 519,507 | 51,353 |
Beginning balance at Mar. 31, 2023 | 2,264,802 | 2,212,191 | 1,424,198 | (64,354) | 852,347 | 52,611 | 2,017,995 | 1,965,384 | 1,547,918 | (70,857) | 488,323 | 52,611 |
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||
Net earnings | 49,423 | 45,436 | 45,436 | 3,987 | 35,303 | 31,316 | 31,316 | 3,987 | ||||
Total other comprehensive income (loss) | 5,119 | 5,119 | 5,119 | (219) | (219) | (219) | ||||||
Dividends declared on preferred stock | (132) | (132) | (132) | |||||||||
Valencia’s transactions with its owner | (5,245) | (5,245) | (5,245) | (5,245) | ||||||||
Ending balance at Jun. 30, 2023 | 2,313,596 | 2,262,243 | 1,423,827 | (59,235) | 897,651 | 51,353 | 2,047,702 | 1,996,349 | 1,547,918 | (71,076) | 519,507 | 51,353 |
Beginning balance at Dec. 31, 2023 | 2,399,051 | 2,349,093 | 1,624,823 | (62,840) | 787,110 | 49,958 | 2,000,775 | 1,950,817 | 1,547,918 | (66,505) | 469,404 | 49,958 |
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||
Net earnings | 102,330 | 95,503 | 95,503 | 6,827 | 79,798 | 72,971 | 72,971 | 6,827 | ||||
Total other comprehensive income (loss) | (7,060) | (7,060) | (7,060) | (7,997) | (7,997) | (7,997) | ||||||
Dividends declared on preferred stock | (264) | (264) | (264) | |||||||||
Equity contribution from parent | 55,000 | 55,000 | 55,000 | |||||||||
Valencia’s transactions with its owner | (7,853) | (7,853) | (7,853) | (7,853) | ||||||||
Ending balance at Jun. 30, 2024 | 2,451,680 | 2,402,748 | 1,625,251 | (69,900) | 847,397 | 48,932 | 2,119,459 | 2,070,527 | 1,602,918 | (74,502) | 542,111 | 48,932 |
Beginning balance at Mar. 31, 2024 | 2,404,730 | 2,355,731 | 1,623,991 | (67,608) | 799,348 | 48,999 | 2,034,870 | 1,985,871 | 1,547,918 | (73,371) | 511,324 | 48,999 |
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||
Net earnings | 51,964 | 48,181 | 48,181 | 3,783 | 34,702 | 30,919 | 30,919 | 3,783 | ||||
Total other comprehensive income (loss) | (2,292) | (2,292) | (2,292) | (1,131) | (1,131) | (1,131) | ||||||
Dividends declared on preferred stock | (132) | (132) | (132) | |||||||||
Equity contribution from parent | 55,000 | 55,000 | 55,000 | |||||||||
Valencia’s transactions with its owner | (3,850) | (3,850) | (3,850) | (3,850) | ||||||||
Ending balance at Jun. 30, 2024 | $ 2,451,680 | $ 2,402,748 | $ 1,625,251 | $ (69,900) | $ 847,397 | $ 48,932 | $ 2,119,459 | $ 2,070,527 | $ 1,602,918 | $ (74,502) | $ 542,111 | $ 48,932 |
Condensed Consolidated State_11
Condensed Consolidated Statements of Earnings - TNMP - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Electric Operating Revenues | $ 488,102 | $ 477,156 | $ 924,979 | $ 1,021,233 |
Operating Expenses: | ||||
Administrative and general | 59,581 | 54,039 | 115,008 | 109,149 |
Depreciation and amortization | 94,413 | 79,139 | 187,600 | 157,213 |
Transmission and distribution costs | 25,051 | 25,465 | 47,815 | 47,661 |
Taxes other than income taxes | 24,084 | 24,401 | 50,018 | 49,963 |
Total operating expenses | 382,419 | 384,826 | 738,706 | 829,812 |
Operating income (loss) | 105,683 | 92,330 | 186,273 | 191,421 |
Other Income and Deductions: | ||||
Interest income | 4,470 | 5,359 | 9,050 | 10,202 |
Other income | 7,688 | 5,600 | 12,599 | 8,693 |
Other (deductions) | (1,636) | (3,515) | (18,158) | (6,008) |
Net other income and deductions | 11,080 | 11,221 | 22,047 | 23,106 |
Interest Charges | 55,828 | 45,899 | 109,590 | 86,822 |
Earnings before Income Taxes | 60,935 | 57,652 | 98,730 | 127,705 |
Income Taxes | 8,971 | 8,229 | (3,600) | 18,009 |
Texas-New Mexico Power Company | ||||
Electric Operating Revenues | 154,431 | 138,914 | 283,193 | 252,826 |
Operating Expenses: | ||||
Cost of energy | 39,934 | 38,843 | 74,826 | 70,676 |
Administrative and general | 13,705 | 13,154 | 27,374 | 27,168 |
Depreciation and amortization | 31,033 | 27,949 | 61,415 | 55,389 |
Transmission and distribution costs | 9,701 | 10,710 | 18,115 | 19,019 |
Taxes other than income taxes | 10,743 | 9,531 | 21,410 | 20,060 |
Total operating expenses | 105,116 | 100,187 | 203,140 | 192,312 |
Operating income (loss) | 49,315 | 38,727 | 80,053 | 60,514 |
Other Income and Deductions: | ||||
Interest income | 127 | 121 | 296 | 235 |
Other income | 2,982 | 1,767 | 4,155 | 2,278 |
Other (deductions) | (277) | (255) | (574) | (630) |
Net other income and deductions | 2,832 | 1,633 | 3,877 | 1,883 |
Interest Charges | 14,451 | 11,412 | 27,787 | 21,837 |
Earnings before Income Taxes | 37,696 | 28,948 | 56,143 | 40,560 |
Income Taxes | 7,771 | 4,316 | 11,635 | 5,895 |
Net Earnings Attributable to PNM | $ 29,925 | $ 24,632 | $ 44,508 | $ 34,665 |
Condensed Consolidated State_12
Condensed Consolidated Statements of Cash Flows - TNMP - USD ($) $ in Thousands | 6 Months Ended | |
Jun. 30, 2024 | Jun. 30, 2023 | |
Cash Flows From Operating Activities: | ||
Net earnings | $ 102,330 | $ 109,696 |
Adjustments to reconcile net earnings to net cash flows from operating activities: | ||
Depreciation and amortization | 206,365 | 173,851 |
Deferred income tax expense | 15,385 | 17,132 |
Allowance for equity funds used during construction and other, net | (8,130) | (5,309) |
Changes in certain assets and liabilities: | ||
Accounts receivable and unbilled revenues | (10,120) | 56,725 |
Materials and supplies | (17,110) | (14,283) |
Other current assets | (19,479) | (18,399) |
Other assets | (16,382) | (6,407) |
Accounts payable | (17,502) | (23,569) |
Accrued interest and taxes | (6,935) | (8,000) |
Other current liabilities | (28,350) | (23,360) |
Other liabilities | (20,717) | (14,231) |
Net cash flows from operating activities | 169,524 | 242,443 |
Cash Flows From Investing Activities: | ||
Utility plant additions | (581,818) | (537,004) |
Net cash flows used in investing activities | (479,498) | (530,263) |
Cash Flows From Financing Activities: | ||
Revolving credit facilities borrowings | 1,584,300 | 1,265,600 |
Revolving credit facilities repayments | (1,519,800) | (1,171,100) |
Long-term borrowings | 1,065,000 | 960,000 |
Transmission interconnection and security deposit arrangements | 64,752 | 29,362 |
Refunds paid under transmission interconnection and security deposit arrangements | (28,702) | (18,004) |
Debt issuance costs and other, net | (17,929) | (5,750) |
Net cash flows from financing activities | 326,351 | 291,382 |
Change in Cash, Cash Equivalents, and Restricted Cash | 16,377 | 3,562 |
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period | 3,943 | 4,078 |
Cash, Cash Equivalents, and Restricted Cash at End of Period | 20,320 | 7,640 |
Supplemental Cash Flow Disclosures: | ||
Interest paid, net of amounts capitalized | 97,747 | 82,947 |
Income taxes paid (refunded), net | (395) | 1,400 |
Supplemental schedule of noncash investing activities: | ||
Decrease in accrued plant additions | 47,369 | 44,547 |
Texas-New Mexico Power Company | ||
Cash Flows From Operating Activities: | ||
Net earnings | 44,508 | 34,665 |
Adjustments to reconcile net earnings to net cash flows from operating activities: | ||
Depreciation and amortization | 61,963 | 55,721 |
Deferred income tax expense | 10,322 | 3,214 |
Allowance for equity funds used during construction and other, net | (1,653) | (1,009) |
Changes in certain assets and liabilities: | ||
Accounts receivable and unbilled revenues | (7,466) | 2,059 |
Materials and supplies | (6,439) | (2,949) |
Other current assets | 6,979 | 1,776 |
Other assets | (4,251) | 521 |
Accounts payable | (2,381) | (539) |
Accrued interest and taxes | (8,246) | (6,942) |
Other current liabilities | 179 | (1,919) |
Other liabilities | (780) | (2,611) |
Net cash flows from operating activities | 92,735 | 81,987 |
Cash Flows From Investing Activities: | ||
Utility plant additions | (253,537) | (218,488) |
Net cash flows used in investing activities | (253,537) | (218,488) |
Cash Flows From Financing Activities: | ||
Revolving credit facilities borrowings | 338,900 | 187,000 |
Revolving credit facilities repayments | (293,400) | (186,600) |
Long-term borrowings | 117,000 | 130,000 |
Transmission interconnection and security deposit arrangements | 6,750 | 11,000 |
Refunds paid under transmission interconnection and security deposit arrangements | (4,850) | (3,500) |
Debt issuance costs and other, net | (2,324) | (1,399) |
Net cash flows from financing activities | 162,076 | 136,501 |
Change in Cash, Cash Equivalents, and Restricted Cash | 1,274 | 0 |
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period | 0 | 0 |
Cash, Cash Equivalents, and Restricted Cash at End of Period | 1,274 | 0 |
Supplemental Cash Flow Disclosures: | ||
Interest paid, net of amounts capitalized | 24,624 | 19,561 |
Income taxes paid (refunded), net | 1,312 | 1,400 |
Supplemental schedule of noncash investing activities: | ||
Decrease in accrued plant additions | $ 14,697 | $ 9,734 |
Condensed Consolidated Balanc_5
Condensed Consolidated Balance Sheets - TNMP - USD ($) $ in Thousands | Jun. 30, 2024 | Dec. 31, 2023 |
Current Assets: | ||
Cash and cash equivalents | $ 3,235 | $ 2,215 |
Accounts receivable | 121,757 | 126,291 |
Unbilled revenues | 76,793 | 64,072 |
Other receivables | 103,721 | 76,509 |
Materials and supplies | 115,144 | 98,034 |
Regulatory assets | 59,397 | 73,046 |
Total current assets | 537,654 | 475,543 |
Other Property and Investments: | ||
Other investments | 229 | 171 |
Non-utility property, net | 27,116 | 29,367 |
Total other property and investments | 468,575 | 593,516 |
Utility Plant: | ||
Plant in service and plant held for future use | 10,028,222 | 9,701,180 |
Less accumulated depreciation and amortization | 2,855,197 | 2,755,823 |
Net plant in service and plant held for future use | 7,173,025 | 6,945,357 |
Construction work in progress | 727,130 | 589,834 |
Net utility plant | 7,974,937 | 7,609,862 |
Deferred Charges and Other Assets: | ||
Regulatory assets | 929,893 | 914,381 |
Goodwill | 278,297 | 278,297 |
Operating lease right-of-use assets, net of accumulated amortization | 177,285 | 182,201 |
Other deferred charges | 216,769 | 198,805 |
Total deferred charges and other assets | 1,602,244 | 1,573,684 |
Total assets | 10,583,410 | 10,252,605 |
Current Liabilities: | ||
Short-term debt | 326,400 | 261,900 |
Current installments of long-term debt | 240,770 | 280,169 |
Accounts payable | 140,304 | 205,175 |
Accrued interest and taxes | 90,763 | 98,655 |
Regulatory liabilities | 76,131 | 140,005 |
Operating lease liabilities | 10,834 | 12,267 |
Other current liabilities | 114,344 | 94,397 |
Total current liabilities | 1,138,637 | 1,230,760 |
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs | 4,596,994 | 4,241,642 |
Deferred Credits and Other Liabilities: | ||
Accumulated deferred income taxes | 854,174 | 845,280 |
Regulatory liabilities | 776,424 | 771,317 |
Asset retirement obligations | 247,653 | 245,531 |
Accrued pension liability and postretirement benefit cost | 16,168 | 21,429 |
Operating lease liabilities | 159,592 | 167,000 |
Other deferred credits | 330,559 | 319,066 |
Total deferred credits and other liabilities | 2,384,570 | 2,369,623 |
Total liabilities | 8,120,201 | 7,842,025 |
Commitments and Contingencies (Note 11) | ||
Common Stockholder’s Equity: | ||
Common stock ($10 par value; 12,000,000 shares authorized; issued and outstanding 6,358 shares) | 1,625,251 | 1,624,823 |
Retained earnings | 847,397 | 787,110 |
Total PNM common stockholder’s equity | 2,402,748 | 2,349,093 |
Total liabilities and stockholders' equity | 10,583,410 | 10,252,605 |
Texas-New Mexico Power Company | ||
Current Assets: | ||
Cash and cash equivalents | 1,274 | 0 |
Accounts receivable | 39,354 | 31,412 |
Unbilled revenues | 16,670 | 17,147 |
Other receivables | 6,997 | 26,983 |
Materials and supplies | 22,901 | 16,462 |
Regulatory assets | 9,606 | 50 |
Prepaid and other current assets | 6,376 | 2,705 |
Total current assets | 103,178 | 94,759 |
Other Property and Investments: | ||
Other investments | 102 | 102 |
Non-utility property, net | 13,921 | 14,746 |
Total other property and investments | 14,023 | 14,848 |
Utility Plant: | ||
Plant in service and plant held for future use | 3,323,163 | 3,210,870 |
Less accumulated depreciation and amortization | 607,005 | 582,140 |
Net plant in service and plant held for future use | 2,716,158 | 2,628,730 |
Construction work in progress | 206,800 | 91,274 |
Net utility plant | 2,922,958 | 2,720,004 |
Deferred Charges and Other Assets: | ||
Regulatory assets | 77,836 | 75,654 |
Goodwill | 226,665 | 226,665 |
Operating lease right-of-use assets, net of accumulated amortization | 1,362 | 1,814 |
Other deferred charges | 8,901 | 11,287 |
Total deferred charges and other assets | 314,764 | 315,420 |
Total assets | 3,354,923 | 3,145,031 |
Current Liabilities: | ||
Short-term debt | 100,600 | 55,100 |
Current installments of long-term debt | 80,000 | 79,947 |
Accrued interest and taxes | 49,312 | 57,558 |
Regulatory liabilities | 688 | 5,159 |
Operating lease liabilities | 835 | 895 |
Other current liabilities | 8,436 | 12,084 |
Total current liabilities | 287,529 | 269,295 |
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs | 1,296,927 | 1,180,933 |
Deferred Credits and Other Liabilities: | ||
Accumulated deferred income taxes | 190,415 | 178,748 |
Regulatory liabilities | 221,907 | 206,296 |
Asset retirement obligations | 936 | 898 |
Accrued pension liability and postretirement benefit cost | 1,203 | 1,480 |
Operating lease liabilities | 457 | 809 |
Other deferred credits | 73,380 | 68,911 |
Total deferred credits and other liabilities | 488,298 | 457,142 |
Total liabilities | 2,072,754 | 1,907,370 |
Commitments and Contingencies (Note 11) | ||
Common Stockholder’s Equity: | ||
Common stock ($10 par value; 12,000,000 shares authorized; issued and outstanding 6,358 shares) | 64 | 64 |
Paid-in-capital | 846,066 | 846,066 |
Retained earnings | 436,039 | 391,531 |
Total PNM common stockholder’s equity | 1,282,169 | 1,237,661 |
Total liabilities and stockholders' equity | 3,354,923 | 3,145,031 |
Texas-New Mexico Power Company | Nonrelated Party | ||
Current Liabilities: | ||
Accounts payable | 34,542 | 51,620 |
Texas-New Mexico Power Company | Related Party | ||
Current Liabilities: | ||
Accounts payable | $ 13,116 | $ 6,932 |
Condensed Consolidated Balanc_6
Condensed Consolidated Balance Sheets - TNMP (Parenthetical) - $ / shares | Jun. 30, 2024 | Dec. 31, 2023 |
Common stock, shares authorized (in shares) | 120,000,000 | 120,000,000 |
Common stock, shares issued (in shares) | 90,200,384 | 90,200,384 |
Common stock, shares outstanding (in shares) | 90,200,384 | 90,200,384 |
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 Company Common Stock | Texas-New Mexico Power Company Paid-in Capital | Texas-New Mexico Power Company Retained Earnings |
Beginning balance TNMP at Dec. 31, 2022 | $ 1,101,824 | $ 64 | $ 805,166 | $ 296,594 | |
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||
Net earnings | 34,665 | 34,665 | |||
Ending balance TNMP at Jun. 30, 2023 | 1,136,489 | 64 | 805,166 | 331,259 | |
Beginning balance TNMP at Mar. 31, 2023 | 1,111,857 | 64 | 805,166 | 306,627 | |
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||
Net earnings | 24,632 | 24,632 | |||
Ending balance TNMP at Jun. 30, 2023 | 1,136,489 | 64 | 805,166 | 331,259 | |
Beginning balance TNMP at Dec. 31, 2023 | $ 2,349,093 | 1,237,661 | 64 | 846,066 | 391,531 |
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||
Net earnings | 44,508 | 44,508 | |||
Ending balance TNMP at Jun. 30, 2024 | 2,402,748 | 1,282,169 | 64 | 846,066 | 436,039 |
Beginning balance TNMP at Mar. 31, 2024 | 1,252,244 | 64 | 846,066 | 406,114 | |
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||
Net earnings | 29,925 | 29,925 | |||
Ending balance TNMP at Jun. 30, 2024 | $ 2,402,748 | $ 1,282,169 | $ 64 | $ 846,066 | $ 436,039 |
Significant Accounting Policies
Significant Accounting Policies and Responsibility for Financial Statements | 6 Months Ended |
Jun. 30, 2024 | |
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 June 30, 2024 and December 31, 2023, and the consolidated results of operations, comprehensive income, and cash flows for the six months ended June 30, 2024 and 2023. 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 2023 Condensed Consolidated Financial Statements and Notes thereto have been reclassified to conform to the 2024 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 2023 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 and ETBC I. 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 attributable to the second quarter of 2024 of $0.3875 per share in July 2024 and declared dividends on common stock attributable to the second quarter of 2023 of $0.3675 per share in August 2023, which are reflected as Dividends Declared per Common Share on the PNMR Condensed Consolidated Statement of Earnings. PNMR did not make any cash equity contributions to TNMP in the three and six months ended June 30, 2024 and 2023. PNMR made a $55.0 million cash equity contribution to PNM in the three and six months ended June 30, 2024. PNMR did not make any cash equity contributions to PNM in the three and six months ended June 30, 2023. PNM and TNMP did not declare or pay any cash dividends on their common stock to PNMR in the three and six months ended June 30, 2024 and 2023. New Accounting Pronouncements Information concerning recently issued accounting pronouncements that have not yet been adopted by the Company is presented below. The Company does not expect difficulty in adopting these standards by their required effective dates. Accounting Standards Update 2023-07 - Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures In November 2023, the FASB issued ASU 2023-07 enhancing disclosures about significant segment expenses. Disclosure requirements of this update include disclosure, on an annual and interim basis, of significant segment expenses that are regularly provided to the Chief Operating Decision Maker (“CODM”) and included within each reported measure of segment profit or loss (collectively referred to as the “significant expense principle”); an amount for other segment items by reportable segment and a description of its composition; the title and position of the CODM and an explanation of how the CODM uses the reported measures in assessing segment performance and deciding how to allocate resources; and that a single reportable segment provides all the disclosures required by the amendments in this ASU and all existing segment disclosures in Topic 280. The amendment also clarifies that in addition to the measure most consistent with the measurement principles under GAAP, reporting of additional measures of a segment’s profit or loss used by the CODM in assessing segment performance and determining allocation of resources is allowed. ASU 2023-07 is effective for the Company for annual periods beginning January 1, 2024 and interim periods beginning January 1, 2025 with early adoption being permitted. ASU 2023-07 is to be applied retrospectively to all prior periods presented in the financial statements. Accounting Standards Update 2023-09 - Income Taxes (Topic 740): Improvements to Income Tax Disclosures In December 2023, the FASB issued ASU 2023-09 enhancing the transparency and decision usefulness of income tax disclosures. Disclosure requirements of this update include (on an annual basis) the disclosure of specific categories in the rate reconciliation and the inclusion of additional information for reconciling items that meet a quantitative threshold (if the effect of the reconciling item is equal to or greater than 5 percent of the amount computed by multiplying pre-tax income by the applicable statutory rate). The amendment also requires the disclosure (on an annual basis) of information about income taxes paid (net of refunds) including the disaggregation by federal, state, and foreign taxes as well as by individual jurisdiction. Additional requirements include the disclosure of income (loss) from continuing operations before income tax expense (benefit) disaggregated between foreign and domestic as well as income tax expense (benefit) from continuing operations disaggregated by federal, state, and foreign. ASU 2023-09 is effective for the Company beginning January 1, 2025 with early adoption being permitted. ASU 2023-09 is to be applied on a prospective basis with retrospective application permitted. |
Segment Information
Segment Information | 6 Months Ended |
Jun. 30, 2024 | |
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, which includes the asset optimization of PNM’s jurisdictional capacity, as well as providing transmission services to third parties. FERC has jurisdiction over wholesale power and transmission rates. In 2023, ETBC I, a special purpose entity that is wholly-owned by PNM, was formed for the limited purpose of purchasing, owning, and administering energy transition property, issuing Securitized Bonds, and performing related activities. See Note 6. 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, until the close of the sale of NMRD on February 27, 2024 (Note 16). 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 June 30, 2024 Electric operating revenues $ 333,671 $ 154,431 $ — $ 488,102 Cost of energy 114,772 39,934 — 154,706 Utility margin 218,899 114,497 — 333,396 Other operating expenses 106,578 34,149 (7,427) 133,300 Depreciation and amortization 54,230 31,033 9,150 94,413 Operating income (loss) 58,091 49,315 (1,723) 105,683 Interest income (expense) 4,443 127 (100) 4,470 Other income (deductions) 3,869 2,705 36 6,610 Interest charges (25,880) (14,451) (15,497) (55,828) Segment earnings (loss) before income taxes 40,523 37,696 (17,284) 60,935 Income taxes (benefit) 5,821 7,771 (4,621) 8,971 Segment earnings (loss) 34,702 29,925 (12,663) 51,964 Valencia non-controlling interest (3,783) — — (3,783) Subsidiary preferred stock dividends (132) — — (132) Segment earnings (loss) attributable to PNMR $ 30,787 $ 29,925 $ (12,663) $ 48,049 Six Months Ended June 30, 2024 Electric operating revenues $ 641,786 $ 283,193 $ — $ 924,979 Cost of energy 212,184 74,826 — 287,010 Utility margin 429,602 208,367 — 637,969 Other operating expenses 213,044 66,899 (15,847) 264,096 Depreciation and amortization 107,517 61,415 18,668 187,600 Operating income (loss) 109,041 80,053 (2,821) 186,273 Interest income (expense) 8,970 296 (216) 9,050 Other income (deductions) 24,415 3,581 (14,999) 12,997 Interest charges (50,996) (27,787) (30,807) (109,590) Segment earnings (loss) before income taxes 91,430 56,143 (48,843) 98,730 Income taxes (benefit) 11,632 11,635 (26,867) (3,600) Segment earnings (loss) 79,798 44,508 (21,976) 102,330 Valencia non-controlling interest (6,827) — — (6,827) Subsidiary preferred stock dividends (264) — — (264) Segment earnings (loss) attributable to PNMR $ 72,707 $ 44,508 $ (21,976) $ 95,239 At June 30, 2024: Total Assets $ 7,060,151 $ 3,354,923 $ 168,336 $ 10,583,410 Goodwill $ 51,632 $ 226,665 $ — $ 278,297 PNM TNMP Corporate PNMR Consolidated (In thousands) Three Months Ended June 30, 2023 Electric operating revenues $ 338,242 $ 138,914 $ — $ 477,156 Cost of energy 133,609 38,843 — 172,452 Utility margin 204,633 100,071 — 304,704 Other operating expenses 106,154 33,395 (6,314) 133,235 Depreciation and amortization 44,064 27,949 7,126 79,139 Operating income (loss) 54,415 38,727 (812) 92,330 Interest income (expense) 5,370 121 (132) 5,359 Other income (deductions) 3,695 1,512 655 5,862 Interest charges (20,766) (11,412) (13,721) (45,899) Segment earnings (loss) before income taxes 42,714 28,948 (14,010) 57,652 Income taxes (benefit) 7,411 4,316 (3,498) 8,229 Segment earnings (loss) 35,303 24,632 (10,512) 49,423 Valencia non-controlling interest (3,987) — — (3,987) Subsidiary preferred stock dividends (132) — — (132) Segment earnings (loss) attributable to PNMR $ 31,184 $ 24,632 $ (10,512) $ 45,304 Six Months Ended June 30, 2023 Electric operating revenues $ 768,407 $ 252,826 $ — $ 1,021,233 Cost of energy 343,462 70,676 — 414,138 Utility margin 424,945 182,150 — 607,095 Other operating expenses 204,876 66,247 (12,662) 258,461 Depreciation and amortization 87,750 55,389 14,074 157,213 Operating income (loss) 132,319 60,514 (1,412) 191,421 Interest income (expense) 10,219 235 (252) 10,202 Other income (deductions) 10,728 1,648 528 12,904 Interest charges (38,888) (21,837) (26,097) (86,822) Segment earnings (loss) before income taxes 114,378 40,560 (27,233) 127,705 Income taxes (benefit) 19,240 5,895 (7,126) 18,009 Segment earnings (loss) 95,138 34,665 (20,107) 109,696 Valencia non-controlling interest (9,114) — — (9,114) Subsidiary preferred stock dividends (264) — — (264) Segment earnings (loss) attributable to PNMR $ 85,760 $ 34,665 $ (20,107) $ 100,318 At June 30, 2023: Total Assets $ 6,440,357 $ 2,916,206 $ 270,407 $ 9,626,970 Goodwill $ 51,632 $ 226,665 $ — $ 278,297 Non-GAAP Financial Measures 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 consumers 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. PNM and TNMP do not intend for utility margin to represent any financial measure as defined by GAAP. However, the calculation of utility margin, as presented, most closely compares to gross margin as defined by GAAP. Reconciliations between utility margin and gross margin are presented below. PNM TNMP Corporate and Other PNMR Consolidated (In thousands) Three Months Ended June 30, 2024 Gross margin $ 124,735 $ 73,763 $ — $ 198,498 Energy production costs 24,584 — — 24,584 Transmission and distribution costs 15,350 9,701 — 25,051 Depreciation and amortization 54,230 31,033 — 85,263 1 Utility margin $ 218,899 $ 114,497 $ — $ 333,396 Six Months Ended June 30, 2024 Gross margin $ 245,589 $ 128,837 $ — $ 374,426 Energy production costs 46,796 — — 46,796 Transmission and distribution costs 29,700 18,115 — 47,815 Depreciation and amortization 107,517 61,415 — 168,932 1 Utility margin $ 429,602 $ 208,367 $ — $ 637,969 Three Months Ended June 30, 2023 Gross margin $ 120,215 $ 61,412 $ — $ 181,627 Energy production costs 25,599 — — 25,599 Transmission and distribution costs 14,755 10,710 — 25,465 Depreciation and amortization 44,064 27,949 — 72,013 1 Utility margin $ 204,633 $ 100,071 $ — $ 304,704 Six Months Ended June 30, 2023 Gross margin $ 260,596 $ 107,742 $ — $ 368,338 Energy production costs 47,957 — — 47,957 Transmission and distribution costs 28,642 19,019 — 47,661 Depreciation and amortization 87,750 55,389 — 143,139 1 Utility margin $ 424,945 $ 182,150 $ — $ 607,095 1 Corporate and Other depreciation and amortization represents corporate level activities that are billed at cost and reflected as general and administrative expenses at PNM and TNMP and therefore are not a component of gross margin or utility margin. See Note 1. |
Accumulated Other Comprehensive
Accumulated Other Comprehensive Income (Loss) | 6 Months Ended |
Jun. 30, 2024 | |
Equity [Abstract] | |
Accumulated Other Comprehensive Income (Loss) | Accumulated Other Comprehensive Income (Loss) Information regarding accumulated other comprehensive income (loss) for the six months ended June 30, 2024 and 2023 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, 2023 $ 10,652 $ (77,157) $ (66,505) $ 3,665 $ (62,840) Amounts reclassified from AOCI (pre-tax) (12,566) 2,433 (10,133) 5,563 (4,570) Income tax impact of amounts reclassified 3,192 (618) 2,574 (1,413) 1,161 Other OCI changes (pre-tax) (587) — (587) (4,307) (4,894) Income tax impact of other OCI changes 149 — 149 1,094 1,243 Net after-tax change (9,812) 1,815 (7,997) 937 (7,060) Balance at June 30, 2024 $ 840 $ (75,342) $ (74,502) $ 4,602 $ (69,900) Balance at December 31, 2022 $ 7,422 $ (81,757) $ (74,335) $ 8,287 $ (66,048) Amounts reclassified from AOCI (pre-tax) (2,580) 2,388 (192) 1,197 1,005 Income tax impact of amounts reclassified 655 (606) 49 (304) (255) Other OCI changes (pre-tax) 4,560 — 4,560 3,567 8,127 Income tax impact of other OCI changes (1,158) — (1,158) (906) (2,064) Net after-tax change 1,477 1,782 3,259 3,554 6,813 Balance at June 30, 2023 $ 8,899 $ (79,975) $ (71,076) $ 11,841 $ (59,235) 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 | 6 Months Ended |
Jun. 30, 2024 | |
Earnings Per Share [Abstract] | |
Earnings Per Share | Earnings Per Share Basic earnings per share is computed by dividing net earnings attributable to PNMR by the weighted average number of common shares outstanding during the period. Diluted earnings per share was computed by dividing net earnings attributable to PNMR by the diluted weighted average number of common shares outstanding during the period. Diluted earnings per share reflect the potential dilution that could occur if securities or other agreements to issue common stock were settled. PNMR applies the treasury stock method for restricted stock, the 2023 Forward Sale Agreements, and the Q2 2024 Forward Sale Agreement. The if-converted method is applied in determining the potential dilutive effect of the conversion of outstanding Convertible Notes. For the three and six months ended June 30, 2024, the Q2 2024 Forward Sale Agreement and the Convertible Notes were excluded from the calculation of diluted EPS because the effects were antidilutive. Information regarding the computation of earnings per share is as follows: Three Months Ended Six Months Ended June 30, June 30, 2024 2023 2024 2023 (In thousands, except per share amounts) Net Earnings Attributable to PNMR $ 48,049 $ 45,304 $ 95,239 $ 100,318 Average Number of Common Shares: Outstanding during period 90,200 85,835 90,200 85,835 Vested awards of restricted stock 304 250 293 258 Average Shares – Basic 90,504 86,085 90,493 86,093 Dilutive Effect of Common Stock Equivalents: Restricted stock 48 39 40 38 2023 Forward Sale Agreements — 5 — 2 Average Shares – Diluted 90,552 86,129 90,533 86,133 Net Earnings Per Share of Common Stock: Basic $ 0.53 $ 0.53 $ 1.05 $ 1.17 Diluted $ 0.53 $ 0.53 $ 1.05 $ 1.16 |
Electric Operating Revenues
Electric Operating Revenues | 6 Months Ended |
Jun. 30, 2024 | |
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 2023 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. In addition to the allowance for credit losses on trade receivables, the Company has evaluated other receivables for potential credit related losses. These balances include potential exposures for other non-retail utility services. In the three and six months ended June 30, 2024 and 2023, there were no estimated credit losses related to these transactions. 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 $82.4 million at June 30, 2024 and $93.6 million at December 31, 2023 resulting from contracts with customers. All of TNMP’s accounts receivable results from contracts with customers. Contract assets are an entity’s right to consideration in exchange for goods or services that the entity has transferred to a customer when that right is conditioned on something other than the passage of time (for example, the entity’s future performance). Upon the completion of the Western Spirit Line, PNM entered into a Transmission Service Agreement (“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 is $27.1 million at June 30, 2024 and $22.1 million at December 31, 2023. This contract asset is presented in Other deferred charges on the Condensed Consolidated Balance Sheets. Contract liabilities arise when consideration is received in advance from a customer before satisfying the performance obligations. Therefore, revenue is deferred and not recognized until the obligation is satisfied. 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 not material for any of the periods presented. The Company has no other arrangements with remaining performance obligations to which a portion of the transaction price would be required to be allocated. Disaggregation of Revenues A disaggregation of revenues from contracts with customers by the type of customer is presented in the table below. PNM TNMP PNMR Consolidated Three Months Ended June 30, 2024 (In thousands) Electric Operating Revenues: Contracts with customers: Retail electric revenue Residential $ 121,065 $ 47,313 $ 168,378 Commercial 109,929 40,499 150,428 Industrial 34,201 7,917 42,118 Public authority 5,216 1,740 6,956 Economy energy service 4,033 — 4,033 Transmission 33,333 42,116 75,449 Wholesale energy sales (1) 23,507 — 23,507 Miscellaneous 1,389 962 2,351 Total revenues from contracts with customers 332,673 140,547 473,220 Alternative revenue programs 830 13,884 14,714 Other electric operating revenues 168 — 168 Total Electric Operating Revenues $ 333,671 $ 154,431 $ 488,102 Six Months Ended June 30, 2024 Electric Operating Revenues: Contracts with customers: Retail electric revenue Residential $ 241,450 $ 88,808 $ 330,258 Commercial 209,266 76,043 285,309 Industrial 58,970 17,773 76,743 Public authority 9,614 3,456 13,070 Economy energy service 11,595 — 11,595 Transmission 69,482 77,925 147,407 Wholesale energy sales (1) 35,197 — 35,197 Miscellaneous 2,814 1,917 4,731 Total revenues from contracts with customers 638,388 265,922 904,310 Alternative revenue programs 2,736 17,271 20,007 Other electric operating revenues 662 — 662 Total Electric Operating Revenues $ 641,786 $ 283,193 $ 924,979 PNM TNMP PNMR Consolidated Three Months Ended June 30, 2023 (In thousands) Electric Operating Revenues: Contracts with customers: Retail electric revenue Residential $ 108,016 $ 41,491 $ 149,507 Commercial 105,262 37,965 143,227 Industrial 26,156 12,930 39,086 Public authority 5,305 1,669 6,974 Economy energy service 10,731 — 10,731 Transmission 37,922 35,062 72,984 Wholesale energy sales (1) 37,308 — 37,308 Miscellaneous 1,377 907 2,284 Total revenues from contracts with customers 332,077 130,024 462,101 Alternative revenue programs 3,577 8,890 12,467 Other electric operating revenues 2,588 — 2,588 Total Electric Operating Revenues $ 338,242 $ 138,914 $ 477,156 Six Months Ended June 30, 2023 Electric Operating Revenues: Contracts with customers: Retail electric revenue Residential $ 227,901 $ 77,857 $ 305,758 Commercial 203,323 72,695 276,018 Industrial 45,633 25,694 71,327 Public authority 9,723 3,288 13,011 Economy energy service 20,041 — 20,041 Transmission 86,930 65,120 152,050 Wholesale energy sales (1) 150,294 — 150,294 Miscellaneous 2,786 1,848 4,634 Total revenues from contracts with customers 746,631 246,502 993,133 Alternative revenue programs 10,902 6,324 17,226 Other electric operating revenues 10,874 — 10,874 Total Electric Operating Revenues $ 768,407 $ 252,826 $ 1,021,233 (1) Includes sales for resale activity resulting from PNM’s participation in the EIM. |
Variable Interest Entities
Variable Interest Entities | 6 Months Ended |
Jun. 30, 2024 | |
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 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 2023 Annual Reports on Form 10-K. Valencia PNM has a PPA to purchase all of the electric capacity and energy from Valencia, a 155 MW natural gas-fired power plant near Belen, New Mexico, through May 2028. A third party built, owns, and operates the facility while PNM is the sole purchaser of the electricity generated. PNM is obligated to pay fixed operation and maintenance and capacity charges in addition to variable operation and maintenance charges under this PPA. For the three and six months ended June 30, 2024, PNM paid $5.1 million and $10.2 million for fixed charges and $0.4 million and $0.5 million for variable charges. For the three and six months ended June 30, 2023, PNM paid $5.1 million and $10.0 million for fixed charges and $1.1 million and $2.7 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 are set forth below and are 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 June 30, Six Months Ended June 30, 2024 2023 2024 2023 (In thousands) Operating revenues $ 5,476 $ 6,144 $ 10,665 $ 12,748 Operating expenses 1,693 2,157 3,838 3,634 Earnings attributable to non-controlling interest $ 3,783 $ 3,987 $ 6,827 $ 9,114 Financial Position June 30, December 31, 2024 2023 (In thousands) Current assets $ 3,664 $ 3,422 Net property, plant, and equipment 45,832 47,253 Total assets 49,496 50,675 Current liabilities 564 717 Owners’ equity – non-controlling interest $ 48,932 $ 49,958 Westmoreland San Juan Mining, LLC As discussed in the subheading Coal Supply in Note 11, PNM and Westmoreland San Juan Mining, LLC (“WSJ LLC”), a subsidiary of Westmoreland Mining Holdings, LLC have agreements under which CCR disposal and mine reclamation services for SJGS will be provided. PNMR issued $30.3 million in letters of credit to facilitate the issuance of reclamation bonds. 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 the reclamation services agreement provides WSJ LLC the ability to recover the cost of reclamation. Additionally, much of the mine reclamation activities have been and will continue to be performed after the SJGS CSA expired on September 30, 2022. As discussed in Note 11, each of the SJGS participants has established and actively fund trusts to meet future reclamation obligations. WSJ LLC is considered a VIE. PNMR’s analysis of its arrangements with WSJ LLC concluded that WSJ LLC has the ability to direct its reclamation services, which are the factors that most significantly impact the economic performance of WSJ LLC. Other than PNM being able to monitor reclamation activities, the reclamation services were solely under the control of WSJ LLC, including developing reclamation plans, hiring of personnel, and incurring operating and maintenance expenses. Neither PNMR nor PNM has any ability to direct or influence the reclamation activities. PNM’s involvement through the reclamation services agreement is a protective right rather than a participating right and WSJ LLC still has the power to direct the activities that most significantly impact the economic performance of WSJ LLC. If WSJ LLC performs reclamation services more efficiently than anticipated, its economic performance will improve. Conversely, if WSJ LLC does not perform reclamation services as efficiently as anticipated, its economic performance will be negatively impacted. Accordingly, PNMR believes WSJ LLC is the primary beneficiary and, therefore, WSJ LLC is not consolidated by either PNMR or PNM. The amounts outstanding under the letters of credit support continue to be PNMR’s maximum exposure to loss from the VIE at June 30, 2024. ETBC I ETBC I is a wholly-owned, special purpose, subsidiary of PNM that was formed in August 2023 for the limited purpose of purchasing, owning, and administering energy transition property, issuing Securitized Bonds, and performing related activities authorized by the NMPRC. On November 15, 2023, ETBC I issued Securitized Bonds and used the proceeds to purchase energy transition property from PNM. The energy transition property purchased includes the right to impose, bill, collect, and adjust a non-bypassable energy transition charge from all PNM retail customers until the Securitized Bonds are paid in full and all allowed financing costs have been recovered. The Securitized Bonds are secured by the energy transition property and cash collections from the energy transition charges are the sole source of funds to satisfy the debt obligation. The bondholders have no recourse to PNM. PNM acts as the servicer of the energy transition property on behalf of ETBC I and is responsible for metering, calculating, billing, and collecting the Energy Transition Charges. On behalf of ETBC I, PNM is required to remit all collections of the Energy Transition Charges to the trustee for the Securitized Bonds. PNM has the power to direct the activities that most significantly impact the economic performance of ETBC I and will absorb the majority of the variability in the cash flows of the entity. As the primary beneficiary, PNM consolidates ETBC I in its financial statements. Accordingly, the assets, liabilities, operating expenses, and cash flows of ETBC I are included in the Consolidated Financial Statements of PNM. The following tables summarize the impact of ETBC I on PNM’s Financial Statements: Results of Operations Three Months Ended June 30, 2024 Six Months Ended June 30, 2024 (In thousands) Operating Revenues $ 5,811 $ 11,756 Depreciation and amortization 821 1,643 Interest charges 5,039 10,064 Other (49) 49 Net Earnings $ — $ — Financial Position June 30, 2024 December 31, 2023 (In thousands) Regulatory Assets - Current $ — $ 2,724 Restricted Cash (included in Other Current Assets) 15,318 — Restricted Cash (included in Other Deferred Charges) 1,767 1,728 Securitized Cost (included in Deferred Regulatory Assets) 338,986 340,629 Current Installments of Long-Term Debt 5,935 2,529 Accrued Interest 12,509 2,502 Regulatory Liabilities - Current 2,401 — Long-Term Debt 335,172 338,521 |
Fair Value of Derivative and Ot
Fair Value of Derivative and Other Financial Instruments | 6 Months Ended |
Jun. 30, 2024 | |
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 2023 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 may be exposed to market risk for the needs of its customers not covered under the FPPAC. PNM has entered into agreements for the purchase and sale of power from third parties. On April 23, 2024, PNM entered into agreements to purchase a total of 150 MW from July 1, 2024 through July 31, 2024 and 100 MW from August 1, 2024 through August 30, 2024. The agreements will be accounted for as derivative agreements and will be considered economic hedges under the NMPRC approved hedging plan covered by its FPPAC during the second quarter of 2024. Agreements for the purchase of 85 MW from June through September 2023 as well as agreements for the sale of 50 MW from September 1, 2024 through December 31, 2024 were not considered derivatives because there was either no notional amount due to their unit-contingent nature or qualified for a normal purchase, normal sale scope exception. PNM’s operations are managed primarily through a net asset-backed strategy, whereby PNM’s aggregate net open forward contract position is covered by its forecasted excess generation capabilities or market purchases. PNM could be exposed to market risk if its generation capabilities were to be disrupted or if its load requirements were to be greater than anticipated. If all or a portion of load requirements were required to be covered as a result of such unexpected situations, commitments would have to be met through market purchases. TNMP does not enter into energy related derivative contracts. Commodity Risk Marketing and procurement of energy often involve market risks associated with managing energy commodities and establishing positions in the energy markets, primarily on a short-term basis. PNM routinely enters into various derivative instruments such as forward contracts, option agreements, and price basis swap agreements to economically hedge price and volume risk on power commitments and fuel requirements and to minimize the effect of market fluctuations. PNM monitors the market risk of its commodity contracts in accordance with approved risk and credit policies. Accounting for Derivatives Under derivative accounting and related rules for energy contracts, PNM accounts for its various instruments for the purchase and sale of energy, which meet the definition of a derivative, based on PNM’s intent. During the six months ended June 30, 2024 and the year ended December 31, 2023, PNM was not hedging its exposure to the variability in future cash flows from commodity derivatives through designated cash flow hedges. The derivative contracts recorded at fair value that do not qualify or are not designated for cash flow hedge accounting are classified as economic hedges. Economic hedges are defined as derivative instruments, including long-term power agreements, used to economically hedge generation assets, purchased power and fuel costs, and customer load requirements. Changes in the fair value of economic hedges are reflected in results of operations on the Condensed Consolidated Statements of Earnings and are classified between Electric 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 Regulatory liabilities on the Condensed Consolidated Balance Sheets. The cash impacts of settled derivatives are recorded as operating activities or financing activities on the Condensed Consolidated Statement of Cash Flows consistent with the classification of the hedged transaction. 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 June 30, December 31, (In thousands) Other current assets $ 846 $ 826 Other current liabilities (4,558) — Net $ (3,712) $ 826 Certain of PNM’s commodity derivative instruments in the above table are subject to master netting agreements whereby assets and liabilities could be offset in the settlement process. PNM does not offset fair value and cash collateral for derivative instruments under master netting arrangements and the above table reflects the gross amounts of fair value assets and liabilities for commodity derivatives. As discussed above, PNM has NMPRC-approved guidelines for hedging arrangements to manage fuel and purchased power costs related to customers covered by its FPPAC. The table above includes $0.8 million of current assets and $4.6 million of current liabilities related to these arrangements at June 30, 2024 and $0.8 million of current assets and zero of current liabilities at December 31, 2023 with changes in fair value recorded as regulatory assets and regulatory liabilities. At June 30, 2024 and December 31, 2023, PNM had no amounts recognized for the legal right to reclaim cash collateral. However, amounts posted as cash collateral under margin arrangements were $0.6 million at June 30, 2024 and $0.2 million at December 31, 2023. These amounts are included in other current assets on the Condensed Consolidated Balance Sheets. At June 30, 2024 and December 31, 2023, obligations to return cash collateral were $0.2 million, which is included in other current liabilities on the Condensed Consolidated Balance Sheets. The changes in the fair value of commodity derivative instruments that are considered economic hedges had no impact on PNM’s net earnings during the six months ended June 30, 2024 and 2023. Commodity derivatives had no impact on OCI for any of the periods presented. Commodity contract volume positions are presented in MMBTU for gas related contracts and in MWh for power related contracts. The table below presents PNM’s net buy (sell) volume positions: Economic Hedges MMBTU MWh June 30, 2024 — 66,790 December 31, 2023 — (15,360) In connection with managing its commodity risks, PNM enters into master agreements with certain counterparties. If PNM is in a net liability position under an agreement, some agreements provide that the counterparties can request collateral if PNM’s credit rating is downgraded; other agreements provide that the counterparty may request collateral to provide it with “adequate assurance” that PNM will perform; and others have no provision for collateral. The table below presents information about PNM’s contingent requirements to provide collateral under certain commodity contracts having an objectively determinable collateral provision, that are in net liability positions, and that are not fully collateralized with cash. Contractual liability represents those commodity derivative contracts recorded at fair value on the balance sheet, determined on an individual contract basis without offsetting amounts for individual contracts that are in an asset position and could be offset under master netting agreements with the same counterparty. Cash collateral posted under these contracts does not reflect letters of credit under the Company’s revolving credit facilities that may have been issued as collateral. Net exposure is the net contractual liability for all contracts, including those designated as normal purchase and normal sale, offset by existing collateral and by any offsets available under master netting agreements, including both assets and liability positions. Contractual Liability Existing Cash Collateral Net Exposure (In thousands) June 30, 2024 $ 4,558 $ — $ 4,558 December 31, 2023 $ — $ — $ — 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, a trust for PNM’s share of decommissioning costs at SJGS, and trusts for PNM’s share of final reclamation costs related to the coal mines serving SJGS and Four Corners. See Note 11. At June 30, 2024 and December 31, 2023, the fair value of investment securities included $370.9 million and $361.0 million for the NDT, $9.6 million and $12.3 million for the SJGS decommissioning trust, and $60.7 million and $71.1 million for the coal mine reclamation trusts. PNM records a realized loss as an impairment for any available-for-sale debt security that has a fair value that is less than its carrying value. At June 30, 2024 and December 31, 2023, 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, SJGS decommissioning, and coal mine reclamation trusts are presented in the following table: Three Months Ended Six Months Ended June 30, June 30, 2024 2023 2024 2023 (In thousands) Equity securities: Net gains (losses) from equity securities sold $ 6,272 $ 2,792 $ 16,143 $ 1,947 Net gains (losses) from equity securities still held (3,880) 1,142 (5,085) 8,619 Total net gains on equity securities 2,392 3,934 11,058 10,566 Available-for-sale debt securities: Net gains (losses) on debt securities (1,834) (157) 7,498 (347) Net gains on investment securities $ 558 $ 3,777 $ 18,556 $ 10,219 The proceeds and gross realized gains and losses on the disposition of securities held in the NDT, SJGS decommissioning trust, 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 $1.6 million and $15.0 million for the three and six months ended June 30, 2024 and $1.4 million and $3.4 million for the three and six months ended June 30, 2023. Three Months Ended Six Months Ended June 30, June 30, 2024 2023 2024 2023 (In thousands) Proceeds from sales $ 110,240 $ 183,566 $ 412,750 $ 274,777 Gross realized gains 7,549 7,014 21,228 10,442 Gross realized (losses) (4,661) (5,741) (12,573) (12,212) At June 30, 2024, the available-for-sale debt securities held by PNM, had the following final maturities: Fair Value (In thousands) Within 1 year $ 26,903 After 1 year through 5 years 11,678 After 5 years through 10 years 9,426 After 10 years through 15 years 10,668 After 15 years through 20 years 5,467 After 20 years 497 $ 64,639 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 fair values are provided by fund managers utilizing a pricing service. For Level 2 fair values, the pricing provider predominantly uses the market approach using bid side market values based upon a hierarchy of information for specific securities or securities with similar characteristics. Fair values of Level 2 investments in mutual funds are equal to net asset value (“NAV”). For commodity derivatives, Level 2 fair values are determined based on market observable inputs, which are validated using multiple broker quotes, including forward price, volatility, and interest rate curves to establish expectations of future prices. Credit valuation adjustments are made for estimated credit losses based on the overall exposure to each counterparty. For the Company’s long-term debt, Level 2 fair values are provided by an external pricing service. The pricing service primarily utilizes quoted prices for similar debt in active markets when determining fair value. Management of the Company independently verifies the information provided by pricing services. Uncategorized investments include common/collective investment trusts, which are measured at NAV at the end of each reporting period. Audited financial statements are received for each fund and reviewed by the Company annually. Fair value for these collective investment trusts is measured using a practical expedient provided under GAAP that allows the NAV per share to be used as fair value for investments in certain entities that do not have readily determinable fair values and are considered to be investment companies. Investments valued using this practical expedient are not required to be presented within the GAAP fair value hierarchy. Items recorded at fair value by PNM on the 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) June 30, 2024 Cash and cash equivalents $ 122,964 $ 122,964 $ — Equity securities: Corporate stocks, common 83,258 83,258 — Corporate stocks, preferred — — — Mutual funds and other 131,525 131,525 — Available-for-sale debt securities: U.S. government 22,189 22,189 — $ 254 Municipals 34,813 — 34,813 785 Corporate and other 7,637 — 7,637 124 Investments categorized within the fair value hierarchy $ 402,386 $ 359,936 $ 42,450 $ 1,163 Uncategorized Collective Investment Trust 38,844 — — Total investment securities $ 441,230 $ 359,936 $ 42,450 December 31, 2023 Cash and cash equivalents $ 93,873 $ 93,873 $ — Equity securities: Corporate stocks, common 77,422 77,422 — Corporate stocks, preferred 4,323 504 3,819 Mutual funds and other 57,966 57,966 — Available-for-sale debt securities: U.S. government 35,113 34,522 591 $ 2,055 International government 8,735 — 8,735 104 Municipals 53,436 — 53,436 2,872 Corporate and other 113,540 — 113,540 9,285 Total investment securities $ 444,408 $ 264,287 $ 180,121 $ 14,316 The carrying amounts and fair values of long-term debt, all of which are considered Level 2 fair value measurements and are not recorded at fair value on the Condensed Consolidated Balance Sheets, are presented below: Carrying Amount Fair Value June 30, 2024 (In thousands) PNMR $ 4,837,764 $ 4,511,857 PNM 2,461,304 2,278,988 TNMP 1,376,927 1,232,842 December 31, 2023 PNMR $ 4,521,811 $ 4,260,509 PNM 2,261,780 2,107,588 TNMP 1,260,880 1,152,922 The carrying amount and fair value of the Company’s other investments presented on the Condensed Consolidated Balance Sheets are not material and not shown in the above table. |
Stock-Based Compensation
Stock-Based Compensation | 6 Months Ended |
Jun. 30, 2024 | |
Share-Based Payment Arrangement [Abstract] | |
Stock-Based Compensation | Stock-Based Compensation PNMR has various stock-based compensation programs, which provide restricted stock awards, that are performance based and time based, under the Performance Equity Plan (“PEP”). Although certain PNM and TNMP employees are eligible to participate in the PNMR plans, PNM and TNMP do not have separate employee stock-based compensation plans. Performance stock awards awarded under the PEP are awarded for a three-year, overlapping performance period. Performance stock awards with performance periods ending before 2024 or after 2025 are subject to achieving both performance and market targets. Performance stock awards with performance periods ending from 2024 through 2025 do not include market targets. Other awards of restricted stock are only subject to time-based vesting requirements. Additional information concerning stock-based compensation under the PEP is contained in Note 12 of the Notes to Consolidated Financial Statements in the 2023 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 June 30, 2024, PNMR had unrecognized expense related to stock awards of $7.6 million, which is expected to be recognized over an average of 1.7 years. The grant date fair value for restricted stock and stock awards with internal PNMR 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: Six Months Ended June 30, Restricted Shares and Performance Based Shares 2024 2023 Expected quarterly dividends per share $ 0.3875 $ 0.3675 Risk-free interest rate 4.27 % 4.46 % Market-Based Shares Dividend yield 4.21 % N/A Expected volatility 13.09 % N/A Risk-free interest rate 4.31 % N/A The following table summarizes activity in restricted stock awards, including performance-based and market-based shares for the six months ended June 30, 2024: Restricted Stock Shares Weighted- Outstanding at December 31, 2023 212,080 $ 40.33 Granted 239,982 32.43 Released (165,583) 38.27 Forfeited — — Outstanding at June 30, 2024 286,479 $ 34.91 Included, as granted and released, in the table above are 80,492 previously awarded shares that were earned for the 2021 - 2023 performance measurement period and ratified by the Board in February 2024 (based upon achieving targets at above “target”, below “maximum” levels). Excluded from the table above are 141,041, 139,825, and 201,916 shares for the three-year performance periods ending in 2024, 2025 and 2026 that will be awarded if all performance and market criteria are achieved at maximum levels and all executives remain eligible. On December 4, 2023, the Company entered into a retention agreements with its Chairman and Chief Executive Officer and its Senior Vice President and General Counsel under which they would be awarded a total of 26,766 and 8,922 respectively of restricted stock rights if they remained employed through the award’s vesting date which is the earliest of 24 months from the grant date, the closing of the Merger, or six months following the termination of the Merger. Upon the notice from Avangrid regarding the termination of the Merger Agreement as of December 31, 2023, these awards vested on June 30, 2024. On December 4, 2023, the Company entered into a retention agreement with its President and Chief Operating Officer under which he would receive a retention bonus of $1.0 million to be paid in increments beginning in December 2023 and continuing each December until 2025. On April 8, 2024, pursuant to the retention agreement, the Board elected to convert the unvested portion of the retention bonus of $0.8 million, into restricted stock rights whereby each share of restricted stock is equal to one share of Company stock as of the first trading day after expiration of the current black-out period. On May 3, 2024, subsequent to the expiration of the black-out period, 19,851 restricted stock rights were awarded that will vest in accordance with the original terms of the retention agreement. The following table provides additional information concerning restricted stock activity, including performance-based and market-based shares: Six Months Ended June 30, Restricted Stock 2024 2023 Weighted-average grant date fair value $ 32.43 $ 45.00 Total fair value of restricted shares that vested (in thousands) $ 6,180 $ 9,622 |
Financing
Financing | 6 Months Ended |
Jun. 30, 2024 | |
Debt Disclosure [Abstract] | |
Financing | Financing The Company’s financing strategy includes both short-term and long-term borrowings. The Company utilizes short-term revolving credit facilities, as well as cash flows from operations, to provide funds for both construction and operating expenditures. Depending on market and other conditions, the Company will periodically sell long-term debt, enter into term loan arrangements, or equity 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 2023 Annual Reports on Form 10-K. On May 16, 2023, PNM filed a shelf registration statement that provides for the issuance of up to $650.0 million of SUNs that expires in May 2026. On March 2, 2022, PNMR filed a shelf registration that provides for the issuance of various types of debt and equity securities. The PNMR shelf registration statement expires in March 2025. Financing Activities On May 6, 2024, PNMR entered into a distribution agreement with BofA Securities, Inc., Citigroup Global Markets, Inc., MUFG Securities Americas Inc., RBC Capital Markets, LLC, Scotia Capital (USA) Inc., and Wells Fargo Securities, LLC, as sales agents and Bank of America, N.A., Citibank, N.A., MUFG Securities EMEA plc, Royal Bank of Canada, The Bank of Nova Scotia, and Wells Fargo Bank, N.A., as forward purchasers, pursuant to which the Company may sell, from time to time, up to an aggregate sales price of $100.0 million of its common stock, no par value, through the sales agents (the “PNMR 2024 ATM Program”). Sales of the shares made pursuant to the distribution agreement, if any, may be made in “at the market offerings” as defined in Rule 415 of the Securities Act. Actual sales will depend on a variety of factors to be determined by the Company, including (among others) market conditions, the trading price of PNMR’s common stock, capital needs and determinations by the Company of the appropriate sources of funding for the Company. PNMR did not receive any proceeds upon the execution of this agreement. The Company also may enter into forward stock purchase transactions, pursuant to the distribution agreement, in which forward purchasers may borrow from third parties and, through a sales agent acting as a forward seller, sell a number of shares equal to the number of shares of the Company’s common stock to hedge the agreement. Although the Company expects to settle any forward stock purchase transaction with fully physical settlement, except in certain specified circumstances, PNMR has the option to elect physical, cash, or net share settlement of the forward stock purchase transactions. The Company will not receive any proceeds from the sale of borrowed shares of common stock by a forward seller. The Company expects to receive proceeds from the sale of shares directly by sales agents or upon future physical settlement(s) in connection with the forward stock purchase transaction, in which latter case the Company will expect to receive, subject to certain adjustments, aggregate net cash proceeds at settlement equal to the number of shares underlying the relevant forward agreement, multiplied by the relevant forward sale price. During the second quarter of 2024, PNMR entered into a forward sale agreement with a forward purchaser for the sale of 262,025 shares of common stock, under the PNMR 2024 ATM Program (the “Q2 2024 Forward Sale Agreement”). The initial forward sale price of $37.77 per share is subject to adjustments based on a net interest rate factor and by future dividends paid on PNMR common stock as specified in the forward sale agreement. PNMR did not initially receive any proceeds upon the execution of this agreement and, except in certain specified circumstances, has the option to elect physical, cash, or net share settlement of the forward sale agreements on or before a date that is 12 months from the agreement effective date. As of June 30, 2024, no shares have been settled under the Q2 2024 Forward Sale Agreement. On May 10, 2024, PNM entered into a $200.0 million term loan agreement (the “PNM 2024 Term Loan”), among PNM, the lenders party thereto and U.S. Bank National Association, as administrative agent. PNM used the proceeds of the PNM 2024 Term Loan to repay borrowings under the PNM Revolving Credit Facility, the PNM New Mexico Credit Facility, and for general corporate purposes. The PNM 2024 Term Loan bears interest at a variable rate, which was 6.33% at June 30, 2024, and must be repaid on or before November 10, 2025. On June 10, 2024, PNMR issued $500.0 million aggregate principal amount of junior subordinated convertible notes due 2054 (the “Convertible Notes”) in a private offering to qualified institutional buyers pursuant to Rule 144A under the Securities Act. The Convertible Notes are unsecured obligations of the Company and rank junior and subordinate in right of payment to the prior payment in full of the Company’s existing and future senior indebtedness. The Convertible Notes bear interest at a rate of 5.75% per year, payable semi-annually in arrears on June 1 and December 1, and mature on June 1, 2054, unless earlier converted, redeemed, or repurchased in accordance with their terms. On June 21, 2024, PNMR issued an additional $50.0 million aggregate principal amount of the Convertible Notes, pursuant to an overallotment option granted by PNMR to the initial purchasers of the $500.0 million Convertible Notes. Proceeds from the Convertible Notes were used to prepay $449.0 million of borrowings under the PNMR 2021 Delayed Draw Term Loan and $90.0 million of borrowings under the PNMR 2023 Term Loan, without penalty, and for other corporate purposes. PNMR may not redeem the Convertible Notes prior to June 6, 2029, except upon the occurrence of certain tax events, rating agency events or treasury stock events (each, a “special event”). PNMR may redeem for cash all, but not less than all, of the Convertibles Notes upon the occurrence of a special event at any time, at its option, at a redemption price equal to 100% of the principal amount of the Convertible Notes to be redeemed, plus accrued and unpaid interest to, but excluding, the redemption date. In addition, PNMR may redeem for cash all or part (subject to certain limitations on partial redemptions) of the Convertible Notes, at its option, on or after June 6, 2029, at a redemption price equal to 100% of the principal amount of the convertible notes to be redeemed, plus accrued and unpaid interest to, but excluding, the redemption date, if the last reported sale price of PNM Resources’ common stock has been at least 130% of the conversion price of the convertible notes then in effect for at least 20 trading days (whether or not consecutive) during any 30 consecutive trading day period (including the last trading day of such period) ending on, and including, the trading day immediately preceding the date on which PNMR provides notice of redemption. In each case, PNMR will not, and will not be permitted to, issue a notice of redemption, or specify a redemption date, during any interest deferral period. Prior to the close of business on the business day immediately preceding December 1, 2053, the Convertible Notes will be convertible at the option of the holders only under certain conditions. On or after December 1, 2053 until the close of business on the second business day immediately preceding the maturity date, holders may convert all or any portion of their Convertible Notes at their option, at any time, at the conversion rate then in effect, irrespective of these conditions. Upon conversion of the Convertible Notes, PNMR will pay cash, or deliver an equal aggregate principal amount of a newly issued series of its nonconvertible junior subordinated notes with the same terms as the Convertible Notes (other than the conversion features and certain features in relation to redemption rights), in either case, up to the aggregate principal amount of the Convertible Notes being converted, and deliver shares of PNMR’s common stock in respect of the remainder, if any, of PNMR’s conversion obligation in excess of the aggregate principal amount of the Convertible Notes being converted. The conversion rate for the Convertible Notes will initially be 22.4911 shares of PNMR’s common stock per $1,000 principal amount of the Convertible Notes, equivalent to an initial conversion price of $44.46 per share of common stock. The initial conversion price of the Convertible Notes represents a conversion premium of 17.5% above the last reported sale price of PNMR’s common stock on June 4, 2024. The conversion rate and the corresponding conversion price will be subject to adjustment by certain events such as increased dividends but will not adjust for any accrued or unpaid interest. In addition, following certain corporate events that occur prior to the maturity date of the Convertible Notes or if PNMR delivers a notice of a special event redemption, PNMR will, in certain circumstances, increase the conversion rate for a holder that elects to convert its Convertible Notes in connection with such a corporate event or such notice of special event redemption, as the case may be. PNMR issued the Convertible Notes pursuant to an indenture (the “Convertible Notes Indenture”) dated as of June 10, 2024 between PNMR and Computershare Trust Company, N.A., as trustee. The Convertible Notes are subject to continuing compliance with the representations, warranties, and covenants set forth in the Convertible Notes Indenture, which include the customary covenants discussed above. In the event of a fundamental change, as defined in the Convertible Notes Indenture, PNMR may be required to repurchase, for cash, the aggregate principal amount of Convertible Notes plus accrued interest. PNMR may not redeem the Convertible notes prior to June 6, 2029 except upon the occurrence of a special event as defined in the Convertible Notes Indenture. So long as no event of default with respect to the Convertible Notes has occurred and is continuing, PNMR may, at its option, defer interest payments on the Convertible Notes on one or more occasions for up to 20 consecutive semi-annual interest payment periods. During any deferral period, interest on the Convertible Notes will continue to accrue at the then-applicable interest rate on the Convertible Notes. In addition, during any deferral period, interest on deferred interest will accrue at the then-applicable interest rate on the Convertible Notes, compounded semi-annually, to the extent permitted by applicable law. At December 31, 2023, PNM had outstanding $37.0 million of 3.00% PCRBs and $125.0 million of 1.15% PCRBs issued by the City of Farmington, New Mexico with a mandatory remarketing date of June 1, 2024 and final maturities of June 2040 and $36.0 million of 3.00% PCRBs issued by Maricopa County, Arizona with a mandatory remarketing date of June 1, 2024 and a final maturity of January 2038. On June 3, 2024, PNM remarketed these PCRBs aggregating $198.0 million to new investors at 3.875% with a mandatory tender date of June 1, 2029. On March 28, 2024, TNMP entered into an agreement (the “TNMP 2024 Bond Purchase Agreement”) with institutional investors for the sale of $285.0 million aggregate principal amount of four series of TNMP first mortgage bonds (the “TNMP 2024 Bonds”) offered in private placement transactions. TNMP issued the first two series on March 28, 2024, consisting of $32.0 million at a 5.26% interest rate, due March 28, 2029, and $85.0 million at a 5.55% interest rate, due March 28, 2036. The third and fourth series were issued on July 1, 2024, consisting of $40.0 million at a 5.65% interest rate, due July 1, 2039, and $128.0 million at a 5.79% interest rate, due July 1, 2054. The proceeds were used to repay existing debt, including the $80.0 million of 4.03% TNMP FMBs that were due July 2024 and borrowings under the TNMP Revolving Credit Facility, for funding of capital expenditures, and for other corporate purposes. The TNMP 2024 Bonds are subject to continuing compliance with the representations, warranties and covenants set forth in the supplemental indentures governing the TNMP 2024 Bonds. The terms of the supplemental indentures governing the TNMP 2024 Bonds include the customary covenants discussed above. In the event of certain changes of control of PNMR or TNMP, TNMP will be required to offer to prepay the TNMP 2024 Bonds at par. TNMP has the right to redeem any or all of the TNMP 2024 Bonds prior to their maturity, subject to payment of a customary make-whole premium. On June 30, 2023, PNMR entered into a $500.0 million term loan agreement (the “PNMR 2023 Term Loan”) among PNMR, the lenders party thereto, and Wells Fargo Bank, N.A., as administrative agent. The proceeds were used to prepay an equal amount of the PNMR 2021 Delayed Draw Term Loan, without penalty. The PNMR 2023 Term Loan has a balance of $410.0 million, bears interest at a variable rate, which was 6.79% at June 30, 2024, and matures on June 30, 2026. At December 31, 2022, PNM had $130.0 million of 1.10% PCRBs outstanding with a mandatory remarketing date of June 1, 2023, issued by the City of Farmington, New Mexico with a final maturity of June 2040. On June 1, 2023, PNM remarketed the $130.0 million to new investors at 3.90% with a mandatory tender date of June 1, 2028. At December 31, 2022, PNM had $55.0 million aggregate principal amount of its 3.15% SUNs outstanding due May 2023. On May 15, 2023, PNM repaid the $55.0 million 3.15% SUNs. On April 28, 2023, PNM entered into an agreement (the “PNM 2023 Note Purchase Agreement”) with institutional investors for the sale and issuance of $200.0 million aggregate principal amount of two series of SUNs (the “PNM 2023 SUNs”) offered in private placement transactions. The PNM 2023 SUNs were issued on April 28, 2023. PNM issued $150.0 million of the PNM 2023 SUNs at 5.51%, due April 28, 2035, and another $50.0 million at 5.92%, due April 28, 2053. Proceeds from the PNM 2023 SUNs were used to repay borrowings under the PNM Revolving Credit Facility and the PNM New Mexico Credit Facility, for funding of capital expenditures, and for general corporate purposes. The PNM 2023 Note Purchase Agreement includes the customary covenants discussed above. In the event of a change of control of PNM, PNM will be required to offer to prepay the PNM 2023 SUNs at par. PNM has the right to redeem any or all of the PNM 2023 SUNs prior to their maturities, subject to payment of a customary make-whole premium. On April 28, 2023, TNMP entered into an agreement (the “TNMP 2023 Bond Purchase Agreement”) with institutional investors for the sale of $185.0 million aggregate principal amount of two series of TNMP first mortgage bonds (the “TNMP 2023 Bonds”) offered in private placement transactions. TNMP issued the first series of $130.0 million on April 28, 2023, at a 5.01% interest rate, due April 28, 2033. The second series of $55.0 million was issued on July 28, 2023, at a 5.47% interest rate, due July 28, 2053. The proceeds were used to repay borrowings under the TNMP Revolving Credit Facility, for funding of capital expenditures, and for other corporate purposes. The TNMP 2023 Bonds are subject to continuing compliance with the representations, warranties and covenants set forth in the supplemental indentures governing the TNMP 2023 Bonds. The terms of the supplemental indentures governing the TNMP 2023 Bonds include the customary covenants discussed above. In the event of certain changes of control of PNMR or TNMP, TNMP will be required to offer to prepay the TNMP 2023 Bonds at par. TNMP has the right to redeem any or all of the TNMP 2023 Bonds prior to their maturity, subject to payment of a customary make-whole premium. On November 10, 2022, PNMR entered into a distribution agreement with BofA Securities, Inc., MUFG Securities Americas Inc. and Wells Fargo Securities, LLC, as sales agents and Bank of America, N.A., MUFG Securities EMEA plc and Wells Fargo Bank, N.A., as forward purchasers, pursuant to which the Company may sell, from time to time, up to an aggregate sales price of $200.0 million of its common stock, no par value, through the sales agents (the “PNMR 2022 ATM Program”). Sales of the shares made pursuant to the distribution agreement may be made in “at the market offerings” as defined in Rule 415 of the Securities Act. PNMR did not receive any proceeds upon the execution of this agreement. Throughout 2023, PNMR entered into the forward sale agreements listed below, for the sale of shares of PNMR common stock. On December 15, 2023, PNMR physically settled the forward purchases under the PNMR 2022 ATM Program and used the proceeds to repay borrowings under the PNMR Revolving Credit Facility and for other corporate purposes. Gross cash proceeds shown below were reduced by $1.0 million in issuance costs resulting in net cash proceeds of $198.2 million. Forward completion Initial forward price Shares Settlement price Settlement amount (in thousands) March 15, 2023 $ 48.49 504,452 $ 49.00 $ 24,720 March 20, 2023 48.30 528,082 48.78 25,758 May 30, 2023 47.56 244,639 47.99 11,741 June 30, 2023 44.87 804,477 45.07 36,257 September 26, 2023 44.03 2,283,860 44.11 100,734 4,365,510 $ 199,210 At June 30, 2024, variable interest rates were 6.39% on the PNMR 2021 Delayed-Draw Term Loan that matures in May 2025, 6.79% on the PNMR 2023 Term Loan that matures in June 2026, and 6.33% on the PNM 2024 Term Loan that matures in November 2025. Hedging Arrangements PNMR has entered into hedging agreements that establish a fixed rate for the indicated amount of variable rate debt, above which a customary spread is applied, which is subject to change if there is a change in PNMR’s credit rating. As of June 30, 2024, PNMR’s hedging agreements are as follows: Variable Rate Established Effective Date Maturity Date Debt Hedged Fixed Rate (In millions) (Percent) January 1, 2024 December 31, 2024 $ 100.0 3.32 % January 1, 2024 December 31, 2024 100.0 3.32 January 1, 2024 December 31, 2024 100.0 3.38 January 1, 2024 December 31, 2024 150.0 3.62 January 1, 2024 December 31, 2024 150.0 3.57 January 1, 2025 December 31, 2025 100.0 4.18 January 1, 2025 December 31, 2025 100.0 4.18 January 1, 2025 December 31, 2025 100.0 3.99 These hedge agreements are accounted for as cash flow hedges. The fair value of these hedges was a gain of $6.2 million at June 30, 2024. A fair value gain of $5.3 million is included in Other current assets and $0.9 million is included in Other deferred charges on the Condensed Consolidated Balance Sheets. The fair value was determined using Level 2 inputs under GAAP, including using forward SOFR curves under the mid-market convention to discount cash flows over the remaining term of the agreements. Short-term Debt and Liquidity As of June 30, 2024, the PNMR Revolving Credit Facility had a financing capacity of $300.0 million and the PNM Revolving Credit Facility had a financing capacity of $400.0 million. On April 1, 2024, PNMR and PNM amended their respective revolving credit facilities, extending their maturity to March 30, 2029, with two one-year extension options that, if exercised, would extend the maturity to March 2031, subject to approval by a majority of the lenders. PNM also has the $40.0 million PNM New Mexico Credit Facility with a maturity of May 20, 2026. As of June 30, 2024, the TNMP Revolving Credit Facility had a capacity of $200.0 million. On April 1, 2024, TNMP entered into a new $200.0 million Revolving Credit Facility that replaced the $100.0 million Revolving Credit Facility. The new $200.0 million Revolving Credit Facility is secured by $200.0 million aggregate principal amount of TNMP first mortgage bonds and has a maturity of March 30, 2029, with two one-year extension options that, if exercised, would extend the maturity to March 2031, subject to approval by a majority of the lenders. Variable interest rates under the PNMR, PNM, and TNMP revolving credit facilities are based on SOFR. Short-term debt outstanding consists of: June 30, 2024 December 31, 2023 Balance Outstanding Weighted Average Interest Rate Balance Outstanding Weighted Average Interest Rate (In thousands) (In thousands) PNM: PNM Revolving Credit Facility $ 30,600 6.67% $ 107,500 6.69% PNM New Mexico Credit Facility 40,000 6.69 30,000 6.71 70,600 137,500 TNMP Revolving Credit Facility 100,600 6.31 55,100 6.32 PNMR Revolving Credit Facility 155,200 6.93 69,300 6.96 $ 326,400 $ 261,900 In addition to the above borrowings, PNMR, PNM, and TNMP had letters of credit outstanding of $3.1 million, zero, and zero at June 30, 2024 that reduce the available capacity under their respective revolving credit facilities. PNMR also had $30.3 million of letters of credit outstanding under the WFB LOC Facility. The above table excludes intercompany debt. As of June 30, 2024 and December 31, 2023, neither PNM nor TNMP had any intercompany borrowings from PNMR. PNMR Development had zero and $2.3 million in short-term borrowings outstanding from PNMR at June 30, 2024 and December 31, 2023. PNMR had no intercompany borrowings from PNMR Development at June 30, 2024 or December 31, 2023. PNM has $2.5 million and $3.4 million in scheduled payments due for the ETBC I Securitized Bonds in August 2024 and February 2025 and $104.0 million of SUNs that are due in May 2025. TNMP had $80.0 million of FMBs that were due in July 2024 and were repaid with the proceeds from the TNMP 2024 Bonds that were issued on July 1, 2024. PNMR has $51.0 million outstanding under the PNMR 2021 Delayed Draw Term Loan that matures in May 2025. The Company’s debt arrangements have various maturities and expiration dates. Additional information on debt maturities is contained in Note 7 of the Notes to Consolidated Financial Statements in the 2023 Annual Reports on Form 10-K. |
Pension and Other Postretiremen
Pension and Other Postretirement Benefit Plans | 6 Months Ended |
Jun. 30, 2024 | |
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 2023 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 June 30, Pension Plan OPEB Plan Executive Retirement Program 2024 2023 2024 2023 2024 2023 (In thousands) Components of Net Periodic Benefit Cost Service cost $ — $ — $ — $ — $ — $ — Interest cost 5,428 5,914 597 676 124 135 Expected return on plan assets (7,757) (7,299) (1,391) (1,243) — — Amortization of net loss 2,662 2,645 — — 50 38 Amortization of prior service cost — — — — — — Net Periodic Benefit Cost (Income) $ 333 $ 1,260 $ (794) $ (567) $ 174 $ 173 Six Months Ended June 30, Pension Plan OPEB Plan Executive Retirement Program 2024 2023 2024 2023 2024 2023 (In thousands) Components of Net Periodic Benefit Cost Service cost $ — $ — $ — $ — $ — $ — Interest cost 10,855 11,827 1,194 1,352 248 270 Expected return on plan assets (15,514) (14,598) (2,782) (2,485) — — Amortization of net loss 5,323 5,291 — — 100 76 Amortization of prior service cost — — — — — — Net Periodic Benefit Cost (Income) $ 664 $ 2,520 $ (1,588) $ (1,133) $ 348 $ 346 PNM did not make any contributions to its pension plan trust in the three and six months ended June 30, 2024 and 2023 and does not anticipate making any contributions to the pension plan in 2024 through 2028 based on current law, funding requirements, and estimates of portfolio performance. Funding assumptions were developed using a discount rate of 5.5%. 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 and six months ended June 30, 2024 and 2023, however, a portion of the disbursements attributable to the OPEB trust is 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 less than $0.1 million and less than $0.1 million for the three and six months ended June 30, 2024 and were less than $0.1 million and $0.1 million for the three and six months ended June 30, 2023. These payments are expected to total $0.2 million in 2024 and $10.1 million for 2025-2028. Disbursements under the executive retirement program, which are funded by PNM and considered to be contributions to the plan, were $0.3 million and $0.6 million in the three and six months ended June 30, 2024 and $0.2 million and $0.6 million in the three and six months ended June 30, 2023 and are expected to total $1.2 million during 2024 and $4.4 million for 2025-2028. TNMP Plans The following table presents the components of the TNMP Plans’ net periodic benefit cost: Three Months Ended June 30, Pension Plan OPEB Plan Executive Retirement Program 2024 2023 2024 2023 2024 2023 (In thousands) Components of Net Periodic Benefit Cost Service cost $ — $ — $ 6 $ 6 $ — $ — Interest cost 554 600 97 107 4 3 Expected return on plan assets (687) (675) (128) (121) — — Amortization of net (gain) loss 139 109 (160) (190) — — Amortization of prior service cost — — — — — — Net Periodic Benefit Cost (Income) $ 6 $ 34 $ (185) $ (198) $ 4 $ 3 Six Months Ended June 30, Pension Plan OPEB Plan Executive Retirement Program 2024 2023 2024 2023 2024 2023 (In thousands) Components of Net Periodic Benefit Cost Service cost $ — $ — $ 11 $ 11 $ — $ — Interest cost 1,107 1,201 193 213 8 6 Expected return on plan assets (1,374) (1,349) (257) (241) — — Amortization of net (gain) loss 278 219 (321) (380) — — Amortization of prior service cost — — — — — — Net Periodic Benefit Cost (Income) $ 11 $ 71 $ (374) $ (397) $ 8 $ 6 |
Commitments and Contingencies
Commitments and Contingencies | 6 Months Ended |
Jun. 30, 2024 | |
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 estimatable. The actual outcomes of the items listed below could ultimately differ from the judgments made and the differences could be material. The Company cannot make any assurances that the amount of reserves or potential insurance coverage will be sufficient to cover the cash obligations that might be incurred as a result of litigation or regulatory proceedings. Except as otherwise disclosed, the Company does not expect that any known lawsuits, environmental costs, or commitments will have a material effect on its financial condition, results of operations, or cash flows. Additional information concerning commitments and contingencies is contained in Note 16 of the Notes to Consolidated Financial Statements in the 2023 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. APS and the DOE entered into a settlement agreement, subsequently extended, that established a process for the payment of claims for costs incurred through December 31, 2025. Under the settlement agreement, APS must submit claims annually for payment of allowable costs. PNM records estimated claims on a quarterly basis. The benefit from the claims is passed through to customers under the FPPAC. PNM estimates that it will incur approximately $55.6 million (in 2023 dollars) for its share of the costs related to the on-site interim storage of spent nuclear fuel at PVNGS for the remaining term of the operating licenses. PNM accrues these costs as a component of fuel expense as the nuclear fuel is consumed. At June 30, 2024 and December 31, 2023, PNM had a liability for interim storage costs of $12.2 million and $11.0 million, which is included in other deferred credits. PVNGS has sufficient capacity at its on-site Independent Spent Fuel Storage Installation (“ISFSI”) to store all of the nuclear fuel that will be irradiated during the initial operating license period, which ends in December 2027. Additionally, PVNGS has sufficient capacity at its on-site ISFSI to store a portion of the fuel that will be irradiated during the period of extended operation, which ends in November 2047. If uncertainties regarding the U.S. government’s obligation to accept and store spent fuel are not favorably resolved, APS will evaluate alternative storage solutions that may obviate the need to expand the ISFSI to accommodate all of the fuel that will be irradiated during the period of extended operation. The Energy Transition Act 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 requires utilities operating in New Mexico to have renewable portfolios equal to 40% by 2025, 50% by 2030, 80% by 2040, and 100% zero-carbon energy by 2045. The ETA also allows for the recovery of undepreciated investments and decommissioning costs related to qualifying EGUs that the NMPRC has required be removed from retail jurisdictional rates, provided replacement resources to be included in retail rates have lower or zero-carbon emissions. The ETA requires the NMPRC to review and approve utilities’ annual renewable portfolio plans to ensure compliance with the RPS. 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 are repaid by a non-bypassable charge paid by all customers of the issuing utility. These customer charges are subject to an adjustment mechanism designed to provide for timely and complete payment of principal and interest due under the energy transition bonds. The ETA also provides that utilities must obtain NMPRC approval of competitively procured replacement resources that shall be evaluated based on their cost, economic development opportunity, ability to provide jobs with comparable pay and benefits to those lost upon retirement of the facility, and that do not exceed emissions thresholds specified in the ETA. In determining whether to approve replacement resources, the NMPRC must give preference to resources with the least environmental impacts, those with higher ratios of capital costs to fuel costs, and those located in the school district of the abandoned facility. The ETA also provides for the procurement of energy storage facilities and gives utilities discretion to maintain, control, and operate these systems to ensure reliable and efficient service. The ETA has had and will have a significant impact on PNM’s future generation portfolio, including PNM’s retirement of SJGS in 2022. PNM cannot predict the full impact of the ETA with respect to Four Corners or the outcome of its future generating resource abandonment and replacement resource filings with the NMPRC. See additional discussion in Note 12 of PNM’s Four Corners Abandonment Application. The Clean Air Act Regional Haze Pursuant to the CAA, states are required to establish goals for improving visibility in national parks and wilderness areas (also known as Class I areas) and to develop long-term strategies for reducing emissions of air pollutants that cause visibility impairment in their own states and for preventing degradation in other states. States must establish a series of interim goals to ensure continued progress by adopting a new SIP every ten years. In the first SIP planning period, states were required to conduct BART determinations for certain covered facilities, including utility boilers, built between 1962 and 1977 that have the potential to emit more than 250 tons per year of visibility impairing pollution. For all future SIP planning periods, states must evaluate whether additional emissions reduction measures may be needed to continue making reasonable progress toward natural visibility conditions. In 2017, EPA published revisions to the regional haze rule in the Federal Register that delayed the due date for the next cycle of SIPs from 2019 to 2021 and altered the planning process that states must employ in determining whether to impose “reasonable progress” emission reduction measures. EPA’s new rule was challenged by numerous parties, but the litigation was held in abeyance after EPA granted various petitions for reconsideration. In 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. In 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 in 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 retired its share of SJGS in 2022. On August 30, 2022, EPA published in the Federal Register an official “Finding of Failure to Submit” for states, including New Mexico, that have not yet submitted a round 2 regional haze SIP. This action by EPA starts a 2-year clock for it to issue a Federal Implementation Plan (FIP). NMED’s current timeline indicates the proposed SIP will be submitted to EPA by Fall 2024. Carbon Dioxide Emissions In 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 challenged 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 reevaluated, which was granted. In 2019, EPA repealed the Clean Power Plan, promulgated the ACE Rule, and revised the implementing regulations for all emission guidelines. EPA set the 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. 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., vacating the ACE Rule. While the DC Circuit rejected the ACE Rule, it did not reinstate the Clean Power Plan. Rather, the DC Circuit granted an EPA motion asking the court to 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. Numerous parties sought review by the US Supreme Court, and on June 30, 2022, the Court held that the “generation shifting” approach in the Clean Power Plan exceeded the powers granted to EPA by Congress, though the Court did not address the related issue of whether Section 111 of the CAA only authorizes EPA to require measures that can be implemented entirely within the fence line at an individual source. Of broader significance in administrative law, the Court’s opinion expressly invoked the “major question” doctrine, which requires rules involving issues of “vast economic or political significance” to be supported by clear statutory authorization. In cases where there is no clear statement of authority, courts need not defer to the agency’s statutory interpretation on “major questions.” The decision sets legal precedent for future rulemakings by EPA and other federal regulatory agencies whereby the agencies’ authority may be limited based upon similar reasoning. The litigation over the Carbon Pollution Standards remains held in abeyance but could be reactivated by the parties upon a determination by the court that reconsideration of the rule has concluded. On May 23, 2023, EPA published in the Federal Register proposed regulatory actions under CAA sections 111(b) and (d) to replace the Clean Power Plan and the ACE Rule, and EPA finalized those rules on May 9, 2024. The final rules include revised new source performance standards under Section 111(b) for all new natural gas-fired combustion turbines and emission guidelines under Section 111(d) requiring states to develop standards of performance for greenhouse gas emissions from existing fossil-fuel-fired electric steam generating units. In the final rules, EPA determined that the standards for existing coal- or gas-fired steam generating units must be based on the use of either CCS (long-term) or natural gas co-firing (medium-term), or exempt from the rule via early retirement, and the standards for new combustion turbines must be based on CCS (base load), efficient simple cycle design (intermediate load), or lower-emitting fuels (low load). We are currently determining what impact, if any, the final rule will have on our business, results of operation, and financial condition. Because the CAA 111 rule does not contain provisions for existing natural gas units, on March 26, 2024, EPA announced it was opening a non-regulatory docket and issued framing questions to gather input about ways to design a stronger, more durable approach to GHG regulation of existing gas combustion turbines. The docket was open for public comment from March 26, 2024 to May 28, 2024 and the agency held a policy forum to bring stakeholders together to share ideas with EPA and others. The agency has indicated that it plans to re-propose emission guidelines for existing natural gas units in December 2024. 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 have or may occur as a result of legislation or regulation under the Biden Administration is ongoing. We are currently determining what impact, if any, the final rules will have on our business, results of operation, and financial condition. National Ambient Air Quality Standards (“NAAQS”) The CAA requires EPA to set NAAQS for pollutants reasonably anticipated to endanger public health or welfare. EPA has set NAAQS for certain pollutants, including NOx, SO 2 , ozone, and particulate matter. NOx Standard – In 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. The State of New Mexico has attained the current NOx NAAQS standards. SO 2 Standard – In 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. 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. All areas of New Mexico have been designated attainment/unclassifiable through four rounds of designations by EPA. Ozone Standard – In 2015, EPA finalized the new ozone NAAQS and lowered both the primary and secondary 8-hour standard from 75 to 70 parts per billion. With ozone standards becoming more stringent, fossil-fueled generation units will come under increasing pressure to reduce emissions of NOx and volatile organic compounds since these are the pollutants that form ground-level ozone. 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. 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. On August 21, 2023, EPA announced an entirely new review of the ozone standard that will incorporate the work to date on the reconsideration, likely indicating a delay in the schedule for a decision on whether the standard should be revised. On January 3, 2024, EPA filed in the DC Circuit an unopposed motion for voluntary remand, without vacatur, of EPA’s final rule retaining the current ozone NAAQS. The filing was made in the consolidated cases challenging the 2020 ozone NAAQS rule. During 2017 and 2018, EPA released rules establishing area designations for ozone. In those rules, San Juan County, New Mexico, where Four Corners is located, is designated as attainment/unclassifiable and only a small area in Doña Ana County, New Mexico is designated as marginal non-attainment. Although Afton Generating Station is located in Doña Ana County, it is not located within the small area designated as non-attainment for the 2015 ozone standard. The rule became effective May 8, 2018. 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. On October 15, 2021, EPA proposed to approve New Mexico’s SIP to meet the emissions inventory and statement requirements of the CAA for the Sunland Park Ozone Non-Attainment Area. 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, EPA is statutorily obligated to complete its review of the ozone standards by December 2025. PNM cannot predict the outcome of this matter. In 2019, EPA issued findings that several states, including New Mexico, had failed to submit interstate transport SIPs for the 2015 8-hour ozone NAAQS, triggering an obligation for EPA to issue a federal implementation plan within two years. In response, NMED submitted a Good Neighbor SIP on July 27, 2021 that demonstrates that there are no significant contributions from New Mexico to downwind problems in meeting the federal ozone standard. Nevertheless, when EPA failed to approve the SIP or issue a FIP within two years of the finding of failure to submit, multiple parties filed a deadline suit against EPA, resulting in a consent decree requiring EPA to issue a FIP or approve a SIP for New Mexico by a deadline of no later than June 1, 2024, which was later extended to August 30, 2024. On March 15, 2023, EPA Administrator Regan signed a final action imposing a FIP on multiple states but did not include a FIP for New Mexico because EPA had not proposed a FIP for the state because the most up to date modeling available at proposal confirmed the state did not contribute to downwind ozone nonattainment or maintenance areas. However, the updated modeling EPA used in the final rule indicated that New Mexico may be significantly contributing to one or more non-attainment or maintenance areas. In light of that modeling result, on February 16, 2024, the EPA published a proposed rule partially disapproving the SIPs for New Mexico and four other states (Arizona, Iowa, Kansas, Tennessee) and expanding the Good Neighbor Federal Implementation Plan (FIP) to apply to these states. In denying the NMED-submitted SIP, the EPA concluded that the SIP was incomplete and did not contain the necessary provisions to prohibit emission from sources within the state from interfering with maintenance of the 2015 ozone NAAQS in downwind areas, specifically a maintenance-only receptor in the El Paso area. The FIP aspect of the proposed rule would require fossil fuel-fired power plants in these five states to participate in an allowance-based ozone season NOX emissions trading program beginning in 2025. Comments on the proposed rule were due May 16, 2024. PNM submitted company-specific comments on the proposal on the due date. EPA is targeting September 2024 for a final rule. Of importance in considering the possibility of a Good Neighbor FIP for New Mexico, are the many court challenges to EPA’s earlier rulemaking disapproving SIPs and imposing a FIP on 23 states. Numerous courts of appeal have already determined that those challenges are likely to succeed and therefore issued stays of EPA’s SIP disapprovals for about half of the states subject to the FIP. In light of those stays, the US Supreme Court granted a stay of the Good Neighbor FIP issued to the 23 states on June 27, 2024, pending the disposition of the applicants petitions for review at the U.S. Court of Appeals for the D.C. Circuit. This court activity may impact the viability of EPA’s multi-state trading program as to New Mexico. PM Standard – On January 27, 2023, EPA published, in the Federal Register, a proposal to lower the annual fine PM standard to between 9-10 µg/m3 but retain the rest of its PM standards, including the current daily fine particulate matter standard, the daily coarse particulate matter standard, and the secondary PM standards. The final rule was published on March 6, 2024, lowering the primary annual PM 2.5 NAAQS to 9 ug/m3. The rule is effective May 6, 2024. States will have until March 2032 to attain compliance with the new standard. During the multi-year implementation process, the NMED will designate attainment/nonattainment areas by March 6, 2026, and submit a State Implementation Plan to EPA by September 6, 2027. This implementation process also applies to the Albuquerque-Bernalillo County Environmental Health Department who may combine efforts with NMED. Bernalillo County does not currently meet the 9 ug/m3 standard which may impact future air permitting activities at Rio Bravo and Reeves Generating Stations if the county is designated as nonattainment. Beginning May 6, 2024, the new standard will be used when conducting required modeling for permit applications and revisions. Although the lower standard is expected to result in new nonattainment areas throughout the country and could prompt additional PM control requirements, PNM cannot predict the impacts of the outcome of future rulemaking. Cooling Water Intake Structures In 2014, EPA issued a rule establishing national standards for certain cooling water intake structures at existing power plants and other facilities under the Clean Water Act to protect fish and other aquatic organisms by minimizing impingement mortality (the capture of aquatic wildlife on intake structures or against screens) and entrainment mortality (the capture of fish or shellfish in water flow entering and passing through intake structures). To minimize impingement mortality, the rule provides operators of facilities, such as Four Corners, seven options for meeting Best Technology Available (“BTA”) standards for reducing impingement. The permitting authority must establish the BTA for entrainment on a site-specific basis, taking into consideration an array of factors, including endangered species and social costs and benefits. Affected sources must submit source water baseline characterization data to the permitting authority to assist in the 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. In 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. 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. 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. 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 in 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. The parties subsequently executed the settlement agreement as of May 2, 2022. Under the settlement, the associated case was administratively closed through September 6, 2023, during which time a third-party consultant spent 12 months sampling discharges from Four Corners and EPA spent three months completing an analysis. On December 1, 2023, EPA issued a modification, effective December 31, 2023, to the NPDES permit issued on November 9, 2020. The modification applies to permit elements related to effluent discharge. PNM cannot predict whether the analysis under the settlement agreement will result in changes to the NPDES permit but does not anticipate that it will have a material impact on PNM’s financial position, results of operations, or cash flows. Effluent Limitation Guidelines In 2013, EPA published proposed revised wastewater ELG establishing technology-based wastewater discharge limitations for fossil fuel-fired electric power plants. EPA signed the final Steam Electric ELG rule in 2015. The final rule, which became effective on January 4, 2016, phased in the new, more stringent requirements in the form of effluent limits for arsenic, mercury, selenium, and nitrogen for wastewater discharged from wet scrubber systems and zero discharge of pollutants in ash transport water that must be incorporated into plants’ NPDES permits. The 2015 rule required each plant to comply between 2018 and 2023 depending on when it needs a new or revised NPDES permit. The Steam Electric ELG rule was challenged in the U.S. Court of Appeals for the Fifth Circuit by numerous parties. In 2017, EPA signe |
Regulatory and Rate Matters
Regulatory and Rate Matters | 6 Months Ended |
Jun. 30, 2024 | |
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 2023 Annual Reports on Form 10-K. PNM New Mexico General Rate Case 2024 Rate Change On December 5, 2022, PNM filed an application with the NMPRC for a general increase in retail electric rates including recovery on total rate base of $2.7 billion based on a calendar year 2024 FTY, an increase of $63.8 million in retail non-fuel revenues, and an ROE 10.25%. The application also proposed ratemaking treatment of PVNGS Leased Interest and testimony supporting the prudence of PNM’s decisions to renew the five leases and repurchase 64.1 MW of PVNGS Unit 2 capacity. On January 3, 2024, the NMPRC issued a final order authorizing PNM to implement an increase in non-fuel base rates of $15.3 million, effective for service beginning January 15, 2024. Major components of the difference compared to PNM’s application include: • A ROE of 9.26%. • A capital structure of 49.61% equity, 50.10% debt, and 0.29% preferred stock. • Finding of imprudence regarding PNM’s decision to remain in Four Corners and a remedy for the imprudence resulting in a disallowance of $81.0 million to PNM’s total Four Corners net book value. • Approval of $51.3 million of PNM’s requested $96.3 million regulatory asset for PVNGS undepreciated investments, but disallowance of a return on the remaining $45.0 million or any CWIP associated with it. • Requiring that the $38.4 million regulatory liability associated with leased capacity at PVNGS after the Unit 1 lease expired on January 15, 2023, be returned to ratepayers over two years through a separate rate rider. • The approval of new depreciation rates, reflecting shorter useful lives, of PNM’s gas plants with service lives and depreciable lives extending beyond January 1, 2045, which would include PNM’s La Luz and Luna generating stations. • The approval of PNM’s TOD pilot program, with a requirement to make annual compliance filings and to adjust certain rate schedules. For additional details related to the initial application, see Note 17 of the Notes to Consolidated Financial Statements in the 2023 Annual Reports on Form 10-K. In the year ended December 31, 2023, PNM evaluated the outcome of the NMPRC final order in the 2024 Rate Change and recorded a regulatory disallowance of $55.5 million on the Consolidated Statement of Earnings and a corresponding reduction to Utility Plant, after accounting for previous impairments, to reflect the remedy adopted in the Final Order for Four Corners. In addition, PNM recorded a reduction to electric operating revenues of $38.4 million with a corresponding current regulatory liability of $19.2 million and a deferred regulatory liability of $19.2 million for the PVNGS rate refunds that will be returned to customers over a two-year period. PNM also recorded a regulatory disallowance of $8.2 million on the Consolidated Statement of Earnings and a corresponding reduction to Utility Plant for the disallowance of CWIP from PVNGS. In March 2024, notice of appeals were separately filed with the NM Supreme Court by NEE and PNM, and a joint notice of appeal was filed by the NM Department of Justice, Bernalillo County, and ABCWUA. Statements of issues from appellants were filed on June 5, 2024. PNM took issue with the NMPRC’s ruling on capital structure; other appellants primarily challenged the NMPRC rulings related to Four Corners and Palo Verde cost recovery. PNM cannot predict the outcome of this matter. 2025 Rate Request On June 14, 2024, PNM filed an application with the NMPRC for a general increase in retail electric rates. The proposed base rate changes would be implemented in two phases, with the first phase effective July 1, 2025 and the second phase effective January 1, 2026. Key aspects of PNM’s request include: • Recovery on total rate base of $3.0 billion, based on a FTY with the 12 months ending June 30, 2026 • An increase of $174.3 million in retail revenues, comprised of a $92.2 million increase in base rates and a $82.1 million increase in revenues collected under PNM’s FPPAC • Drivers of revenue deficiency: ◦ Needed investments across distribution, transmission, and generation facilities to ensure safe, reliable delivery of electricity ◦ Increased operations and maintenance expenses to meet operational needs including wildfire risk mitigation ◦ Costs associated with ESAs, previously approved by the NMPRC, necessary to serve our customers ◦ ROE of 10.45% ◦ Proposed capital structure of 52.5% equity ◦ An increased cost of borrowing ◦ Adjustments to Four Corners depreciation rates to recover remaining plant investments through July 2031, the expected abandonment date of the facility • Proposed ratemaking treatment of ESAs to be recovered through PNM’s FPPAC beginning July 1, 2025 The NMPRC has suspended PNM’s advice notice in the case for the statutory suspension period, until July 15, 2025 and the hearing examiners set a procedural schedule with a hearing to begin February 17, 2025. Renewable Energy Portfolio Standard As discussed in Note 11, the ETA amends the REA including removal of diversity requirements and certain customer caps and exemptions relating to the application of the RPS under the REA. The REA provides for streamlined proceedings for approval of utilities’ renewable energy procurement plans, assures that utilities recover costs incurred consistent with approved procurement plans, and requires the NMPRC to establish a Reasonable Cost Threshold (“RCT”) for the procurement of renewable resources to prevent excessive costs being added to rates. The ETA sets a RCT of $60 per MWh, adjusted for inflation, using an average annual levelized resource cost basis. PNM makes renewable procurements consistent with the NMPRC approved plans and recovers certain renewable procurement costs from customers through the renewable energy rider billed on a KWh basis. Included in PNM’s approved procurement plans are the following renewable energy resources: • 158 MW of PNM-owned solar-PV facilities • A PPA through 2044 for the output of New Mexico Wind, having a current aggregate capacity of 200 MW, and a PPA through 2035 for the output of Red Mesa Wind, having an aggregate capacity of 102 MW • A PPA through 2040 for 140 MW of output from La Joya Wind II • A PPA through 2042 for the output of the Lightning Dock Geothermal facility with a capacity of 11 MW • Solar distributed generation, aggregating 295.7 MW at June 30, 2024, owned by customers or third parties from whom PNM purchases any net excess output and RECs The NMPRC has authorized PNM to recover certain renewable procurement costs through a rate rider billed on a per KWh basis. In its 2024 renewable energy procurement plan, which became effective on January 1, 2024, PNM proposed to collect $59.0 million for the year. PNM recorded revenues from the rider of $15.3 million and $30.6 million in the three and six months ended June 30, 2024 and $15.4 million and $34.0 million in the three and six months ended June 30, 2023. On June 3, 2024, PNM filed its renewable energy procurement plan for 2025 which proposes to collect $58.7 million for the year. PNM is not proposing any new resource procurements, and the plan states that existing projects are anticipated to exceed the applicable RPS standards of 2025, despite the standard doubling. 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 2023. 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 does not exceed seventy-five thousand dollars. On April 17, 2023, PNM filed an application for energy efficiency and load management programs to be offered in 2024, 2025, and 2026 (the “2024 Plan”). The 2024 Plan proposed to continue ten existing energy efficiency programs with modification and a total annual budget of $34.5 million in 2024, $35.4 million in 2025, and $36.5 million in 2026. The application also sought approval of an annual base incentive of 7.1% of the portfolio budget and a sliding scale that provides additional incentive for additional energy saved as a percentage of program cost, up to the maximum allowed by the energy efficiency rule which for PNM is 8.82%. On January 26, 2024, the hearing examiners in the case issued a RD. The RD largely approved PNM’s 2024 Plan but with modifications that include the pursuit of demand response resources, additional analysis in future filings, adjustments to certain energy efficiency programs, and modification of the incentive sliding scale cap to reflect a new maximum. On March 7, 2024, the NMPRC approved the RD in its entirety. 2020 Decoupling Petition As discussed above, the legislature amended the EUEA to, among other things, include a decoupling mechanism for disincentives. On May 28, 2020, PNM filed a petition for approval of a rate adjustment mechanism that would decouple the rates of its residential and small power rate classes. Decoupling is a rate design principle that severs the link between the recovery of fixed costs of the utility through volumetric charges. On July 13, 2020, NEE, ABCWUA, the City of Albuquerque, and Bernalillo County filed motions to dismiss the petition on the grounds that approving PNM’s proposed rate adjustment mechanism outside of a general rate case would result in retroactive ratemaking and piecemeal ratemaking. The motions to dismiss also alleged that PNM’s proposed rate adjustment mechanism is inconsistent with the EUEA. On October 2, 2020, PNM requested an order to vacate the public hearing, scheduled to begin October 13, 2020, and staying the proceeding until the NMPRC decides whether to entertain a petition to issue a declaratory order resolving the issues raised in the motions to dismiss. On October 7, 2020, the hearing examiner approved PNM’s request to stay the proceeding and vacate the public hearing and required PNM to file a petition for declaratory order by October 30, 2020. On October 30, 2020, PNM filed a petition for declaratory order asking the NMPRC to issue an order finding that full revenue decoupling is authorized by the EUEA. On November 4, 2020, ABCWUA and Bernalillo County jointly filed a competing petition asking the NMPRC to issue a declaratory order on the EUEA’s requirements related to disincentives. On March 17, 2021, the NMPRC issued an order granting the petitions for declaratory order, commencing a declaratory order proceeding to address the petitions and appointing a hearing examiner to preside over the declaratory order proceeding. On January 14, 2022, the hearing examiner issued a RD recommending the NMPRC find that the EUEA does not mandate the NMPRC to authorize or approve a full decoupling mechanism, defining full decoupling as limited to energy efficiency and load management measures and programs. The RD also states that a utility may request approval of a rate adjustment mechanism to remove regulatory disincentives to energy efficiency and load management measures and programs through a stand-alone petition, as part of the utility’s triennial energy efficiency application or a general rate case and that PNM is not otherwise precluded from petitioning for a rate adjustment mechanism prior to its next general rate case. Finally, the RD stated that the EUEA does not permit the NMPRC to reduce a utility’s ROE based on approval of a disincentive removal mechanism founded on removing regulatory disincentives to energy efficiency and load management measures and programs. The RD does not specifically prohibit a downward adjustment to a utility’s capital structure, based on approval of a disincentive removal mechanism. On April 27, 2022, the NMPRC issued an order adopting the RD in its entirety. On May 24, 2022, PNM filed a notice of appeal with the NM Supreme Court. The NM Supreme Court held oral arguments on November 13, 2023. On May 13, 2024, the NM Supreme Court issued a decision finding that the EUEA allows a utility to propose full decoupling mechanisms. The NM Supreme Court did not address the second issue regarding a downward adjustment to a utility’s capital structure based on approval of disincentive removal mechanism. 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 three years of that period. On September 14, 2022, the NMPRC adopted revisions to the IRP Rule. The new rule revamps and modernizes the planning process to accommodate increased stakeholder involvement. The IRP Rule establishes a collaborative facilitated process for a utility and stakeholders to agree on a statement of need for potential new or additional resources, as well as an action plan to guide procurement or development of resources to meet the stated need. A most-cost-effective portfolio of resources shall be derived from the statement of need analysis. The statement of need and action plan must be accepted before the utility begins the resource solicitation process pursuant to the IRP Rule. Following acceptance of the statement of need and action plan, a utility will provide the NMPRC and intervenors drafts of the request for proposals (“RFP”) and a timeline for issuing, receiving, evaluating, and ranking bids. The NMPRC will then appoint an Independent Monitor (“IM”) to oversee the RFP process, which allows for parties and the IM to comment on the RFP consistency with the IRP, after which the utility issues the RFP. Within 120 days of receiving bids the utility shall provide the IM with results including pricing and non-price evaluation criteria, ranking of bids, chosen portfolio and alternatives that also meet the needs; the IM then rules on the fairness of the RFP execution. Acceptance of the statement of need and action plan will not constitute a finding of prudency or pre-approval of costs associated with the additional resources. Following the RFP and IM processes, the utility may apply for approvals, and any costs incurred to implement the action plan will be considered in a general rate case and/or resource acquisition proceeding. On October 14, 2022, PNM and other investor-owned utilities filed motions for rehearing with the NMPRC. On October 26, 2022, the NMPRC issued an order partially granting and partially denying certain aspects of PNM’s and the other investor-owned utilities’ motions for rehearing. On November 2, 2022, the NMPRC adopted an amended IRP Rule. On December 2, 2022, PNM filed an appeal with the NM Supreme Court. Two other investor-owned utilities also separately filed appeals at the NM Supreme Court. On January 3, 2023, PNM and the two other investor-owned utilities filed statements of issues with the NM Supreme Court. Among other things, the investor-owned utilities question whether the IRP Rule exceeds the NMPRC authority by imposing unauthorized requirements on utilities and extending NMPRC jurisdiction through over-broad interpretation of the statutes and state that the IRP Rule is contrary to law in its provisions for NMPRC regulation of a utility’s resource procurement decision-making. On June 5, 2023, PNM and the other two investor-owned utilities filed their Joint Brief in Chief and request for oral arguments at the NM Supreme Court. The NM Supreme Court held oral arguments on May 13, 2024. PNM cannot predict the outcome of this matter. 2023 IRP On December 15, 2023, PNM filed its 2023 IRP with a continued focus on a carbon-free energy system by 2040. The plan highlights the need for the significant sustained addition of resources over the next two decades, replacing retiring or expiring capacity, meeting concurrent load growth, while reducing the carbon intensity of PNM’s portfolio. On April 4, 2024, the NMPRC accepted PNM’s 2023 IRP. On May 2, 2024, the NMPRC issued an order appointing an independent monitor who will report the results of PNM’s 2023 IRP. Four Corners Abandonment Application In 2020, PNM entered into the Four Corners Purchase and Sale Agreement with NTEC, pursuant to which PNM agreed to sell its 13% ownership interest (other than certain transmission assets) in Four Corners to NTEC, contingent upon NMPRC approval. In connection with the sale, PNM would make payments of $75.0 million to NTEC for relief from its obligations under the coal supply agreement for Four Corners after December 31, 2024. PNM made an initial payment to NTEC of $15.0 million in November 2020, subject to refund with interest upon termination of the Four Corners Purchase and Sale Agreement prior to closing. Under the terms of the Four Corners Purchase and Sale Agreement, upon receipt of the NMPRC approval, PNM was expected to make a final payment of $60.0 million. On January 8, 2021, PNM filed the Four Corners Abandonment Application, which sought NMPRC approval to exit PNM’s share of Four Corners as of December 31, 2024, and issuance of approximately $300 million of Securitized Bonds as provided by the ETA. On December 15, 2021, the NMPRC issued a final order denying approval of the Four Corners Abandonment Application and the corresponding request for issuance of securitized financing. On December 22, 2021, PNM filed a Notice of Appeal with the NM Supreme Court of the NMPRC decision to deny the application and on July 6, 2023, the NM Supreme Court affirmed the NMPRC decision concluding that the NMPRC reasonably and lawfully denied PNM’s application for abandonment. As a result of the NM Supreme Court's decision to uphold the NMPRC's denial, the Condensed Consolidated Statements of Earnings for the three and six months ended June 30, 2023 reflect a regulatory disallowance of $3.7 million. On April 23, 2024, PNM filed an interim notice informing the NMPRC that PNM’s updated analysis indicates it is in the interest of customers for PNM to remain as a participant in Four Corners until the expiration of the current coal supply agreement in 2031. PNM continues to work with the other Four Corners owners to update the necessary project agreements to reflect this continued participation. Summer Peak Resource Adequacy Beginning in 2021 PNM began providing notices of delays, as received from developers, and status updates to the NMPRC for the approved SJGS replacement resource projects as well as delays in replacement resources for the PVNGS leased capacity that expired in January 2023 and January 2024. While PNM continues to experience new system peaks, PNM’s generation resources performed sufficiently with no challenges to resource adequacy during the 2023 summer peak season. While some of the replacement resources have come online, other replacement resources have experienced additional developer delays and PNM has entered into additional firm energy market purchases necessary to meet customer load during the 2024 summer season. See Note 7. 2026 Resource Application On October 25, 2023, PNM filed an application with the NMPRC seeking approval of resources to be available for the 2026 summer peak. The application included a request for approval of a 100 MW solar PPA and three battery storage agreements of 100 MW, 100 MW, and 50 MW. In addition, PNM was seeking approval of a CCN for a 60 MW battery storage system to be owned by PNM. The resources were deemed necessary for PNM to safely and reliably meet its projected system load. A hearing was held on March 20 and 21, 2024. On May 3, 2024, the hearing examiner in the case issued a RD approving PNM’s requested resources. On May 30, 2024, the NMPRC approved the RD in its entirety. On July 9, 2024 a group of New Mexico legislators filed a petition with the NM Supreme Court requesting the court grant their motion for rehearing. Grid Modernization Application On October 3, 2022, in compliance with New Mexico Grid Modernization Statute, PNM filed its Grid Modernization Application with the NMPRC. The projects included in the Grid Modernization Application improve customers’ ability to customize their use of energy and ensure that customers, including low-income customers, are a top priority and will benefit consistent with the Grid Modernization Statute. PNM’s proposal to modernize its electricity grid through infrastructure and technology improvements also increases the efficiency, reliability, resilience, and security of PNM’s electric system. PNM’s application seeks approval of grid modernization investments of approximately $344 million for the first six years of a broader 11-year strategy. The proposed Grid Modernization Rider would recover capital costs, operating expenses, and taxes associated with the investments included in the Grid Modernization Application. PNM also requested authorization to create related regulatory assets and liabilities, permitting PNM to record costs incurred for the development and implementation of PNM’s plan between the requested approval of the application on July 1, 2023, and the implementation of the Grid Modernization Rider by September 1, 2023; undepreciated investments associated with legacy meters being replaced with AMI meters; and over- or under-collection of costs through the Grid Modernization Rider. In addition, PNM requested approval of the proposed format of an Opt-Out Consent Form and methodology to determine PNM’s proposed cost-based opt-out fees, which includes a one-time fee and a monthly fee. Following a hearing and subsequent briefs, on May 31, 2023, the NMPRC issued an order requiring the hearing examiner to direct PNM to file a cost benefit analysis as a supplement to the application. On November 22, 2023, PNM filed the required cost benefit analysis supporting PNM’s proposed Grid Modernization plan. A hearing was held in April 2024 and post-hearing briefs and response briefs were filed in June 2024. PNM is unable to predict the outcome of this matter. The Community Solar Act In 2021, the Community Solar Act established a program that allows for the development of community solar facilities and provides customers of a qualifying utility with the option of subscribing to community solar facilities, and in exchange would receive a bill credit from their utility, while the utility received energy from the community solar facility. The NMPRC is charged with administering the Community Solar Act program, establishing a total maximum capacity of 200 MW community solar (applicable until November 2024) facilities and allocating proportionally to the New Mexico electric investor-owned utilities and participating cooperatives. On March 30, 2022, the NMPRC issued an order that adopted a rule on the administration of the Community Solar Act program. The rule required utilities to file proposed community solar tariffs with the NMPRC within 60 days from the publication of the rule. A number of motions for rehearing and requests for clarification were filed between April 7 and May 2, 2022. On May 18, 2022, the NMPRC issued an order partially granting motions for rehearing, reconsideration and clarification and staying implementation pending further rulemaking. On June 16, 2022, PNM requested clarification related to the existing interconnection queue, which would not delay implementation of the Community Solar Act program. On July 12, 2022, the NMPRC provided notice of publication of its final rule in the New Mexico Register, starting the 60-day clock for utilities to file their proposed community solar tariffs, forms, and other relevant agreements. On September 14, 2022, PNM filed Community Solar tariffs. On October 12, 2022, the NMPRC issued an order to suspend PNM’s and two other investor-owned utilities tariffs and required the utilities to file information NMPRC Staff has identified as necessary for a complete evaluation of the tariffs but did not appoint a hearing examiner or schedule a public hearing. Another investor-owned utility has filed an appeal with the NM Supreme Court seeking review of the NMPRC’s decisions, to which PNM has intervened. The NM Supreme Court held oral arguments on March 11, 2024 and issued an order upholding the Community Solar Rule and affirming without further delay the implementation of the Community Solar Act program. On November 16, 2022, PNM filed its Community Solar tariff which establishes the Community Solar bill credit to be applied to an eligible retail customer of PNM who is a subscriber to a community solar facility. On December 23, 2022, PNM filed an updated Community Solar tariff under protest and filed a motion for clarification, suspension, and timely hearing on PNM’s Community Solar tariff. On January 18, 2023, the NMPRC suspended PNM’s Community Solar tariff. On March 1, 2023, the NMPRC issued an Order Opening a New Docket for Two-Phase Proceedings. The first phase addressed issues concerning the proposed subscriber organization agreements and the proposed customer data forms. The second phase will address all issues concerning proposed tariffs, agreements and forms that are not addressed in the first phase. On May 31, 2023, the utilities filed a Consolidated Reply Brief to the NMPRC and the Joint Intervenors-Appellee filed Answer Briefs in the NM Supreme Court proceeding. On September 21, 2023, the NMPRC issued an order approving an uncontested stipulation on the first phase and on October 30, 2023, PNM’s advice notice conforming to the stipulation became effective. A hearing for the second phase was held from January 17 through January 19, 2024. PNM cannot predict the outcome of the pending matters. Transportation and Electrification Program (TEP) On June 1, 2023, PNM filed its 2024-2026 TEP with the NMPRC, requesting approval of a $37.1 million total three-year budget and continuation of the current TEP Rider. Approximately 22% of the budget, $8.0 million, will be dedicated to low-income customers. On February 2, 2024, the hearing examiners in the case issued a RD largely approving PNM’s 2024 Plan but with modifications to certain TEP programs. On February 23, 2024, the NMPRC approved the RD with additional modifications that reduced the three-year budget by $4.0 million, for a total revised budget of $32.9 million. The TEP rider became effective on April 26, 2024. TNMP Transmission Cost of Service Rates TNMP can update its TCOS rates twice per year to reflect changes in its invested capital although updates are not allowed while a general rate case is in process. Updated rates reflect the addition and retirement of transmission facilities, including appropriate depreciation, federal income tax and other associated taxes, and the approved rate of return on such facilities. 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) May 12, 2023 $ 150.5 $ 19.4 September 6, 2023 21.4 4.2 March 15, 2024 97.4 13.1 On July 25, 2024, TNMP filed an application to further update its transmission rates to reflect an increase in total rate base of $20.6 million, which would increase revenues by $3.9 million annually. The application is pending before the PUCT. Periodic Distribution Rate Adjustment PUCT rules permit interim rate adjustments to reflect changes in investments in distribution assets. Historically, distribution utilities have been restricted to a single, annual periodic rate adjustment through a DCRF submitted between April 1 and April 8 of each year as long as the electric utility was not earning more than its authorized rate of return using weather-normalized data. However, the recent passage of Senate Bill 1015 now permits DCRF proceedings to be filed twice per year with a 60-day administrative deadline that can be extended for 15 days on good cause. Additionally, a DCRF may be filed during a pending rate case proceeding as long as that DCRF request is not filed until the 185th day after the rate case proceeding was initiated. The following sets forth TNMP’s recent interim distribution rate increases: Effective Date Approved Increase in Rate Base Annual Increase in Revenue (In millions) September 1, 2022 $ 95.7 $ 6.8 September 1, 2023 157.0 14.5 July 28, 2024 205.9 15.6 On July 30, 2024, TNMP filed its second 2024 DCRF that requested an increase in TNMP annual distribution revenue requirement of $7.8 million based on an increase in rate base of $43.7 million. The case is pending review by the PUCT. Energy Efficiency TNMP recovers the costs of its energy efficiency programs through an energy efficiency cost recovery factor (“EECRF”), which includes projected program costs, under and over collected costs from prior years, rate case expenses, and performance bonuses (if programs exceed mandated savings goals). TNMP’s 2022 EECRF filing requested recovery of $7.3 million, including a performance bonus of $1.9 million, and became effective March 1, 2023. On May 26, 2023, TNMP filed its request to adjust the EECRF to reflect changes in costs for 2024. On September 28, 2023, the PUCT approved a unanimous stipulation, authorizing recovery of $6.6 million, including a performance bonus of $1.2 million based on TNMP’s energy efficiency achievements in the 2022 plan year. On May 31, 2024, TNMP filed its request to adjust the EECRF to reflect changes in costs for 2025. The total amount requested was $7.0 million, which includes a performance bonus of $1.3 million based on TNMP’s energy efficiency achievements in the 2023 plan year. The case is pending review by the PUCT. Hurricane Beryl On July 8, 2024, Hurricane Beryl made landfall in the Texas Gulf Coast leaving approximately 116,000 customers in the TNMP service area, without power. TNMP is tracking storm-related restoration costs to be collected in a future regulatory proceeding. |
Lease Commitments
Lease Commitments | 6 Months Ended |
Jun. 30, 2024 | |
Leases [Abstract] | |
Lease Commitments | Lease Commitments The Company leases office buildings, vehicles, battery storage facilities, and other equipment. In addition, 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 2023 Annual Reports on Form 10-K. PVNGS In 1985 and 1986, PNM entered into leases for its interest in PVNGS Unit 1 and 2. The leases initially were scheduled to expire in January 2015 for four Unit 1 leases and January 2016 for four Unit 2 leases. Following procedures set forth in the PVNGS leases, PNM notified four of the lessors under the Unit 1 leases and one lessor under the Unit 2 lease that it would elect to renew those leases on the expiration date of the original leases. The four Unit 1 leases expired in January 2023 and the one Unit 2 lease expired in January 2024. PNM has no further lease payments related to PVNGS Unit 1 or 2. On April 5, 2021, PNM and 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. In January 2023, the Unit 1 leases expired, and PNM closed on the associated sale to SRP, receiving payments of $33.7 million, of which $28.4 million was recorded as a reduction to Net utility plant on the Condensed Consolidated Balance Sheets and is presented as cash flows from investing activities on the Condensed Consolidated Statement of Cash Flows. In addition, $5.3 million was recorded as a reduction to materials, supplies, and fuel stock on the Condensed Consolidated Balance Sheets and is presented as cash flows from operating activities on the Condensed Consolidated Statement of Cash Flows. In January 2024, the Unit 2 leases expired, and PNM closed on the associated sale to SRP, receiving payments of $3.4 million, of which $2.8 million was recorded as a reduction to Net utility plant on the Condensed Consolidated Balance Sheets and is presented as cash flows from investing activities on the Condensed Consolidated Statement of Cash Flows. In addition, $0.6 million was recorded as a reduction to Materials, supplies and fuel stock on the Condensed Consolidated Balance Sheets and is presented as cash flows from operating activities on the Condensed Consolidated Statement of Cash Flows. Land Easements and Rights-of-Ways Many of PNM’s electric transmission and distribution facilities are located on lands that require the grant of rights-of-way from governmental entities, Native American tribes, or private parties. PNM has completed several renewals of rights-of-way, the largest of which is a renewal with the Navajo Nation. PNM is obligated to pay the Navajo Nation annual payments of $6.0 million, subject to adjustment each year based on the Consumer Price Index, through 2029. PNM’s April 2024 payment for the amount due under the Navajo Nation right-of-way lease was $8.6 million, which included amounts due under the Consumer Price Index adjustment. Changes in the Consumer Price Index subsequent to January 1, 2019 are considered variable lease payments. PNM has other prepaid rights-of-way agreements that are not accounted for as leases or recognized as a component of plant in service. PNM reflects the unamortized balance of these prepayments in other deferred charges on the Condensed Consolidated Balance Sheets and recognizes amortization expense associated with these agreements in the Condensed Consolidated Statement of Earnings over their term. As of June 30, 2024 and December 31, 2023, the unamortized balance of these rights-of-ways was $69.0 million and $56.2 million. PNM recognized amortization expense associated with these agreements of $1.0 million and $2.1 million in the three and six months ended June 30, 2024 and $0.9 million and $1.8 million in the three and six months ended June 30, 2023. 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 June 30, 2024, residual value guarantees on fleet vehicle and equipment leases are $0.8 million, $1.0 million, and $1.7 million for PNM, TNMP, and PNMR Consolidated. Battery Storage Agreements The Company has entered into various battery storage agreements for 20-year terms that have fixed payments over the life of the agreements. The Company accounts for these agreements as operating leases and records the initial lease liabilities with corresponding right-of-use assets. In addition, the Company has elected to separate lease components from non-lease components for battery storage agreements and accordingly, does not include non-lease components in the measurement of the lease liability or right-of-use asset. The non-lease components, currently not included in the measurement of the lease liability or the corresponding right-of-use asset, comprise 25.5% of the value of the agreements. Information related to the Company’s operating leases recorded on the Condensed Consolidated Balance Sheets is presented below: June 30, 2024 December 31, 2023 PNM TNMP PNMR Consolidated PNM TNMP PNMR Consolidated (In thousands) Operating leases: Operating lease assets, net of amortization $ 175,363 $ 1,362 $ 177,285 $ 180,370 $ 1,814 $ 182,201 Current portion of operating lease liabilities 9,963 835 10,834 11,371 895 12,267 Long-term portion of operating lease liabilities 158,609 457 159,592 166,191 809 167,000 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: June 30, 2024 December 31, 2023 PNM TNMP PNMR Consolidated PNM TNMP PNMR Consolidated (In thousands) Financing leases: Non-utility property $ 22,594 $ 24,054 $ 47,023 $ 25,425 $ 24,487 $ 49,981 Accumulated depreciation (10,859) (12,261) (23,199) (11,984) (11,869) (23,905) Non-utility property, net 11,735 11,793 23,824 13,441 12,618 26,076 Other current liabilities $ 3,710 $ 4,476 $ 8,268 $ 4,146 $ 4,616 $ 8,776 Other deferred credits 8,045 7,338 15,601 9,300 8,023 17,326 Information concerning the weighted average remaining lease terms and the weighted average discount rates used to determine the Company’s lease liabilities as of June 30, 2024 is presented below: PNM TNMP PNMR Consolidated Weighted average remaining lease term (years): Operating leases 16.74 1.41 16.60 Financing leases 3.54 2.95 3.25 Weighted average discount rate: Operating leases 5.65 % 4.26 % 5.64 % Financing leases 4.77 % 4.96 % 4.87 % Information for the components of lease expense is as follows: Three Months Ended June 30, 2024 Six Months Ended June 30, 2024 PNM TNMP PNMR Consolidated PNM TNMP PNMR Consolidated (In thousands) Operating lease cost: Battery storage leases $ 2,947 $ — $ 2,947 $ 5,893 $ — $ 5,893 Other operating leases 1,908 237 2,157 3,967 507 4,486 Amounts capitalized (28) (209) (237) (63) (442) (505) Total operating lease expense 4,827 28 4,867 9,797 65 9,874 Financing lease cost: Amortization of right-of-use assets 1,120 1,315 2,463 2,337 2,631 5,005 Interest on lease liabilities 143 147 294 287 299 591 Amounts capitalized (756) (1,161) (1,917) (1,597) (2,343) (3,940) Total financing lease expense 507 301 840 1,027 587 1,656 Variable lease expense 433 — 433 793 — 793 Short-term lease expense 148 7 165 352 12 381 Total lease expense for the period $ 5,915 $ 336 $ 6,305 $ 11,969 $ 664 $ 12,704 Three Months Ended June 30, 2023 Six Months Ended June 30, 2023 PNM TNMP PNMR Consolidated PNM TNMP PNMR Consolidated (In thousands) Operating lease cost: $ 2,468 $ 401 $ 2,869 $ 6,376 $ 830 $ 7,206 Amounts capitalized (103) (331) (434) (263) (684) (947) Total operating lease expense 2,365 70 2,435 6,113 146 6,259 Financing lease cost: Amortization of right-of-use assets 1,123 1,098 2,235 2,132 2,162 4,329 Interest on lease liabilities 140 112 252 262 223 486 Amounts capitalized (778) (699) (1,477) (1,469) (1,699) (3,167) Total financing lease expense 485 511 1,010 925 686 1,648 Variable lease expense 360 — 360 622 — 622 Short-term lease expense 145 1 149 292 1 299 Total lease expense for the period $ 3,355 $ 582 $ 3,954 $ 7,952 $ 833 $ 8,828 Supplemental cash flow information related to the Company’s leases is as follows: Six Months Ended Six Months Ended June 30, 2024 June 30, 2023 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 $ 13,701 $ 26 $ 13,737 $ 16,208 $ 155 $ 16,363 Operating cash flows from financing leases 94 53 152 88 38 127 Finance cash flows from financing leases 919 533 1,487 792 646 1,474 Non-cash information related to right-of-use assets obtained in exchange for lease obligations: Operating leases $ 27 $ 69 $ 663 $ 94 $ 6 $ 100 Financing leases 831 1,736 2,885 4,793 1,783 6,576 Capitalized lease costs are reflected as investing activities on the Company’s Condensed Consolidated Statements of Cash Flows for the six months ended June 30, 2024 and 2023. Future expected lease payments are shown below: As of June 30, 2024 PNM TNMP PNMR Consolidated Operating Operating Financing Battery Storage Other Financing Operating Financing Battery Storage Other (In thousands) Remainder of 2024 $ 2,202 $ 5,893 $ 161 $ 2,595 $ 454 $ 4,846 $ 5,893 $ 648 2025 3,797 11,786 7,082 4,471 787 8,357 11,786 7,935 2026 3,269 11,786 7,031 3,235 90 6,592 11,786 7,190 2027 2,026 11,786 7,035 1,800 14 3,914 11,786 7,120 2028 913 11,786 7,038 501 11 1,426 11,786 7,122 Later years 614 172,254 10,587 113 — 728 172,254 11,013 Total minimum lease payments 12,821 225,291 38,934 12,715 1,356 25,863 225,291 41,028 Less: Imputed interest 1,066 90,546 5,107 901 64 1,994 90,546 5,347 Lease liabilities $ 11,755 $ 134,745 $ 33,827 $ 11,814 $ 1,292 $ 23,869 $ 134,745 $ 35,681 The above table includes $11.2 million, $11.6 million, and $22.8 million for PNM, TNMP, and PNMR at June 30, 2024 for expected future payments on fleet vehicle and equipment leases that could be avoided if the leased assets were returned and the lessor is able to recover estimated market value for the equipment from third parties. At June 30, 2024, the Company has various lease arrangements that have been executed but have not yet commenced, which are primarily related to battery storage agreements. The Company currently expects lease commencement dates in 2024, with lease terms expiring in 2045, and will recognize lease assets and liabilities upon lease commencement. The expected total fixed consideration to be paid for these arrangements, which includes non-lease payments, is approximately $1.1 billion over the 20-year terms of the agreements. |
Lease Commitments | Lease Commitments The Company leases office buildings, vehicles, battery storage facilities, and other equipment. In addition, 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 2023 Annual Reports on Form 10-K. PVNGS In 1985 and 1986, PNM entered into leases for its interest in PVNGS Unit 1 and 2. The leases initially were scheduled to expire in January 2015 for four Unit 1 leases and January 2016 for four Unit 2 leases. Following procedures set forth in the PVNGS leases, PNM notified four of the lessors under the Unit 1 leases and one lessor under the Unit 2 lease that it would elect to renew those leases on the expiration date of the original leases. The four Unit 1 leases expired in January 2023 and the one Unit 2 lease expired in January 2024. PNM has no further lease payments related to PVNGS Unit 1 or 2. On April 5, 2021, PNM and 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. In January 2023, the Unit 1 leases expired, and PNM closed on the associated sale to SRP, receiving payments of $33.7 million, of which $28.4 million was recorded as a reduction to Net utility plant on the Condensed Consolidated Balance Sheets and is presented as cash flows from investing activities on the Condensed Consolidated Statement of Cash Flows. In addition, $5.3 million was recorded as a reduction to materials, supplies, and fuel stock on the Condensed Consolidated Balance Sheets and is presented as cash flows from operating activities on the Condensed Consolidated Statement of Cash Flows. In January 2024, the Unit 2 leases expired, and PNM closed on the associated sale to SRP, receiving payments of $3.4 million, of which $2.8 million was recorded as a reduction to Net utility plant on the Condensed Consolidated Balance Sheets and is presented as cash flows from investing activities on the Condensed Consolidated Statement of Cash Flows. In addition, $0.6 million was recorded as a reduction to Materials, supplies and fuel stock on the Condensed Consolidated Balance Sheets and is presented as cash flows from operating activities on the Condensed Consolidated Statement of Cash Flows. Land Easements and Rights-of-Ways Many of PNM’s electric transmission and distribution facilities are located on lands that require the grant of rights-of-way from governmental entities, Native American tribes, or private parties. PNM has completed several renewals of rights-of-way, the largest of which is a renewal with the Navajo Nation. PNM is obligated to pay the Navajo Nation annual payments of $6.0 million, subject to adjustment each year based on the Consumer Price Index, through 2029. PNM’s April 2024 payment for the amount due under the Navajo Nation right-of-way lease was $8.6 million, which included amounts due under the Consumer Price Index adjustment. Changes in the Consumer Price Index subsequent to January 1, 2019 are considered variable lease payments. PNM has other prepaid rights-of-way agreements that are not accounted for as leases or recognized as a component of plant in service. PNM reflects the unamortized balance of these prepayments in other deferred charges on the Condensed Consolidated Balance Sheets and recognizes amortization expense associated with these agreements in the Condensed Consolidated Statement of Earnings over their term. As of June 30, 2024 and December 31, 2023, the unamortized balance of these rights-of-ways was $69.0 million and $56.2 million. PNM recognized amortization expense associated with these agreements of $1.0 million and $2.1 million in the three and six months ended June 30, 2024 and $0.9 million and $1.8 million in the three and six months ended June 30, 2023. 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 June 30, 2024, residual value guarantees on fleet vehicle and equipment leases are $0.8 million, $1.0 million, and $1.7 million for PNM, TNMP, and PNMR Consolidated. Battery Storage Agreements The Company has entered into various battery storage agreements for 20-year terms that have fixed payments over the life of the agreements. The Company accounts for these agreements as operating leases and records the initial lease liabilities with corresponding right-of-use assets. In addition, the Company has elected to separate lease components from non-lease components for battery storage agreements and accordingly, does not include non-lease components in the measurement of the lease liability or right-of-use asset. The non-lease components, currently not included in the measurement of the lease liability or the corresponding right-of-use asset, comprise 25.5% of the value of the agreements. Information related to the Company’s operating leases recorded on the Condensed Consolidated Balance Sheets is presented below: June 30, 2024 December 31, 2023 PNM TNMP PNMR Consolidated PNM TNMP PNMR Consolidated (In thousands) Operating leases: Operating lease assets, net of amortization $ 175,363 $ 1,362 $ 177,285 $ 180,370 $ 1,814 $ 182,201 Current portion of operating lease liabilities 9,963 835 10,834 11,371 895 12,267 Long-term portion of operating lease liabilities 158,609 457 159,592 166,191 809 167,000 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: June 30, 2024 December 31, 2023 PNM TNMP PNMR Consolidated PNM TNMP PNMR Consolidated (In thousands) Financing leases: Non-utility property $ 22,594 $ 24,054 $ 47,023 $ 25,425 $ 24,487 $ 49,981 Accumulated depreciation (10,859) (12,261) (23,199) (11,984) (11,869) (23,905) Non-utility property, net 11,735 11,793 23,824 13,441 12,618 26,076 Other current liabilities $ 3,710 $ 4,476 $ 8,268 $ 4,146 $ 4,616 $ 8,776 Other deferred credits 8,045 7,338 15,601 9,300 8,023 17,326 Information concerning the weighted average remaining lease terms and the weighted average discount rates used to determine the Company’s lease liabilities as of June 30, 2024 is presented below: PNM TNMP PNMR Consolidated Weighted average remaining lease term (years): Operating leases 16.74 1.41 16.60 Financing leases 3.54 2.95 3.25 Weighted average discount rate: Operating leases 5.65 % 4.26 % 5.64 % Financing leases 4.77 % 4.96 % 4.87 % Information for the components of lease expense is as follows: Three Months Ended June 30, 2024 Six Months Ended June 30, 2024 PNM TNMP PNMR Consolidated PNM TNMP PNMR Consolidated (In thousands) Operating lease cost: Battery storage leases $ 2,947 $ — $ 2,947 $ 5,893 $ — $ 5,893 Other operating leases 1,908 237 2,157 3,967 507 4,486 Amounts capitalized (28) (209) (237) (63) (442) (505) Total operating lease expense 4,827 28 4,867 9,797 65 9,874 Financing lease cost: Amortization of right-of-use assets 1,120 1,315 2,463 2,337 2,631 5,005 Interest on lease liabilities 143 147 294 287 299 591 Amounts capitalized (756) (1,161) (1,917) (1,597) (2,343) (3,940) Total financing lease expense 507 301 840 1,027 587 1,656 Variable lease expense 433 — 433 793 — 793 Short-term lease expense 148 7 165 352 12 381 Total lease expense for the period $ 5,915 $ 336 $ 6,305 $ 11,969 $ 664 $ 12,704 Three Months Ended June 30, 2023 Six Months Ended June 30, 2023 PNM TNMP PNMR Consolidated PNM TNMP PNMR Consolidated (In thousands) Operating lease cost: $ 2,468 $ 401 $ 2,869 $ 6,376 $ 830 $ 7,206 Amounts capitalized (103) (331) (434) (263) (684) (947) Total operating lease expense 2,365 70 2,435 6,113 146 6,259 Financing lease cost: Amortization of right-of-use assets 1,123 1,098 2,235 2,132 2,162 4,329 Interest on lease liabilities 140 112 252 262 223 486 Amounts capitalized (778) (699) (1,477) (1,469) (1,699) (3,167) Total financing lease expense 485 511 1,010 925 686 1,648 Variable lease expense 360 — 360 622 — 622 Short-term lease expense 145 1 149 292 1 299 Total lease expense for the period $ 3,355 $ 582 $ 3,954 $ 7,952 $ 833 $ 8,828 Supplemental cash flow information related to the Company’s leases is as follows: Six Months Ended Six Months Ended June 30, 2024 June 30, 2023 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 $ 13,701 $ 26 $ 13,737 $ 16,208 $ 155 $ 16,363 Operating cash flows from financing leases 94 53 152 88 38 127 Finance cash flows from financing leases 919 533 1,487 792 646 1,474 Non-cash information related to right-of-use assets obtained in exchange for lease obligations: Operating leases $ 27 $ 69 $ 663 $ 94 $ 6 $ 100 Financing leases 831 1,736 2,885 4,793 1,783 6,576 Capitalized lease costs are reflected as investing activities on the Company’s Condensed Consolidated Statements of Cash Flows for the six months ended June 30, 2024 and 2023. Future expected lease payments are shown below: As of June 30, 2024 PNM TNMP PNMR Consolidated Operating Operating Financing Battery Storage Other Financing Operating Financing Battery Storage Other (In thousands) Remainder of 2024 $ 2,202 $ 5,893 $ 161 $ 2,595 $ 454 $ 4,846 $ 5,893 $ 648 2025 3,797 11,786 7,082 4,471 787 8,357 11,786 7,935 2026 3,269 11,786 7,031 3,235 90 6,592 11,786 7,190 2027 2,026 11,786 7,035 1,800 14 3,914 11,786 7,120 2028 913 11,786 7,038 501 11 1,426 11,786 7,122 Later years 614 172,254 10,587 113 — 728 172,254 11,013 Total minimum lease payments 12,821 225,291 38,934 12,715 1,356 25,863 225,291 41,028 Less: Imputed interest 1,066 90,546 5,107 901 64 1,994 90,546 5,347 Lease liabilities $ 11,755 $ 134,745 $ 33,827 $ 11,814 $ 1,292 $ 23,869 $ 134,745 $ 35,681 The above table includes $11.2 million, $11.6 million, and $22.8 million for PNM, TNMP, and PNMR at June 30, 2024 for expected future payments on fleet vehicle and equipment leases that could be avoided if the leased assets were returned and the lessor is able to recover estimated market value for the equipment from third parties. At June 30, 2024, the Company has various lease arrangements that have been executed but have not yet commenced, which are primarily related to battery storage agreements. The Company currently expects lease commencement dates in 2024, with lease terms expiring in 2045, and will recognize lease assets and liabilities upon lease commencement. The expected total fixed consideration to be paid for these arrangements, which includes non-lease payments, is approximately $1.1 billion over the 20-year terms of the agreements. |
Income Taxes
Income Taxes | 6 Months Ended |
Jun. 30, 2024 | |
Income Tax Disclosure [Abstract] | |
Income Taxes | Income Taxes The Company makes an estimate of its anticipated effective tax rate for the year as of the end of each quarterly period within its fiscal year. In interim periods, income tax expense is calculated by applying the anticipated annual effective tax rate to year-to-date earnings before income taxes. Certain unusual or infrequently occurring items are excluded from the estimated annual rate calculation. Such items include regulatory disallowances and excess tax benefits or deficiencies related to stock awards. At June 30, 2024, PNMR, PNM, and TNMP estimated their effective income tax rates for the year ended December 31, 2024 would be 15.29%, 14.31%, and 20.71%. The primary difference between the statutory income tax rates and the effective tax rates is the effect of the reduction in income tax expense resulting from the amortization of excess deferred federal income taxes. During the six months ended June 30, 2024, income tax expense calculated by applying the expected annual effective income tax rate to earnings before income taxes was further decreased by discrete items, including $1.1 million for the tax effects of regulatory disallowances at PNM and $19.5 million from the sale of NMRD at PNMR. Excess tax shortfalls related to stock awards increased tax expense by less than $0.1 million for PNMR, of which less than $0.1 million was allocated to PNM and less than $0.1 million was allocated to TNMP. Beginning February 2018, PNM’s NM 2016 Rate Case reflected the reduction in the federal corporate income tax rate resulting from enactment of legislation commonly known as the Tax Cuts and Jobs Act (the “Tax Act”), including amortization of excess deferred federal 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 had been returning the unprotected portion of excess deferred federal income taxes to customers over a period of approximately twenty-three years. Pursuant to the final order in the PNM 2024 Rate Change, the remaining balance of $62.7 million of unprotected excess deferred income taxes is being returned over a five-year period. 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 $23.3 million, $20.7 million, and |
Related Party Transactions
Related Party Transactions | 6 Months Ended |
Jun. 30, 2024 | |
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, PNM purchases renewable energy from certain NMRD-owned facilities at a fixed price per MWh of energy produced. On February 27, 2024, PNMR Development and AEP Onsite Partners sold their respective interests in NMRD and the table below reflects transactions with NMRD prior to the sale. 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 Six Months Ended June 30, June 30, 2024 2023 2024 2023 (In thousands) Services billings: PNMR to PNM $ 31,023 $ 29,142 $ 66,430 $ 60,642 PNMR to TNMP 12,885 11,333 27,121 23,727 PNM to TNMP 109 104 190 169 TNMP to PNMR — 35 10 71 PNMR to NMRD — 82 66 164 Renewable energy purchases: PNM from NMRD — 3,748 1,523 6,109 Interest billings: PNMR to PNM 25 7 39 10 PNM to PNMR 154 143 309 273 PNMR to TNMP 22 117 179 128 Income tax sharing payments: PNMR to PNM — — — — TNMP to PNMR — — — — |
Equity Method Investment
Equity Method Investment | 6 Months Ended |
Jun. 30, 2024 | |
Equity Method Investments and Joint Ventures [Abstract] | |
Equity Method Investment | Equity Method Investment As discussed in Note 21 of the Company’s 2023 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. On February 27, 2024, PNMR Development and AEP Onsite Partners sold their respective interests in NMRD. PNMR Development received net proceeds of $117.0 million and recognized an after-tax gain of $4.4 million, which includes the recognition of deferred investment tax credits of $15.7 million. In the six months ended June 30, 2024 and 2023, PNMR Development and AEP OnSite Partners each made cash contributions to NMRD of $12.6 million and $14.8 million for its construction activities. Until the sale closing on February 27, 2024, PNMR presented its share of net earnings from NMRD in Other income on the Condensed Consolidated Statements of Earnings. Summarized financial information for NMRD through the closing date of the sale is as follows: Results of Operations Three Months Ended June 30, Six Months Ended June 30, 2024 2023 2024 2023 (In thousands) Operating revenues $ — $ 3,975 $ 3,204 $ 6,505 Operating expenses — 1,965 3,378 4,384 Net earnings (loss) $ — $ 2,010 $ (174) $ 2,121 Financial Position June 30, December 31, 2024 2023 (In thousands) Current assets $ — $ 2,589 Net property, plant, and equipment — 235,791 Non-current assets — 1,849 Total assets — 240,229 Current liabilities — 730 Non-current liabilities — 358 Owners’ equity $ — $ 239,141 |
Goodwill
Goodwill | 6 Months Ended |
Jun. 30, 2024 | |
Goodwill and Intangible Assets Disclosure [Abstract] | |
Goodwill | Goodwill The excess purchase price over the fair value of the assets acquired and the liabilities assumed by PNMR for its 2005 acquisition of TNP Enterprises, Inc. and Subsidiaries (“TNP”) was recorded as goodwill and was pushed down to the businesses acquired. In 2007, the TNMP assets that were included in its New Mexico operations, including goodwill, were transferred to PNM. PNMR’s reporting units that currently have goodwill are PNM and TNMP. The Company evaluates its goodwill for impairment annually at the reporting unit level or more frequently if circumstances indicate that the goodwill may be impaired. Application of the impairment test requires judgment, including the identification of reporting units, assignment of assets and liabilities to reporting units, and determination of the fair value of each reporting unit. In certain circumstances an entity may perform a qualitative analysis to conclude that the goodwill of a reporting unit is not impaired. Under a qualitative assessment an entity considers macroeconomic conditions, industry and market considerations, cost factors, overall financial performance, other relevant entity-specific events affecting a reporting unit, as well as whether a sustained decrease (both absolute and relative to its peers) in share price has occurred. An entity considers the extent to which each of the adverse events and circumstances identified could affect the comparison of a reporting unit’s fair value with its carrying amount. An entity places more weight on the events and circumstances that most affect a reporting unit’s fair value or the carrying amount of its net assets. An entity also considers positive and mitigating events and circumstances that may affect its determination of whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount. An entity evaluates, on the basis of the weight of evidence, the significance of all identified events and circumstances in the context of determining whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount. A quantitative analysis is not required if, after assessing events and circumstances, an entity determines that it is not more likely than not that the fair value of a reporting unit is less than its carrying amount. In other circumstances, an entity may perform a quantitative analysis to reach the conclusion regarding impairment with respect to a reporting unit. An entity may choose to perform a quantitative analysis without performing a qualitative analysis and may perform a qualitative analysis for certain reporting units, but a quantitative analysis for others. The first step of the quantitative impairment test requires an entity to compare the fair value of the reporting unit with its carrying value, including goodwill. If, as a result of this analysis, the entity concludes there is an indication of impairment in a reporting unit having goodwill, the entity is required to perform the second step of the impairment analysis, determining the amount of goodwill impairment to be recorded. The amount is calculated by comparing the implied fair value of the goodwill to its carrying amount. This exercise would require the entity to allocate the fair value determined in step one to the individual assets and liabilities of the reporting unit. Any remaining fair value would be the implied fair value of goodwill on the testing date. To the extent the recorded amount of goodwill of a reporting unit exceeds the implied fair value determined in step two, an impairment loss would be reflected in results of operations. PNMR periodically updates its quantitative analysis for both PNM and TNMP. The use of a quantitative approach in a given period is not necessarily an indication that a potential impairment has been identified under a qualitative approach. When PNMR performs a quantitative analysis for PNM or TNMP, a discounted cash flow methodology is primarily used to estimate the fair value of the reporting unit. This analysis requires significant judgments, including estimations of future cash flows, which is dependent on internal forecasts, estimations of long-term growth rates for the business, and determination of appropriate weighted average cost of capital for the reporting unit. Changes in these estimates and assumptions could materially affect the determination of fair value and the conclusion of impairment. When PNMR performs a qualitative or quantitative analysis for PNM or TNMP, PNMR considers market and macroeconomic factors including changes in growth rates, changes in the Weighted Average Cost of Capital (“WACC”), and changes in discount rates. PNMR also evaluates its stock price relative to historical performance, industry peers, and to major market indices, including an evaluation of PNMR’s market capitalization relative to the carrying value of its reporting units. For its annual evaluations performed as of April 1, 2024, PNMR performed a quantitative analysis for the PNM reporting unit and a qualitative analysis for the TNMP reporting unit. The quantitative analysis, discussed above, indicated that the fair value of the PNM reporting unit, which has goodwill of $51.6 million, exceeded its carrying value by approximately 54%. The qualitative analysis, in addition to the typical considerations discussed above, considered changes in the Company’s expectations of future financial performance since the April 1, 2020 quantitative analysis and the previous qualitative analyses through April 1, 2023 performed for TNMP. This analysis considered events specific to TNMP such as the potential impacts of legal and regulatory matters discussed in Note 11 and Note 12. Based on an evaluation of these and other factors, the Company determined it was not more likely than not that the April 1, 2024 carrying values of PNM and TNMP exceeded their fair value. Since the April 1, 2024 annual evaluation, there have been no events or indications that the fair values of the reporting units with recorded goodwill have decreased below their carrying values. For its annual evaluations performed as of April 1, 2023, PNMR performed a qualitative analysis for both the PNM and TNMP reporting units. In addition to the typical considerations discussed above, the qualitative analysis considered changes in the Company’s expectations of future financial performance since the April 1, 2018 quantitative analysis and the previous qualitative analyses through April 1, 2022 performed for PNM, as well as the April 1, 2020 quantitative analysis and the previous qualitative analyses through April 1, 2022 performed for TNMP. This analysis considered Company specific events such as the Merger, potential impacts of legal and regulatory matters discussed in Note 11 and Note 12, including potential outcomes in PNM’s San Juan Abandonment Application, PNM’s Four Corners Abandonment Application, and PNM’s PVNGS Leased Interest Abandonment Application. The April 1, 2018 quantitative evaluations indicated the fair value of the PNM reporting unit, which has goodwill of $51.6 million, exceeded its carrying value by approximately 19%. The April 1, 2020 quantitative evaluations indicated the fair value of the TNMP reporting unit, which has goodwill of $226.7 million, exceeded its carrying value by approximately 38%. Based on an evaluation of these and other factors, the Company determined it was not more likely than not that the April 1, 2023 carrying values of PNM and TNMP exceeded their fair value. |
Insider Trading Arrangements
Insider Trading Arrangements | 3 Months Ended |
Jun. 30, 2024 | |
Trading Arrangements, by Individual | |
Rule 10b5-1 Arrangement Adopted | false |
Non-Rule 10b5-1 Arrangement Adopted | false |
Rule 10b5-1 Arrangement Terminated | false |
Non-Rule 10b5-1 Arrangement Terminated | false |
Significant Accounting Polici_2
Significant Accounting Policies and Responsibility for Financial Statements (Policies) | 6 Months Ended |
Jun. 30, 2024 | |
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 and ETBC I. 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. |
New Accounting Pronouncements | New Accounting Pronouncements Information concerning recently issued accounting pronouncements that have not yet been adopted by the Company is presented below. The Company does not expect difficulty in adopting these standards by their required effective dates. Accounting Standards Update 2023-07 - Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures In November 2023, the FASB issued ASU 2023-07 enhancing disclosures about significant segment expenses. Disclosure requirements of this update include disclosure, on an annual and interim basis, of significant segment expenses that are regularly provided to the Chief Operating Decision Maker (“CODM”) and included within each reported measure of segment profit or loss (collectively referred to as the “significant expense principle”); an amount for other segment items by reportable segment and a description of its composition; the title and position of the CODM and an explanation of how the CODM uses the reported measures in assessing segment performance and deciding how to allocate resources; and that a single reportable segment provides all the disclosures required by the amendments in this ASU and all existing segment disclosures in Topic 280. The amendment also clarifies that in addition to the measure most consistent with the measurement principles under GAAP, reporting of additional measures of a segment’s profit or loss used by the CODM in assessing segment performance and determining allocation of resources is allowed. ASU 2023-07 is effective for the Company for annual periods beginning January 1, 2024 and interim periods beginning January 1, 2025 with early adoption being permitted. ASU 2023-07 is to be applied retrospectively to all prior periods presented in the financial statements. Accounting Standards Update 2023-09 - Income Taxes (Topic 740): Improvements to Income Tax Disclosures In December 2023, the FASB issued ASU 2023-09 enhancing the transparency and decision usefulness of income tax disclosures. Disclosure requirements of this update include (on an annual basis) the disclosure of specific categories in the rate reconciliation and the inclusion of additional information for reconciling items that meet a quantitative threshold (if the effect of the reconciling item is equal to or greater than 5 percent of the amount computed by multiplying pre-tax income by the applicable statutory rate). The amendment also requires the disclosure (on an annual basis) of information about income taxes paid (net of refunds) including the disaggregation by federal, state, and foreign taxes as well as by individual jurisdiction. Additional requirements include the disclosure of income (loss) from continuing operations before income tax expense (benefit) disaggregated between foreign and domestic as well as income tax expense (benefit) from continuing operations disaggregated by federal, state, and foreign. ASU 2023-09 is effective for the Company beginning January 1, 2025 with early adoption being permitted. ASU 2023-09 is to be applied on a prospective basis with retrospective application permitted. |
Segment Information (Tables)
Segment Information (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
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 June 30, 2024 Electric operating revenues $ 333,671 $ 154,431 $ — $ 488,102 Cost of energy 114,772 39,934 — 154,706 Utility margin 218,899 114,497 — 333,396 Other operating expenses 106,578 34,149 (7,427) 133,300 Depreciation and amortization 54,230 31,033 9,150 94,413 Operating income (loss) 58,091 49,315 (1,723) 105,683 Interest income (expense) 4,443 127 (100) 4,470 Other income (deductions) 3,869 2,705 36 6,610 Interest charges (25,880) (14,451) (15,497) (55,828) Segment earnings (loss) before income taxes 40,523 37,696 (17,284) 60,935 Income taxes (benefit) 5,821 7,771 (4,621) 8,971 Segment earnings (loss) 34,702 29,925 (12,663) 51,964 Valencia non-controlling interest (3,783) — — (3,783) Subsidiary preferred stock dividends (132) — — (132) Segment earnings (loss) attributable to PNMR $ 30,787 $ 29,925 $ (12,663) $ 48,049 Six Months Ended June 30, 2024 Electric operating revenues $ 641,786 $ 283,193 $ — $ 924,979 Cost of energy 212,184 74,826 — 287,010 Utility margin 429,602 208,367 — 637,969 Other operating expenses 213,044 66,899 (15,847) 264,096 Depreciation and amortization 107,517 61,415 18,668 187,600 Operating income (loss) 109,041 80,053 (2,821) 186,273 Interest income (expense) 8,970 296 (216) 9,050 Other income (deductions) 24,415 3,581 (14,999) 12,997 Interest charges (50,996) (27,787) (30,807) (109,590) Segment earnings (loss) before income taxes 91,430 56,143 (48,843) 98,730 Income taxes (benefit) 11,632 11,635 (26,867) (3,600) Segment earnings (loss) 79,798 44,508 (21,976) 102,330 Valencia non-controlling interest (6,827) — — (6,827) Subsidiary preferred stock dividends (264) — — (264) Segment earnings (loss) attributable to PNMR $ 72,707 $ 44,508 $ (21,976) $ 95,239 At June 30, 2024: Total Assets $ 7,060,151 $ 3,354,923 $ 168,336 $ 10,583,410 Goodwill $ 51,632 $ 226,665 $ — $ 278,297 PNM TNMP Corporate PNMR Consolidated (In thousands) Three Months Ended June 30, 2023 Electric operating revenues $ 338,242 $ 138,914 $ — $ 477,156 Cost of energy 133,609 38,843 — 172,452 Utility margin 204,633 100,071 — 304,704 Other operating expenses 106,154 33,395 (6,314) 133,235 Depreciation and amortization 44,064 27,949 7,126 79,139 Operating income (loss) 54,415 38,727 (812) 92,330 Interest income (expense) 5,370 121 (132) 5,359 Other income (deductions) 3,695 1,512 655 5,862 Interest charges (20,766) (11,412) (13,721) (45,899) Segment earnings (loss) before income taxes 42,714 28,948 (14,010) 57,652 Income taxes (benefit) 7,411 4,316 (3,498) 8,229 Segment earnings (loss) 35,303 24,632 (10,512) 49,423 Valencia non-controlling interest (3,987) — — (3,987) Subsidiary preferred stock dividends (132) — — (132) Segment earnings (loss) attributable to PNMR $ 31,184 $ 24,632 $ (10,512) $ 45,304 Six Months Ended June 30, 2023 Electric operating revenues $ 768,407 $ 252,826 $ — $ 1,021,233 Cost of energy 343,462 70,676 — 414,138 Utility margin 424,945 182,150 — 607,095 Other operating expenses 204,876 66,247 (12,662) 258,461 Depreciation and amortization 87,750 55,389 14,074 157,213 Operating income (loss) 132,319 60,514 (1,412) 191,421 Interest income (expense) 10,219 235 (252) 10,202 Other income (deductions) 10,728 1,648 528 12,904 Interest charges (38,888) (21,837) (26,097) (86,822) Segment earnings (loss) before income taxes 114,378 40,560 (27,233) 127,705 Income taxes (benefit) 19,240 5,895 (7,126) 18,009 Segment earnings (loss) 95,138 34,665 (20,107) 109,696 Valencia non-controlling interest (9,114) — — (9,114) Subsidiary preferred stock dividends (264) — — (264) Segment earnings (loss) attributable to PNMR $ 85,760 $ 34,665 $ (20,107) $ 100,318 At June 30, 2023: Total Assets $ 6,440,357 $ 2,916,206 $ 270,407 $ 9,626,970 Goodwill $ 51,632 $ 226,665 $ — $ 278,297 |
Public Utilities General Disclosures | PNM and TNMP do not intend for utility margin to represent any financial measure as defined by GAAP. However, the calculation of utility margin, as presented, most closely compares to gross margin as defined by GAAP. Reconciliations between utility margin and gross margin are presented below. PNM TNMP Corporate and Other PNMR Consolidated (In thousands) Three Months Ended June 30, 2024 Gross margin $ 124,735 $ 73,763 $ — $ 198,498 Energy production costs 24,584 — — 24,584 Transmission and distribution costs 15,350 9,701 — 25,051 Depreciation and amortization 54,230 31,033 — 85,263 1 Utility margin $ 218,899 $ 114,497 $ — $ 333,396 Six Months Ended June 30, 2024 Gross margin $ 245,589 $ 128,837 $ — $ 374,426 Energy production costs 46,796 — — 46,796 Transmission and distribution costs 29,700 18,115 — 47,815 Depreciation and amortization 107,517 61,415 — 168,932 1 Utility margin $ 429,602 $ 208,367 $ — $ 637,969 Three Months Ended June 30, 2023 Gross margin $ 120,215 $ 61,412 $ — $ 181,627 Energy production costs 25,599 — — 25,599 Transmission and distribution costs 14,755 10,710 — 25,465 Depreciation and amortization 44,064 27,949 — 72,013 1 Utility margin $ 204,633 $ 100,071 $ — $ 304,704 Six Months Ended June 30, 2023 Gross margin $ 260,596 $ 107,742 $ — $ 368,338 Energy production costs 47,957 — — 47,957 Transmission and distribution costs 28,642 19,019 — 47,661 Depreciation and amortization 87,750 55,389 — 143,139 1 Utility margin $ 424,945 $ 182,150 $ — $ 607,095 1 Corporate and Other depreciation and amortization represents corporate level activities that are billed at cost and reflected as general and administrative expenses at PNM and TNMP and therefore are not a component of gross margin or utility margin. See Note 1. |
Accumulated Other Comprehensi_2
Accumulated Other Comprehensive Income (Loss) (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
Equity [Abstract] | |
Schedule of Accumulated Other Comprehensive Income (Loss) | Information regarding accumulated other comprehensive income (loss) for the six months ended June 30, 2024 and 2023 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, 2023 $ 10,652 $ (77,157) $ (66,505) $ 3,665 $ (62,840) Amounts reclassified from AOCI (pre-tax) (12,566) 2,433 (10,133) 5,563 (4,570) Income tax impact of amounts reclassified 3,192 (618) 2,574 (1,413) 1,161 Other OCI changes (pre-tax) (587) — (587) (4,307) (4,894) Income tax impact of other OCI changes 149 — 149 1,094 1,243 Net after-tax change (9,812) 1,815 (7,997) 937 (7,060) Balance at June 30, 2024 $ 840 $ (75,342) $ (74,502) $ 4,602 $ (69,900) Balance at December 31, 2022 $ 7,422 $ (81,757) $ (74,335) $ 8,287 $ (66,048) Amounts reclassified from AOCI (pre-tax) (2,580) 2,388 (192) 1,197 1,005 Income tax impact of amounts reclassified 655 (606) 49 (304) (255) Other OCI changes (pre-tax) 4,560 — 4,560 3,567 8,127 Income tax impact of other OCI changes (1,158) — (1,158) (906) (2,064) Net after-tax change 1,477 1,782 3,259 3,554 6,813 Balance at June 30, 2023 $ 8,899 $ (79,975) $ (71,076) $ 11,841 $ (59,235) |
Earnings Per Share (Tables)
Earnings Per Share (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
Earnings Per Share [Abstract] | |
Computation of Earnings Per Share | Information regarding the computation of earnings per share is as follows: Three Months Ended Six Months Ended June 30, June 30, 2024 2023 2024 2023 (In thousands, except per share amounts) Net Earnings Attributable to PNMR $ 48,049 $ 45,304 $ 95,239 $ 100,318 Average Number of Common Shares: Outstanding during period 90,200 85,835 90,200 85,835 Vested awards of restricted stock 304 250 293 258 Average Shares – Basic 90,504 86,085 90,493 86,093 Dilutive Effect of Common Stock Equivalents: Restricted stock 48 39 40 38 2023 Forward Sale Agreements — 5 — 2 Average Shares – Diluted 90,552 86,129 90,533 86,133 Net Earnings Per Share of Common Stock: Basic $ 0.53 $ 0.53 $ 1.05 $ 1.17 Diluted $ 0.53 $ 0.53 $ 1.05 $ 1.16 |
Electric Operating Revenues (Ta
Electric Operating Revenues (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
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. PNM TNMP PNMR Consolidated Three Months Ended June 30, 2024 (In thousands) Electric Operating Revenues: Contracts with customers: Retail electric revenue Residential $ 121,065 $ 47,313 $ 168,378 Commercial 109,929 40,499 150,428 Industrial 34,201 7,917 42,118 Public authority 5,216 1,740 6,956 Economy energy service 4,033 — 4,033 Transmission 33,333 42,116 75,449 Wholesale energy sales (1) 23,507 — 23,507 Miscellaneous 1,389 962 2,351 Total revenues from contracts with customers 332,673 140,547 473,220 Alternative revenue programs 830 13,884 14,714 Other electric operating revenues 168 — 168 Total Electric Operating Revenues $ 333,671 $ 154,431 $ 488,102 Six Months Ended June 30, 2024 Electric Operating Revenues: Contracts with customers: Retail electric revenue Residential $ 241,450 $ 88,808 $ 330,258 Commercial 209,266 76,043 285,309 Industrial 58,970 17,773 76,743 Public authority 9,614 3,456 13,070 Economy energy service 11,595 — 11,595 Transmission 69,482 77,925 147,407 Wholesale energy sales (1) 35,197 — 35,197 Miscellaneous 2,814 1,917 4,731 Total revenues from contracts with customers 638,388 265,922 904,310 Alternative revenue programs 2,736 17,271 20,007 Other electric operating revenues 662 — 662 Total Electric Operating Revenues $ 641,786 $ 283,193 $ 924,979 PNM TNMP PNMR Consolidated Three Months Ended June 30, 2023 (In thousands) Electric Operating Revenues: Contracts with customers: Retail electric revenue Residential $ 108,016 $ 41,491 $ 149,507 Commercial 105,262 37,965 143,227 Industrial 26,156 12,930 39,086 Public authority 5,305 1,669 6,974 Economy energy service 10,731 — 10,731 Transmission 37,922 35,062 72,984 Wholesale energy sales (1) 37,308 — 37,308 Miscellaneous 1,377 907 2,284 Total revenues from contracts with customers 332,077 130,024 462,101 Alternative revenue programs 3,577 8,890 12,467 Other electric operating revenues 2,588 — 2,588 Total Electric Operating Revenues $ 338,242 $ 138,914 $ 477,156 Six Months Ended June 30, 2023 Electric Operating Revenues: Contracts with customers: Retail electric revenue Residential $ 227,901 $ 77,857 $ 305,758 Commercial 203,323 72,695 276,018 Industrial 45,633 25,694 71,327 Public authority 9,723 3,288 13,011 Economy energy service 20,041 — 20,041 Transmission 86,930 65,120 152,050 Wholesale energy sales (1) 150,294 — 150,294 Miscellaneous 2,786 1,848 4,634 Total revenues from contracts with customers 746,631 246,502 993,133 Alternative revenue programs 10,902 6,324 17,226 Other electric operating revenues 10,874 — 10,874 Total Electric Operating Revenues $ 768,407 $ 252,826 $ 1,021,233 (1) Includes sales for resale activity resulting from PNM’s participation in the EIM. |
Variable Interest Entities (Tab
Variable Interest Entities (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
Variable Interest Entities [Abstract] | |
Summarized Financial Information | Summarized financial information for Valencia is as follows: Results of Operations Three Months Ended June 30, Six Months Ended June 30, 2024 2023 2024 2023 (In thousands) Operating revenues $ 5,476 $ 6,144 $ 10,665 $ 12,748 Operating expenses 1,693 2,157 3,838 3,634 Earnings attributable to non-controlling interest $ 3,783 $ 3,987 $ 6,827 $ 9,114 Financial Position June 30, December 31, 2024 2023 (In thousands) Current assets $ 3,664 $ 3,422 Net property, plant, and equipment 45,832 47,253 Total assets 49,496 50,675 Current liabilities 564 717 Owners’ equity – non-controlling interest $ 48,932 $ 49,958 The following tables summarize the impact of ETBC I on PNM’s Financial Statements: Results of Operations Three Months Ended June 30, 2024 Six Months Ended June 30, 2024 (In thousands) Operating Revenues $ 5,811 $ 11,756 Depreciation and amortization 821 1,643 Interest charges 5,039 10,064 Other (49) 49 Net Earnings $ — $ — Financial Position June 30, 2024 December 31, 2023 (In thousands) Regulatory Assets - Current $ — $ 2,724 Restricted Cash (included in Other Current Assets) 15,318 — Restricted Cash (included in Other Deferred Charges) 1,767 1,728 Securitized Cost (included in Deferred Regulatory Assets) 338,986 340,629 Current Installments of Long-Term Debt 5,935 2,529 Accrued Interest 12,509 2,502 Regulatory Liabilities - Current 2,401 — Long-Term Debt 335,172 338,521 |
Fair Value of Derivative and _2
Fair Value of Derivative and Other Financial Instruments (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
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 June 30, December 31, (In thousands) Other current assets $ 846 $ 826 Other current liabilities (4,558) — Net $ (3,712) $ 826 |
Schedule of Commodity Contract Volume Positions | Commodity contract volume positions are presented in MMBTU for gas related contracts and in MWh for power related contracts. The table below presents PNM’s net buy (sell) volume positions: Economic Hedges MMBTU MWh June 30, 2024 — 66,790 December 31, 2023 — (15,360) |
Schedule Of Contingent Requirement For Commodity Contracts | The table below presents information about PNM’s contingent requirements to provide collateral under certain commodity contracts having an objectively determinable collateral provision, that are in net liability positions, and that are not fully collateralized with cash. Contractual liability represents those commodity derivative contracts recorded at fair value on the balance sheet, determined on an individual contract basis without offsetting amounts for individual contracts that are in an asset position and could be offset under master netting agreements with the same counterparty. Cash collateral posted under these contracts does not reflect letters of credit under the Company’s revolving credit facilities that may have been issued as collateral. Net exposure is the net contractual liability for all contracts, including those designated as normal purchase and normal sale, offset by existing collateral and by any offsets available under master netting agreements, including both assets and liability positions. Contractual Liability Existing Cash Collateral Net Exposure (In thousands) June 30, 2024 $ 4,558 $ — $ 4,558 December 31, 2023 $ — $ — $ — |
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, SJGS decommissioning, and coal mine reclamation trusts are presented in the following table: Three Months Ended Six Months Ended June 30, June 30, 2024 2023 2024 2023 (In thousands) Equity securities: Net gains (losses) from equity securities sold $ 6,272 $ 2,792 $ 16,143 $ 1,947 Net gains (losses) from equity securities still held (3,880) 1,142 (5,085) 8,619 Total net gains on equity securities 2,392 3,934 11,058 10,566 Available-for-sale debt securities: Net gains (losses) on debt securities (1,834) (157) 7,498 (347) Net gains on investment securities $ 558 $ 3,777 $ 18,556 $ 10,219 Three Months Ended Six Months Ended June 30, June 30, 2024 2023 2024 2023 (In thousands) Proceeds from sales $ 110,240 $ 183,566 $ 412,750 $ 274,777 Gross realized gains 7,549 7,014 21,228 10,442 Gross realized (losses) (4,661) (5,741) (12,573) (12,212) |
Investments Classified by Contractual Maturity Date | At June 30, 2024, the available-for-sale debt securities held by PNM, had the following final maturities: Fair Value (In thousands) Within 1 year $ 26,903 After 1 year through 5 years 11,678 After 5 years through 10 years 9,426 After 10 years through 15 years 10,668 After 15 years through 20 years 5,467 After 20 years 497 $ 64,639 |
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) June 30, 2024 Cash and cash equivalents $ 122,964 $ 122,964 $ — Equity securities: Corporate stocks, common 83,258 83,258 — Corporate stocks, preferred — — — Mutual funds and other 131,525 131,525 — Available-for-sale debt securities: U.S. government 22,189 22,189 — $ 254 Municipals 34,813 — 34,813 785 Corporate and other 7,637 — 7,637 124 Investments categorized within the fair value hierarchy $ 402,386 $ 359,936 $ 42,450 $ 1,163 Uncategorized Collective Investment Trust 38,844 — — Total investment securities $ 441,230 $ 359,936 $ 42,450 December 31, 2023 Cash and cash equivalents $ 93,873 $ 93,873 $ — Equity securities: Corporate stocks, common 77,422 77,422 — Corporate stocks, preferred 4,323 504 3,819 Mutual funds and other 57,966 57,966 — Available-for-sale debt securities: U.S. government 35,113 34,522 591 $ 2,055 International government 8,735 — 8,735 104 Municipals 53,436 — 53,436 2,872 Corporate and other 113,540 — 113,540 9,285 Total investment securities $ 444,408 $ 264,287 $ 180,121 $ 14,316 |
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 June 30, 2024 (In thousands) PNMR $ 4,837,764 $ 4,511,857 PNM 2,461,304 2,278,988 TNMP 1,376,927 1,232,842 December 31, 2023 PNMR $ 4,521,811 $ 4,260,509 PNM 2,261,780 2,107,588 TNMP 1,260,880 1,152,922 |
Stock-Based Compensation (Table
Stock-Based Compensation (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
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: Six Months Ended June 30, Restricted Shares and Performance Based Shares 2024 2023 Expected quarterly dividends per share $ 0.3875 $ 0.3675 Risk-free interest rate 4.27 % 4.46 % Market-Based Shares Dividend yield 4.21 % N/A Expected volatility 13.09 % N/A Risk-free interest rate 4.31 % N/A The following table summarizes activity in restricted stock awards, including performance-based and market-based shares for the six months ended June 30, 2024: Restricted Stock Shares Weighted- Outstanding at December 31, 2023 212,080 $ 40.33 Granted 239,982 32.43 Released (165,583) 38.27 Forfeited — — Outstanding at June 30, 2024 286,479 $ 34.91 The following table provides additional information concerning restricted stock activity, including performance-based and market-based shares: Six Months Ended June 30, Restricted Stock 2024 2023 Weighted-average grant date fair value $ 32.43 $ 45.00 Total fair value of restricted shares that vested (in thousands) $ 6,180 $ 9,622 |
Financing (Tables)
Financing (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
Debt Disclosure [Abstract] | |
Schedule of Forward Contracts Indexed to Issuer's Equity | Gross cash proceeds shown below were reduced by $1.0 million in issuance costs resulting in net cash proceeds of $198.2 million. Forward completion Initial forward price Shares Settlement price Settlement amount (in thousands) March 15, 2023 $ 48.49 504,452 $ 49.00 $ 24,720 March 20, 2023 48.30 528,082 48.78 25,758 May 30, 2023 47.56 244,639 47.99 11,741 June 30, 2023 44.87 804,477 45.07 36,257 September 26, 2023 44.03 2,283,860 44.11 100,734 4,365,510 $ 199,210 |
Schedule of Derivative Liabilities at Fair Value | As of June 30, 2024, PNMR’s hedging agreements are as follows: Variable Rate Established Effective Date Maturity Date Debt Hedged Fixed Rate (In millions) (Percent) January 1, 2024 December 31, 2024 $ 100.0 3.32 % January 1, 2024 December 31, 2024 100.0 3.32 January 1, 2024 December 31, 2024 100.0 3.38 January 1, 2024 December 31, 2024 150.0 3.62 January 1, 2024 December 31, 2024 150.0 3.57 January 1, 2025 December 31, 2025 100.0 4.18 January 1, 2025 December 31, 2025 100.0 4.18 January 1, 2025 December 31, 2025 100.0 3.99 |
Schedule of Short-term Debt | Short-term debt outstanding consists of: June 30, 2024 December 31, 2023 Balance Outstanding Weighted Average Interest Rate Balance Outstanding Weighted Average Interest Rate (In thousands) (In thousands) PNM: PNM Revolving Credit Facility $ 30,600 6.67% $ 107,500 6.69% PNM New Mexico Credit Facility 40,000 6.69 30,000 6.71 70,600 137,500 TNMP Revolving Credit Facility 100,600 6.31 55,100 6.32 PNMR Revolving Credit Facility 155,200 6.93 69,300 6.96 $ 326,400 $ 261,900 |
Pension and Other Postretirem_2
Pension and Other Postretirement Benefit Plans (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
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 June 30, Pension Plan OPEB Plan Executive Retirement Program 2024 2023 2024 2023 2024 2023 (In thousands) Components of Net Periodic Benefit Cost Service cost $ — $ — $ — $ — $ — $ — Interest cost 5,428 5,914 597 676 124 135 Expected return on plan assets (7,757) (7,299) (1,391) (1,243) — — Amortization of net loss 2,662 2,645 — — 50 38 Amortization of prior service cost — — — — — — Net Periodic Benefit Cost (Income) $ 333 $ 1,260 $ (794) $ (567) $ 174 $ 173 Six Months Ended June 30, Pension Plan OPEB Plan Executive Retirement Program 2024 2023 2024 2023 2024 2023 (In thousands) Components of Net Periodic Benefit Cost Service cost $ — $ — $ — $ — $ — $ — Interest cost 10,855 11,827 1,194 1,352 248 270 Expected return on plan assets (15,514) (14,598) (2,782) (2,485) — — Amortization of net loss 5,323 5,291 — — 100 76 Amortization of prior service cost — — — — — — Net Periodic Benefit Cost (Income) $ 664 $ 2,520 $ (1,588) $ (1,133) $ 348 $ 346 The following table presents the components of the TNMP Plans’ net periodic benefit cost: Three Months Ended June 30, Pension Plan OPEB Plan Executive Retirement Program 2024 2023 2024 2023 2024 2023 (In thousands) Components of Net Periodic Benefit Cost Service cost $ — $ — $ 6 $ 6 $ — $ — Interest cost 554 600 97 107 4 3 Expected return on plan assets (687) (675) (128) (121) — — Amortization of net (gain) loss 139 109 (160) (190) — — Amortization of prior service cost — — — — — — Net Periodic Benefit Cost (Income) $ 6 $ 34 $ (185) $ (198) $ 4 $ 3 Six Months Ended June 30, Pension Plan OPEB Plan Executive Retirement Program 2024 2023 2024 2023 2024 2023 (In thousands) Components of Net Periodic Benefit Cost Service cost $ — $ — $ 11 $ 11 $ — $ — Interest cost 1,107 1,201 193 213 8 6 Expected return on plan assets (1,374) (1,349) (257) (241) — — Amortization of net (gain) loss 278 219 (321) (380) — — Amortization of prior service cost — — — — — — Net Periodic Benefit Cost (Income) $ 11 $ 71 $ (374) $ (397) $ 8 $ 6 |
Regulatory and Rate Matters (Ta
Regulatory and Rate Matters (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
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) May 12, 2023 $ 150.5 $ 19.4 September 6, 2023 21.4 4.2 March 15, 2024 97.4 13.1 |
Schedule Of Interim Distribution Rate Increases | The following sets forth TNMP’s recent interim distribution rate increases: Effective Date Approved Increase in Rate Base Annual Increase in Revenue (In millions) September 1, 2022 $ 95.7 $ 6.8 September 1, 2023 157.0 14.5 July 28, 2024 205.9 15.6 |
Lease Commitments (Tables)
Lease Commitments (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
Leases [Abstract] | |
Assets and Liabilities, Lessee | Information related to the Company’s operating leases recorded on the Condensed Consolidated Balance Sheets is presented below: June 30, 2024 December 31, 2023 PNM TNMP PNMR Consolidated PNM TNMP PNMR Consolidated (In thousands) Operating leases: Operating lease assets, net of amortization $ 175,363 $ 1,362 $ 177,285 $ 180,370 $ 1,814 $ 182,201 Current portion of operating lease liabilities 9,963 835 10,834 11,371 895 12,267 Long-term portion of operating lease liabilities 158,609 457 159,592 166,191 809 167,000 Information related to the Company’s financing leases recorded on the Condensed Consolidated Balance Sheets is presented below: June 30, 2024 December 31, 2023 PNM TNMP PNMR Consolidated PNM TNMP PNMR Consolidated (In thousands) Financing leases: Non-utility property $ 22,594 $ 24,054 $ 47,023 $ 25,425 $ 24,487 $ 49,981 Accumulated depreciation (10,859) (12,261) (23,199) (11,984) (11,869) (23,905) Non-utility property, net 11,735 11,793 23,824 13,441 12,618 26,076 Other current liabilities $ 3,710 $ 4,476 $ 8,268 $ 4,146 $ 4,616 $ 8,776 Other deferred credits 8,045 7,338 15,601 9,300 8,023 17,326 Information concerning the weighted average remaining lease terms and the weighted average discount rates used to determine the Company’s lease liabilities as of June 30, 2024 is presented below: PNM TNMP PNMR Consolidated Weighted average remaining lease term (years): Operating leases 16.74 1.41 16.60 Financing leases 3.54 2.95 3.25 Weighted average discount rate: Operating leases 5.65 % 4.26 % 5.64 % Financing leases 4.77 % 4.96 % 4.87 % |
Lease, Cost | Information for the components of lease expense is as follows: Three Months Ended June 30, 2024 Six Months Ended June 30, 2024 PNM TNMP PNMR Consolidated PNM TNMP PNMR Consolidated (In thousands) Operating lease cost: Battery storage leases $ 2,947 $ — $ 2,947 $ 5,893 $ — $ 5,893 Other operating leases 1,908 237 2,157 3,967 507 4,486 Amounts capitalized (28) (209) (237) (63) (442) (505) Total operating lease expense 4,827 28 4,867 9,797 65 9,874 Financing lease cost: Amortization of right-of-use assets 1,120 1,315 2,463 2,337 2,631 5,005 Interest on lease liabilities 143 147 294 287 299 591 Amounts capitalized (756) (1,161) (1,917) (1,597) (2,343) (3,940) Total financing lease expense 507 301 840 1,027 587 1,656 Variable lease expense 433 — 433 793 — 793 Short-term lease expense 148 7 165 352 12 381 Total lease expense for the period $ 5,915 $ 336 $ 6,305 $ 11,969 $ 664 $ 12,704 Three Months Ended June 30, 2023 Six Months Ended June 30, 2023 PNM TNMP PNMR Consolidated PNM TNMP PNMR Consolidated (In thousands) Operating lease cost: $ 2,468 $ 401 $ 2,869 $ 6,376 $ 830 $ 7,206 Amounts capitalized (103) (331) (434) (263) (684) (947) Total operating lease expense 2,365 70 2,435 6,113 146 6,259 Financing lease cost: Amortization of right-of-use assets 1,123 1,098 2,235 2,132 2,162 4,329 Interest on lease liabilities 140 112 252 262 223 486 Amounts capitalized (778) (699) (1,477) (1,469) (1,699) (3,167) Total financing lease expense 485 511 1,010 925 686 1,648 Variable lease expense 360 — 360 622 — 622 Short-term lease expense 145 1 149 292 1 299 Total lease expense for the period $ 3,355 $ 582 $ 3,954 $ 7,952 $ 833 $ 8,828 |
Schedule of Leases, Supplemental Cash Flows | Supplemental cash flow information related to the Company’s leases is as follows: Six Months Ended Six Months Ended June 30, 2024 June 30, 2023 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 $ 13,701 $ 26 $ 13,737 $ 16,208 $ 155 $ 16,363 Operating cash flows from financing leases 94 53 152 88 38 127 Finance cash flows from financing leases 919 533 1,487 792 646 1,474 Non-cash information related to right-of-use assets obtained in exchange for lease obligations: Operating leases $ 27 $ 69 $ 663 $ 94 $ 6 $ 100 Financing leases 831 1,736 2,885 4,793 1,783 6,576 |
Lessee, Operating Lease, Liability, Maturity | Future expected lease payments are shown below: As of June 30, 2024 PNM TNMP PNMR Consolidated Operating Operating Financing Battery Storage Other Financing Operating Financing Battery Storage Other (In thousands) Remainder of 2024 $ 2,202 $ 5,893 $ 161 $ 2,595 $ 454 $ 4,846 $ 5,893 $ 648 2025 3,797 11,786 7,082 4,471 787 8,357 11,786 7,935 2026 3,269 11,786 7,031 3,235 90 6,592 11,786 7,190 2027 2,026 11,786 7,035 1,800 14 3,914 11,786 7,120 2028 913 11,786 7,038 501 11 1,426 11,786 7,122 Later years 614 172,254 10,587 113 — 728 172,254 11,013 Total minimum lease payments 12,821 225,291 38,934 12,715 1,356 25,863 225,291 41,028 Less: Imputed interest 1,066 90,546 5,107 901 64 1,994 90,546 5,347 Lease liabilities $ 11,755 $ 134,745 $ 33,827 $ 11,814 $ 1,292 $ 23,869 $ 134,745 $ 35,681 |
Finance Lease, Liability, Maturity | Future expected lease payments are shown below: As of June 30, 2024 PNM TNMP PNMR Consolidated Operating Operating Financing Battery Storage Other Financing Operating Financing Battery Storage Other (In thousands) Remainder of 2024 $ 2,202 $ 5,893 $ 161 $ 2,595 $ 454 $ 4,846 $ 5,893 $ 648 2025 3,797 11,786 7,082 4,471 787 8,357 11,786 7,935 2026 3,269 11,786 7,031 3,235 90 6,592 11,786 7,190 2027 2,026 11,786 7,035 1,800 14 3,914 11,786 7,120 2028 913 11,786 7,038 501 11 1,426 11,786 7,122 Later years 614 172,254 10,587 113 — 728 172,254 11,013 Total minimum lease payments 12,821 225,291 38,934 12,715 1,356 25,863 225,291 41,028 Less: Imputed interest 1,066 90,546 5,107 901 64 1,994 90,546 5,347 Lease liabilities $ 11,755 $ 134,745 $ 33,827 $ 11,814 $ 1,292 $ 23,869 $ 134,745 $ 35,681 |
Related Party Transactions (Tab
Related Party Transactions (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
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 Six Months Ended June 30, June 30, 2024 2023 2024 2023 (In thousands) Services billings: PNMR to PNM $ 31,023 $ 29,142 $ 66,430 $ 60,642 PNMR to TNMP 12,885 11,333 27,121 23,727 PNM to TNMP 109 104 190 169 TNMP to PNMR — 35 10 71 PNMR to NMRD — 82 66 164 Renewable energy purchases: PNM from NMRD — 3,748 1,523 6,109 Interest billings: PNMR to PNM 25 7 39 10 PNM to PNMR 154 143 309 273 PNMR to TNMP 22 117 179 128 Income tax sharing payments: PNMR to PNM — — — — TNMP to PNMR — — — — |
Equity Method Investment (Table
Equity Method Investment (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
Equity Method Investments and Joint Ventures [Abstract] | |
Marketable Securities | Summarized financial information for NMRD through the closing date of the sale is as follows: Results of Operations Three Months Ended June 30, Six Months Ended June 30, 2024 2023 2024 2023 (In thousands) Operating revenues $ — $ 3,975 $ 3,204 $ 6,505 Operating expenses — 1,965 3,378 4,384 Net earnings (loss) $ — $ 2,010 $ (174) $ 2,121 Financial Position June 30, December 31, 2024 2023 (In thousands) Current assets $ — $ 2,589 Net property, plant, and equipment — 235,791 Non-current assets — 1,849 Total assets — 240,229 Current liabilities — 730 Non-current liabilities — 358 Owners’ equity $ — $ 239,141 |
Significant Accounting Polici_3
Significant Accounting Policies and Responsibility for Financial Statements (Details) - USD ($) | 1 Months Ended | 3 Months Ended | 6 Months Ended | |||
Jul. 31, 2024 | Aug. 31, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Subsequent Event [Line Items] | ||||||
Payment defaults under agreements | $ 0 | $ 0 | ||||
Dividends declared per common share (in dollars per share) | $ 0.3675 | $ 0.3875 | $ 0.3675 | $ 0.7750 | $ 0.7350 | |
Dividends declared on common stock | $ 34,952,000 | $ 31,545,000 | ||||
PNMR | ||||||
Subsequent Event [Line Items] | ||||||
Equity contribution from parent | $ 55,000,000 | $ 0 | 55,000,000 | 0 | ||
Texas-New Mexico Power Company | ||||||
Subsequent Event [Line Items] | ||||||
Dividends declared on common stock | 0 | 0 | 0 | 0 | ||
Public Service Company of New Mexico | ||||||
Subsequent Event [Line Items] | ||||||
Equity contribution from parent | 55,000,000 | 0 | ||||
Dividends declared on common stock | $ 0 | $ 0 | $ 0 | $ 0 | ||
Subsequent Event | ||||||
Subsequent Event [Line Items] | ||||||
Dividends declared per common share (in dollars per share) | $ 0.3875 |
Segment Information - Summarize
Segment Information - Summarized Financial Information (Details) $ in Thousands | 3 Months Ended | 6 Months Ended | ||||||
Jun. 30, 2024 USD ($) | Jun. 30, 2023 USD ($) | Jun. 30, 2024 USD ($) segment | Jun. 30, 2023 USD ($) | Apr. 01, 2024 USD ($) | Dec. 31, 2023 USD ($) | Apr. 01, 2020 USD ($) | Apr. 01, 2018 USD ($) | |
Segment Reporting Information, Profit (Loss) [Abstract] | ||||||||
Electric operating revenues | $ 488,102 | $ 477,156 | $ 924,979 | $ 1,021,233 | ||||
Utility margin | 198,498 | 181,627 | 374,426 | 368,338 | ||||
Other operating expenses | 133,300 | 133,235 | 264,096 | 258,461 | ||||
Depreciation and amortization | 94,413 | 79,139 | 187,600 | 157,213 | ||||
Operating income (loss) | 105,683 | 92,330 | 186,273 | 191,421 | ||||
Interest income (expense) | 4,470 | 5,359 | 9,050 | 10,202 | ||||
Other income (deductions) | 6,610 | 5,862 | 12,997 | 12,904 | ||||
Interest charges | (55,828) | (45,899) | (109,590) | (86,822) | ||||
Earnings before Income Taxes | 60,935 | 57,652 | 98,730 | 127,705 | ||||
Income taxes (benefit) | 8,971 | 8,229 | (3,600) | 18,009 | ||||
Net Earnings | 51,964 | 49,423 | 102,330 | 109,696 | ||||
Valencia non-controlling interest | (3,783) | (3,987) | (6,827) | (9,114) | ||||
Subsidiary preferred stock dividends | (132) | (132) | (264) | (264) | ||||
Net Earnings Available for PNM Common Stock | 48,049 | 45,304 | 95,239 | 100,318 | ||||
Total Assets | 10,583,410 | 9,626,970 | 10,583,410 | 9,626,970 | $ 10,252,605 | |||
Goodwill | 278,297 | 278,297 | 278,297 | 278,297 | 278,297 | |||
PNM | ||||||||
Segment Reporting Information, Profit (Loss) [Abstract] | ||||||||
Utility margin | 124,735 | 120,215 | 245,589 | 260,596 | ||||
Other operating expenses | 106,578 | 106,154 | 213,044 | 204,876 | ||||
Depreciation and amortization | 54,230 | 44,064 | 107,517 | 87,750 | ||||
Operating income (loss) | 58,091 | 54,415 | 109,041 | 132,319 | ||||
Interest income (expense) | 4,443 | 5,370 | 8,970 | 10,219 | ||||
Other income (deductions) | 3,869 | 3,695 | 24,415 | 10,728 | ||||
Interest charges | (25,880) | (20,766) | (50,996) | (38,888) | ||||
Earnings before Income Taxes | 40,523 | 42,714 | 91,430 | 114,378 | ||||
Income taxes (benefit) | 5,821 | 7,411 | 11,632 | 19,240 | ||||
Net Earnings | 34,702 | 35,303 | 79,798 | 95,138 | ||||
Valencia non-controlling interest | (3,783) | (3,987) | (6,827) | (9,114) | ||||
Subsidiary preferred stock dividends | (132) | (132) | (264) | (264) | ||||
Net Earnings Available for PNM Common Stock | 30,787 | 31,184 | 72,707 | 85,760 | ||||
Total Assets | 7,060,151 | 6,440,357 | 7,060,151 | 6,440,357 | ||||
Goodwill | 51,632 | 51,632 | 51,632 | 51,632 | ||||
TNMP | ||||||||
Segment Reporting Information, Profit (Loss) [Abstract] | ||||||||
Utility margin | 73,763 | 61,412 | 128,837 | 107,742 | ||||
Other operating expenses | 34,149 | 33,395 | 66,899 | 66,247 | ||||
Depreciation and amortization | 31,033 | 27,949 | 61,415 | 55,389 | ||||
Operating income (loss) | 49,315 | 38,727 | 80,053 | 60,514 | ||||
Interest income (expense) | 127 | 121 | 296 | 235 | ||||
Other income (deductions) | 2,705 | 1,512 | 3,581 | 1,648 | ||||
Interest charges | (14,451) | (11,412) | (27,787) | (21,837) | ||||
Earnings before Income Taxes | 37,696 | 28,948 | 56,143 | 40,560 | ||||
Income taxes (benefit) | 7,771 | 4,316 | 11,635 | 5,895 | ||||
Net Earnings | 29,925 | 24,632 | 44,508 | 34,665 | ||||
Valencia non-controlling interest | 0 | 0 | 0 | 0 | ||||
Subsidiary preferred stock dividends | 0 | 0 | 0 | 0 | ||||
Net Earnings Available for PNM Common Stock | 29,925 | 24,632 | 44,508 | 34,665 | ||||
Total Assets | 3,354,923 | 2,916,206 | 3,354,923 | 2,916,206 | ||||
Goodwill | 226,665 | 226,665 | 226,665 | 226,665 | ||||
Corporate and Other | ||||||||
Segment Reporting Information, Profit (Loss) [Abstract] | ||||||||
Utility margin | 0 | 0 | 0 | 0 | ||||
Other operating expenses | (7,427) | (6,314) | (15,847) | (12,662) | ||||
Depreciation and amortization | 9,150 | 7,126 | 18,668 | 14,074 | ||||
Operating income (loss) | (1,723) | (812) | (2,821) | (1,412) | ||||
Interest income (expense) | (100) | (132) | (216) | (252) | ||||
Other income (deductions) | 36 | 655 | (14,999) | 528 | ||||
Interest charges | (15,497) | (13,721) | (30,807) | (26,097) | ||||
Earnings before Income Taxes | (17,284) | (14,010) | (48,843) | (27,233) | ||||
Income taxes (benefit) | (4,621) | (3,498) | (26,867) | (7,126) | ||||
Net Earnings | (12,663) | (10,512) | (21,976) | (20,107) | ||||
Valencia non-controlling interest | 0 | 0 | 0 | 0 | ||||
Subsidiary preferred stock dividends | 0 | 0 | 0 | 0 | ||||
Net Earnings Available for PNM Common Stock | (12,663) | (10,512) | (21,976) | (20,107) | ||||
Total Assets | 168,336 | 270,407 | 168,336 | 270,407 | ||||
Goodwill | 0 | 0 | 0 | 0 | ||||
Energy | ||||||||
Segment Reporting Information, Profit (Loss) [Abstract] | ||||||||
Electric operating revenues | 488,102 | 477,156 | 924,979 | 1,021,233 | ||||
Cost of energy | 154,706 | 172,452 | 287,010 | 414,138 | ||||
Utility margin | 333,396 | 304,704 | 637,969 | 607,095 | ||||
Energy | PNM | ||||||||
Segment Reporting Information, Profit (Loss) [Abstract] | ||||||||
Electric operating revenues | 333,671 | 338,242 | 641,786 | 768,407 | ||||
Cost of energy | 114,772 | 133,609 | 212,184 | 343,462 | ||||
Utility margin | 218,899 | 204,633 | 429,602 | 424,945 | ||||
Energy | TNMP | ||||||||
Segment Reporting Information, Profit (Loss) [Abstract] | ||||||||
Electric operating revenues | 154,431 | 138,914 | 283,193 | 252,826 | ||||
Cost of energy | 39,934 | 38,843 | 74,826 | 70,676 | ||||
Utility margin | 114,497 | 100,071 | 208,367 | 182,150 | ||||
Energy | Corporate and Other | ||||||||
Segment Reporting Information, Profit (Loss) [Abstract] | ||||||||
Electric operating revenues | 0 | 0 | 0 | 0 | ||||
Cost of energy | 0 | 0 | 0 | 0 | ||||
Utility margin | 0 | 0 | $ 0 | 0 | ||||
PNM | ||||||||
Segment Reporting Information [Line Items] | ||||||||
Number of operating segments | segment | 1 | |||||||
Segment Reporting Information, Profit (Loss) [Abstract] | ||||||||
Electric operating revenues | 333,671 | 338,242 | $ 641,786 | 768,407 | ||||
Depreciation and amortization | 54,230 | 44,064 | 107,517 | 87,750 | ||||
Operating income (loss) | 58,091 | 54,415 | 109,041 | 132,319 | ||||
Interest charges | (25,880) | (20,766) | (50,996) | (38,888) | ||||
Earnings before Income Taxes | 40,523 | 42,714 | 91,430 | 114,378 | ||||
Income taxes (benefit) | 5,821 | 7,411 | 11,632 | 19,240 | ||||
Net Earnings | 34,702 | 35,303 | 79,798 | 95,138 | ||||
Valencia non-controlling interest | (3,783) | (3,987) | (6,827) | (9,114) | ||||
Subsidiary preferred stock dividends | (132) | (132) | (264) | (264) | ||||
Net Earnings Available for PNM Common Stock | 30,787 | 31,184 | 72,707 | 85,760 | ||||
Total Assets | 7,060,151 | 7,060,151 | 6,813,065 | |||||
Goodwill | 51,632 | 51,632 | $ 51,600 | 51,632 | $ 51,600 | |||
PNM | Energy | ||||||||
Segment Reporting Information, Profit (Loss) [Abstract] | ||||||||
Cost of energy | 114,772 | 133,609 | $ 212,184 | 343,462 | ||||
TNMP | ||||||||
Segment Reporting Information [Line Items] | ||||||||
Number of operating segments | segment | 1 | |||||||
Segment Reporting Information, Profit (Loss) [Abstract] | ||||||||
Electric operating revenues | 154,431 | 138,914 | $ 283,193 | 252,826 | ||||
Cost of energy | 39,934 | 38,843 | 74,826 | 70,676 | ||||
Depreciation and amortization | 31,033 | 27,949 | 61,415 | 55,389 | ||||
Operating income (loss) | 49,315 | 38,727 | 80,053 | 60,514 | ||||
Interest charges | (14,451) | (11,412) | (27,787) | (21,837) | ||||
Earnings before Income Taxes | 37,696 | 28,948 | 56,143 | 40,560 | ||||
Income taxes (benefit) | 7,771 | $ 4,316 | 11,635 | 5,895 | ||||
Net Earnings | 44,508 | $ 34,665 | ||||||
Total Assets | 3,354,923 | 3,354,923 | 3,145,031 | |||||
Goodwill | $ 226,665 | $ 226,665 | $ 226,665 | $ 226,700 |
Segment Information - Schedule
Segment Information - Schedule of Gross Margin (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Segment Reporting Information [Line Items] | ||||
Gross margin | $ 198,498 | $ 181,627 | $ 374,426 | $ 368,338 |
Transmission and distribution costs | 25,051 | 25,465 | 47,815 | 47,661 |
Depreciation and amortization | 85,263 | 72,013 | 168,932 | 143,139 |
Utility margin | 333,396 | 304,704 | 637,969 | 607,095 |
Energy Production | ||||
Segment Reporting Information [Line Items] | ||||
Energy production costs | 24,584 | 25,599 | 46,796 | 47,957 |
PNM | ||||
Segment Reporting Information [Line Items] | ||||
Gross margin | 124,735 | 120,215 | 245,589 | 260,596 |
Transmission and distribution costs | 15,350 | 14,755 | 29,700 | 28,642 |
Depreciation and amortization | 54,230 | 44,064 | 107,517 | 87,750 |
Utility margin | 218,899 | 204,633 | 429,602 | 424,945 |
PNM | Energy Production | ||||
Segment Reporting Information [Line Items] | ||||
Energy production costs | 24,584 | 25,599 | 46,796 | 47,957 |
TNMP | ||||
Segment Reporting Information [Line Items] | ||||
Gross margin | 73,763 | 61,412 | 128,837 | 107,742 |
Transmission and distribution costs | 9,701 | 10,710 | 18,115 | 19,019 |
Depreciation and amortization | 31,033 | 27,949 | 61,415 | 55,389 |
Utility margin | 114,497 | 100,071 | 208,367 | 182,150 |
TNMP | Energy Production | ||||
Segment Reporting Information [Line Items] | ||||
Energy production costs | 0 | 0 | 0 | 0 |
Corporate and Other | ||||
Segment Reporting Information [Line Items] | ||||
Gross margin | 0 | 0 | 0 | 0 |
Transmission and distribution costs | 0 | 0 | 0 | 0 |
Depreciation and amortization | 0 | 0 | 0 | 0 |
Utility margin | 0 | 0 | 0 | 0 |
Corporate and Other | Energy Production | ||||
Segment Reporting Information [Line Items] | ||||
Energy production costs | $ 0 | $ 0 | $ 0 | $ 0 |
Accumulated Other Comprehensi_3
Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Accumulated Other Comprehensive Income (Loss) [Roll Forward] | ||||
Beginning balance | $ 2,404,730 | $ 2,264,802 | $ 2,399,051 | $ 2,244,926 |
Total Other Comprehensive Income (Loss) | (2,292) | 5,119 | (7,060) | 6,813 |
Ending balance | 2,451,680 | 2,313,596 | 2,451,680 | 2,313,596 |
Total | ||||
Accumulated Other Comprehensive Income (Loss) [Roll Forward] | ||||
Beginning balance | (67,608) | (64,354) | (62,840) | (66,048) |
Amounts reclassified from AOCI (pre-tax) | (4,570) | 1,005 | ||
Income tax impact of amounts reclassified | 1,161 | (255) | ||
Other OCI changes (pre-tax) | (4,894) | 8,127 | ||
Income tax impact of other OCI changes | 1,243 | (2,064) | ||
Total Other Comprehensive Income (Loss) | (2,292) | 5,119 | (7,060) | 6,813 |
Ending balance | (69,900) | (59,235) | (69,900) | (59,235) |
Fair Value Adjustment for Cash Flow Hedges | ||||
Accumulated Other Comprehensive Income (Loss) [Roll Forward] | ||||
Beginning balance | 3,665 | 8,287 | ||
Amounts reclassified from AOCI (pre-tax) | 5,563 | 1,197 | ||
Income tax impact of amounts reclassified | (1,413) | (304) | ||
Other OCI changes (pre-tax) | (4,307) | 3,567 | ||
Income tax impact of other OCI changes | 1,094 | (906) | ||
Total Other Comprehensive Income (Loss) | 937 | 3,554 | ||
Ending balance | 4,602 | 11,841 | 4,602 | 11,841 |
PNM | ||||
Accumulated Other Comprehensive Income (Loss) [Roll Forward] | ||||
Beginning balance | 2,034,870 | 2,017,995 | 2,000,775 | 1,960,324 |
Total Other Comprehensive Income (Loss) | (1,131) | (219) | (7,997) | 3,259 |
Ending balance | 2,119,459 | 2,047,702 | 2,119,459 | 2,047,702 |
PNM | Total | ||||
Accumulated Other Comprehensive Income (Loss) [Roll Forward] | ||||
Beginning balance | (73,371) | (70,857) | (66,505) | (74,335) |
Amounts reclassified from AOCI (pre-tax) | (10,133) | (192) | ||
Income tax impact of amounts reclassified | 2,574 | 49 | ||
Other OCI changes (pre-tax) | (587) | 4,560 | ||
Income tax impact of other OCI changes | 149 | (1,158) | ||
Total Other Comprehensive Income (Loss) | (1,131) | (219) | (7,997) | 3,259 |
Ending balance | (74,502) | (71,076) | (74,502) | (71,076) |
PNM | Unrealized Gains on Available-for-Sale Debt Securities | ||||
Accumulated Other Comprehensive Income (Loss) [Roll Forward] | ||||
Beginning balance | 10,652 | 7,422 | ||
Amounts reclassified from AOCI (pre-tax) | (12,566) | (2,580) | ||
Income tax impact of amounts reclassified | 3,192 | 655 | ||
Other OCI changes (pre-tax) | (587) | 4,560 | ||
Income tax impact of other OCI changes | 149 | (1,158) | ||
Total Other Comprehensive Income (Loss) | (9,812) | 1,477 | ||
Ending balance | 840 | 8,899 | 840 | 8,899 |
PNM | Pension Liability Adjustment | ||||
Accumulated Other Comprehensive Income (Loss) [Roll Forward] | ||||
Beginning balance | (77,157) | (81,757) | ||
Amounts reclassified from AOCI (pre-tax) | 2,433 | 2,388 | ||
Income tax impact of amounts reclassified | (618) | (606) | ||
Other OCI changes (pre-tax) | 0 | 0 | ||
Income tax impact of other OCI changes | 0 | 0 | ||
Total Other Comprehensive Income (Loss) | 1,815 | 1,782 | ||
Ending balance | $ (75,342) | $ (79,975) | $ (75,342) | $ (79,975) |
Earnings Per Share (Details)
Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] | ||||
Net Earnings Attributable to PNMR | $ 48,049 | $ 45,304 | $ 95,239 | $ 100,318 |
Average Number of Common Shares: | ||||
Outstanding during period (in shares) | 90,200 | 85,835 | 90,200 | 85,835 |
Vested awards of restricted stock (in shares) | 304 | 250 | 293 | 258 |
Average Shares – Basic (in shares) | 90,504 | 86,085 | 90,493 | 86,093 |
Dilutive Effect of Common Stock Equivalents: | ||||
Restricted stock (in shares) | 48 | 39 | 40 | 38 |
Average Shares – Diluted (in shares) | 90,552 | 86,129 | 90,533 | 86,133 |
Net Earnings Per Share of Common Stock: | ||||
Basic (in dollars per share) | $ 0.53 | $ 0.53 | $ 1.05 | $ 1.17 |
Diluted (in dollars per share) | $ 0.53 | $ 0.53 | $ 1.05 | $ 1.16 |
2023 Forward Sale Agreements | ||||
Dilutive Effect of Common Stock Equivalents: | ||||
2023 Forward Sale Agreements (in shares) | 0 | 5 | 0 | 2 |
Electric Operating Revenues - N
Electric Operating Revenues - Narrative (Details) | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2024 USD ($) utility | Jun. 30, 2023 USD ($) | Jun. 30, 2024 USD ($) utility | Jun. 30, 2023 USD ($) | Dec. 31, 2023 USD ($) | |
Disaggregation of Revenue [Line Items] | |||||
Number of regulated utilities | utility | 2 | 2 | |||
Other receivables, allowance for credit loss, period increase | $ 0 | $ 0 | $ 0 | $ 0 | |
Contract assets | 27,100,000 | 27,100,000 | $ 22,100,000 | ||
PNM | |||||
Disaggregation of Revenue [Line Items] | |||||
Accounts receivable | $ 82,400,000 | $ 82,400,000 | $ 93,600,000 |
Electric Operating Revenues - D
Electric Operating Revenues - Disaggregation of revenues (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | $ 473,220 | $ 462,101 | $ 904,310 | $ 993,133 |
Alternative revenue programs | 14,714 | 12,467 | 20,007 | 17,226 |
Other electric operating revenues | 168 | 2,588 | 662 | 10,874 |
Total Electric Operating Revenues | 488,102 | 477,156 | 924,979 | 1,021,233 |
PNM | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 332,673 | 332,077 | 638,388 | 746,631 |
Alternative revenue programs | 830 | 3,577 | 2,736 | 10,902 |
Other electric operating revenues | 168 | 2,588 | 662 | 10,874 |
Total Electric Operating Revenues | 333,671 | 338,242 | 641,786 | 768,407 |
TNMP | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 140,547 | 130,024 | 265,922 | 246,502 |
Alternative revenue programs | 13,884 | 8,890 | 17,271 | 6,324 |
Other electric operating revenues | 0 | 0 | 0 | 0 |
Total Electric Operating Revenues | 154,431 | 138,914 | 283,193 | 252,826 |
Energy | ||||
Disaggregation of Revenue [Line Items] | ||||
Total Electric Operating Revenues | 488,102 | 477,156 | 924,979 | 1,021,233 |
Energy | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 168,378 | 149,507 | 330,258 | 305,758 |
Energy | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 150,428 | 143,227 | 285,309 | 276,018 |
Energy | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 42,118 | 39,086 | 76,743 | 71,327 |
Energy | Public authority | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 6,956 | 6,974 | 13,070 | 13,011 |
Energy | Economy energy service | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 4,033 | 10,731 | 11,595 | 20,041 |
Energy | PNM | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 121,065 | 108,016 | 241,450 | 227,901 |
Energy | PNM | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 109,929 | 105,262 | 209,266 | 203,323 |
Energy | PNM | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 34,201 | 26,156 | 58,970 | 45,633 |
Energy | PNM | Public authority | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 5,216 | 5,305 | 9,614 | 9,723 |
Energy | PNM | Economy energy service | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 4,033 | 10,731 | 11,595 | 20,041 |
Energy | TNMP | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 47,313 | 41,491 | 88,808 | 77,857 |
Energy | TNMP | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 40,499 | 37,965 | 76,043 | 72,695 |
Energy | TNMP | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 7,917 | 12,930 | 17,773 | 25,694 |
Energy | TNMP | Public authority | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 1,740 | 1,669 | 3,456 | 3,288 |
Energy | TNMP | Economy energy service | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 0 | 0 | 0 | 0 |
Transmission | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 75,449 | 72,984 | 147,407 | 152,050 |
Transmission | PNM | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 33,333 | 37,922 | 69,482 | 86,930 |
Transmission | TNMP | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 42,116 | 35,062 | 77,925 | 65,120 |
Wholesale energy sales | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 23,507 | 37,308 | 35,197 | 150,294 |
Wholesale energy sales | PNM | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 23,507 | 37,308 | 35,197 | 150,294 |
Wholesale energy sales | TNMP | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 0 | 0 | 0 | 0 |
Miscellaneous | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 2,351 | 2,284 | 4,731 | 4,634 |
Miscellaneous | PNM | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | 1,389 | 1,377 | 2,814 | 2,786 |
Miscellaneous | TNMP | ||||
Disaggregation of Revenue [Line Items] | ||||
Total revenues from contracts with customers | $ 962 | $ 907 | $ 1,917 | $ 1,848 |
Variable Interest Entities - Na
Variable Interest Entities - Narrative (Details) $ in Millions | 3 Months Ended | 6 Months Ended | ||||
Jun. 30, 2024 USD ($) MW | Jun. 30, 2023 USD ($) | Jun. 30, 2024 USD ($) MW | Jun. 30, 2023 USD ($) | Dec. 05, 2022 MW | Jan. 31, 2016 USD ($) | |
San Juan Generating Station | Coal supply | ||||||
Variable Interest Entity [Line Items] | ||||||
Cash used to support bank letter or credit arrangement | $ 30.3 | |||||
PNM | ||||||
Variable Interest Entity [Line Items] | ||||||
Number of megawatts purchased (in megawatts) | MW | 64.1 | |||||
PNM | Valencia | ||||||
Variable Interest Entity [Line Items] | ||||||
Payment for fixed costs | $ 5.1 | $ 5.1 | $ 10.2 | $ 10 | ||
Payment for variable costs | $ 0.4 | $ 1.1 | $ 0.5 | $ 2.7 | ||
Long-term contract option to purchase, ownership percentage (up to) | 50% | |||||
Long-term contract option to purchase, purchase price - percentage of adjusted NBV | 50% | |||||
Long-term contract option to purchase, purchase price - percentage of FMV | 50% | |||||
PNM | Purchased through May 2028 | Valencia | ||||||
Variable Interest Entity [Line Items] | ||||||
Number of megawatts purchased (in megawatts) | MW | 155 | 155 |
Variable Interest Entities - Sc
Variable Interest Entities - Schedule of Operations for Valencia (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | Dec. 31, 2023 | |
Results of Operations | |||||
Operating revenues | $ 488,102 | $ 477,156 | $ 924,979 | $ 1,021,233 | |
Operating expenses | 382,419 | 384,826 | 738,706 | 829,812 | |
Earnings attributable to non-controlling interest | 3,783 | 3,987 | 6,827 | 9,114 | |
Financial Position | |||||
Current assets | 537,654 | 537,654 | $ 475,543 | ||
Total assets | 10,583,410 | 9,626,970 | 10,583,410 | 9,626,970 | 10,252,605 |
Current liabilities | 1,138,637 | 1,138,637 | 1,230,760 | ||
Owners’ equity – non-controlling interest | 48,932 | 48,932 | 49,958 | ||
Public Service Company of New Mexico | |||||
Results of Operations | |||||
Operating revenues | 333,671 | 338,242 | 641,786 | 768,407 | |
Operating expenses | 275,580 | 283,827 | 532,745 | 636,088 | |
Earnings attributable to non-controlling interest | 3,783 | 3,987 | 6,827 | 9,114 | |
Financial Position | |||||
Current assets | 436,272 | 436,272 | 377,837 | ||
Total assets | 7,060,151 | 7,060,151 | 6,813,065 | ||
Current liabilities | 668,281 | 668,281 | 839,194 | ||
Owners’ equity – non-controlling interest | 48,932 | 48,932 | 49,958 | ||
Valencia | Public Service Company of New Mexico | |||||
Results of Operations | |||||
Operating revenues | 5,476 | 6,144 | 10,665 | 12,748 | |
Operating expenses | 1,693 | 2,157 | 3,838 | 3,634 | |
Earnings attributable to non-controlling interest | 3,783 | $ 3,987 | 6,827 | $ 9,114 | |
Financial Position | |||||
Current assets | 3,664 | 3,664 | 3,422 | ||
Net property, plant, and equipment | 45,832 | 45,832 | 47,253 | ||
Total assets | 49,496 | 49,496 | 50,675 | ||
Current liabilities | 564 | 564 | 717 | ||
Owners’ equity – non-controlling interest | $ 48,932 | $ 48,932 | $ 49,958 |
Variable Interest Entities - _2
Variable Interest Entities - Schedule of Impact on Results of Operation (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Variable Interest Entity [Line Items] | ||||
Depreciation and amortization | $ 206,365 | $ 173,851 | ||
Interest charges | $ 55,828 | $ 45,899 | 109,590 | 86,822 |
Public Service Company of New Mexico | ||||
Variable Interest Entity [Line Items] | ||||
Depreciation and amortization | 120,385 | 100,225 | ||
Interest charges | 25,880 | $ 20,766 | 50,996 | $ 38,888 |
Valencia | Public Service Company of New Mexico | ||||
Variable Interest Entity [Line Items] | ||||
Operating Revenues | 5,811 | 11,756 | ||
Depreciation and amortization | 821 | 1,643 | ||
Interest charges | 5,039 | 10,064 | ||
Other | (49) | 49 | ||
Net Earnings | $ 0 | $ 0 |
Variable Interest Entities - _3
Variable Interest Entities - Schedule of Impact on Balance Sheet (Details) - USD ($) $ in Thousands | Jun. 30, 2024 | Dec. 31, 2023 |
Variable Interest Entity [Line Items] | ||
Regulatory Assets - Current | $ 59,397 | $ 73,046 |
Current Installments of Long-Term Debt | 240,770 | 280,169 |
Regulatory Liabilities - Current | 76,131 | 140,005 |
Long-Term Debt | 4,596,994 | 4,241,642 |
Public Service Company of New Mexico | ||
Variable Interest Entity [Line Items] | ||
Regulatory Assets - Current | 49,791 | 72,996 |
Current Installments of Long-Term Debt | 109,844 | 200,222 |
Regulatory Liabilities - Current | 75,443 | 134,846 |
Long-Term Debt | 2,351,460 | 2,061,558 |
Valencia | Public Service Company of New Mexico | ||
Variable Interest Entity [Line Items] | ||
Regulatory Assets - Current | 0 | 2,724 |
Securitized Cost (included in Deferred Regulatory Assets) | 338,986 | 340,629 |
Current Installments of Long-Term Debt | 5,935 | 2,529 |
Accrued Interest | 12,509 | 2,502 |
Regulatory Liabilities - Current | 2,401 | 0 |
Long-Term Debt | 335,172 | 338,521 |
Valencia | Public Service Company of New Mexico | Other Current Assets | ||
Variable Interest Entity [Line Items] | ||
Restricted Cash | 15,318 | 0 |
Valencia | Public Service Company of New Mexico | Other Deferred Charges | ||
Variable Interest Entity [Line Items] | ||
Restricted Cash | $ 1,767 | $ 1,728 |
Fair Value of Derivative and _3
Fair Value of Derivative and Other Financial Instruments - Narrative (Details) | 4 Months Ended | |||
Apr. 23, 2024 MW | Sep. 30, 2023 MW | Jun. 30, 2024 USD ($) | Dec. 31, 2023 USD ($) | |
Debt Securities, Available-for-sale [Line Items] | ||||
Obligations to return cash | $ 200,000 | $ 200,000 | ||
PNM | ||||
Debt Securities, Available-for-sale [Line Items] | ||||
Amounts recognized for right to reclaim cash | 0 | 0 | ||
Cash collateral under margin arrangements | 600,000 | 200,000 | ||
PNM | Recurring | ||||
Debt Securities, Available-for-sale [Line Items] | ||||
Available-for-sale debt securities | 402,386,000 | |||
PNM | Nuclear Decommissioning Trust | Recurring | ||||
Debt Securities, Available-for-sale [Line Items] | ||||
Available-for-sale debt securities | 370,900,000 | 361,000,000 | ||
PNM | SJGS Decommissioning Trust | Recurring | ||||
Debt Securities, Available-for-sale [Line Items] | ||||
Available-for-sale debt securities | 9,600,000 | 12,300,000 | ||
PNM | Mine Reclamation Trust | Recurring | ||||
Debt Securities, Available-for-sale [Line Items] | ||||
Available-for-sale debt securities | 60,700,000 | 71,100,000 | ||
PNM | Commodity derivatives | Designated as Hedging Instrument | ||||
Debt Securities, Available-for-sale [Line Items] | ||||
Other current assets | 846,000 | 826,000 | ||
Current derivative liability | $ 4,558,000 | 0 | ||
PNM | Portfolio One | ||||
Debt Securities, Available-for-sale [Line Items] | ||||
Number of megawatts available in purchase power agreement (in megawatts) | MW | 150 | 85 | ||
PNM | Portfolio Two | ||||
Debt Securities, Available-for-sale [Line Items] | ||||
Number of megawatts available in purchase power agreement (in megawatts) | MW | 100 | 50 | ||
PNM | Fuel and purchased power costs | Commodity derivatives | Designated as Hedging Instrument | ||||
Debt Securities, Available-for-sale [Line Items] | ||||
Other current assets | 800,000 | |||
Current derivative liability | $ 0 |
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 | Jun. 30, 2024 | Dec. 31, 2023 |
Derivatives, Fair Value [Line Items] | ||
Other current assets | $ 846 | $ 826 |
Other current liabilities | (4,558) | 0 |
Total investment securities | $ (3,712) | $ 826 |
Fair Value of Derivative and _5
Fair Value of Derivative and Other Financial Instruments - Schedule of Commodity Contract Volume Positions (Details) | 6 Months Ended | 12 Months Ended | ||
Jun. 30, 2024 MMBTU | Jun. 30, 2024 MWh | Dec. 31, 2023 MMBTU | Dec. 31, 2023 MWh | |
Commodity derivatives | Designated as Hedging Instrument | Public Service Company of New Mexico | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Economic Hedges (in mmbtu and mwh) | 0 | 66,790 | 0 | (15,360) |
Fair Value of Derivative and _6
Fair Value of Derivative and Other Financial Instruments - Schedule of Commodity Contract Contingent Consideration (Details) - USD ($) $ in Thousands | Jun. 30, 2024 | Dec. 31, 2023 |
Fair Value Disclosures [Abstract] | ||
Contractual Liability | $ 4,558 | $ 0 |
Existing Cash Collateral | 0 | 0 |
Net Exposure | $ 4,558 | $ 0 |
Fair Value of Derivative and _7
Fair Value of Derivative and Other Financial Instruments - Investments in NDT and Gross Realized Losses (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Equity securities: | ||||
Net gains (losses) from equity securities sold | $ 6,272 | $ 2,792 | $ 16,143 | $ 1,947 |
Net gains (losses) from equity securities still held | (3,880) | 1,142 | (5,085) | 8,619 |
Total net gains on equity securities | 2,392 | 3,934 | 11,058 | 10,566 |
Available-for-sale debt securities: | ||||
Net gains (losses) on debt securities | (1,834) | (157) | 7,498 | (347) |
Net gains on investment securities | $ 558 | $ 3,777 | $ 18,556 | $ 10,219 |
Fair Value of Derivative and _8
Fair Value of Derivative and Other Financial Instruments - Gross Realized (Losses) (Details) - PNM - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Debt Securities, Available-for-sale [Line Items] | ||||
(Increase)/decrease in other than temporary losses of available-for-sale securities, net portion recognized in earnings | $ 1,600 | $ 1,400 | $ 15,000 | $ 3,400 |
Proceeds from sales | 110,240 | 183,566 | 412,750 | 274,777 |
Gross realized gains | 7,549 | 7,014 | 21,228 | 10,442 |
Gross realized (losses) | $ (4,661) | $ (5,741) | $ (12,573) | $ (12,212) |
Fair Value of Derivative and _9
Fair Value of Derivative and Other Financial Instruments - Maturities of Debt Securities (Details) - PNMR and PNM $ in Thousands | Jun. 30, 2024 USD ($) |
Available-for-Sale | |
Within 1 year | $ 26,903 |
After 1 year through 5 years | 11,678 |
After 5 years through 10 years | 9,426 |
After 10 years through 15 years | 10,668 |
After 15 years through 20 years | 5,467 |
After 20 years | 497 |
Available-for-sale debt securities | $ 64,639 |
Fair Value of Derivative and_10
Fair Value of Derivative and Other Financial Instruments - Items Recorded and Presented by Level of Hierarchy (Details) - USD ($) $ in Thousands | 6 Months Ended | 12 Months Ended |
Jun. 30, 2024 | Dec. 31, 2023 | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Investment securities | $ 441,230 | $ 444,408 |
Fair value of long-term debt | 4,511,857 | 4,260,509 |
Carrying Amount | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Fair value of long-term debt | 4,837,764 | 4,521,811 |
PNM | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Investment securities | 441,230 | 444,408 |
Fair value of long-term debt | 2,278,988 | 2,107,588 |
PNM | Carrying Amount | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Fair value of long-term debt | 2,461,304 | 2,261,780 |
TNMP | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Fair value of long-term debt | 1,232,842 | 1,152,922 |
TNMP | Carrying Amount | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Fair value of long-term debt | 1,376,927 | 1,260,880 |
Recurring | PNM | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Available-for-sale debt securities | 402,386 | |
Uncategorized Collective Investment Trust | 38,844 | |
Investment securities | 441,230 | 444,408 |
Unrealized Gains | 1,163 | 14,316 |
Recurring | PNM | Level 1 | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Available-for-sale debt securities | 359,936 | |
Uncategorized Collective Investment Trust | 0 | |
Investment securities | 359,936 | 264,287 |
Recurring | PNM | Level 2 | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Available-for-sale debt securities | 42,450 | |
Uncategorized Collective Investment Trust | 0 | |
Investment securities | 42,450 | 180,121 |
Recurring | PNM | Cash and cash equivalents | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash and cash equivalents | 122,964 | 93,873 |
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 | 122,964 | 93,873 |
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 | 83,258 | 77,422 |
Recurring | PNM | Corporate stocks, common | Level 1 | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Equity securities | 83,258 | 77,422 |
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 | 0 | 4,323 |
Recurring | PNM | Corporate stocks, preferred | Level 1 | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Equity securities | 0 | 504 |
Recurring | PNM | Corporate stocks, preferred | Level 2 | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Equity securities | 0 | 3,819 |
Recurring | PNM | Mutual funds and other | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Equity securities | 131,525 | 57,966 |
Recurring | PNM | Mutual funds and other | Level 1 | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Equity securities | 131,525 | 57,966 |
Recurring | PNM | Mutual funds and other | Level 2 | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Equity securities | 0 | 0 |
Recurring | PNM | U.S. government | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Available-for-sale debt securities | 22,189 | 35,113 |
Unrealized Gains | 254 | 2,055 |
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 | 22,189 | 34,522 |
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 | 0 | 591 |
Recurring | PNM | International government | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Available-for-sale debt securities | 8,735 | |
Unrealized Gains | 104 | |
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 | |
Recurring | PNM | International government | Level 2 | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Available-for-sale debt securities | 8,735 | |
Recurring | PNM | Municipals | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Available-for-sale debt securities | 34,813 | 53,436 |
Unrealized Gains | 785 | 2,872 |
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 | 34,813 | 53,436 |
Recurring | PNM | Corporate and other | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Available-for-sale debt securities | 7,637 | 113,540 |
Unrealized Gains | 124 | 9,285 |
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 | $ 7,637 | $ 113,540 |
Stock-Based Compensation - Narr
Stock-Based Compensation - Narrative (Details) - USD ($) $ in Thousands | 6 Months Ended | |||||
May 03, 2024 | Apr. 08, 2024 | Dec. 04, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | Dec. 31, 2023 | |
President And Chief Operating Officer | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Retention agreement, bonus | $ 1,000 | |||||
Performance Shares | Executive | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Maximum number of shares awarded in year two (in shares) | 141,041 | |||||
Maximum number of shares awarded in year three (in shares) | 139,825 | |||||
Maximum number of shares awarded in year four (in shares) | 201,916 | |||||
Performance period | 3 years | |||||
Performance Shares | Executive | Achieved Performance Target For 2021 Through 2023 | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Maximum number of shares awarded in year one (in shares) | 80,492 | |||||
Restricted Shares and Performance Based Shares | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Unrecognized expense related to stock awards | $ 7,600 | |||||
Period of time stock expense is expected to be recognized | 1 year 8 months 12 days | |||||
Restricted Stock | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Nonvested (in shares) | 286,479 | 212,080 | ||||
Fair value of restricted stock rights | $ 6,180 | $ 9,622 | ||||
Granted (in shares) | 239,982 | |||||
Restricted Stock | President And Chief Operating Officer | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Fair value of restricted stock rights | $ 800 | |||||
Granted (in shares) | 19,851 | |||||
Performance Equity Plan | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Vesting period | 3 years | |||||
Vesting rate | 100% | |||||
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 | |||||
Performance Equity Plan | Performance Shares | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Vesting period | 3 years | |||||
Retention Agreement | Restricted Stock | Share-Based Payment Arrangement, Tranche One | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Vesting period | 24 months | |||||
Retention Agreement | Restricted Stock | Share-Based Payment Arrangement, Tranche Two | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Vesting period | 6 months | |||||
Retention Agreement | Restricted Stock | Chairman And Chief Executive Officer | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Nonvested (in shares) | 26,766 | |||||
Retention Agreement | Restricted Stock | Senior Vice President And General Counsel | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Nonvested (in shares) | 8,922 |
Stock-Based Compensation - Weig
Stock-Based Compensation - Weighted Average Assumptions (Details) - $ / shares | 6 Months Ended | |
Jun. 30, 2024 | Jun. 30, 2023 | |
Restricted Shares and Performance Based Shares | ||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||
Expected quarterly dividends per share (in dollars per share) | $ 0.3875 | $ 0.3675 |
Risk-free interest rate | 4.27% | 4.46% |
Market-Based Shares | ||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||
Risk-free interest rate | 4.31% | |
Dividend yield | 4.21% | |
Expected volatility | 13.09% |
Stock-Based Compensation - Rest
Stock-Based Compensation - Restricted Stock Awards (Details) - Restricted Stock - $ / shares | 6 Months Ended | |
Jun. 30, 2024 | Jun. 30, 2023 | |
Restricted Stock, Shares | ||
Outstanding at beginning of period (in shares) | 212,080 | |
Granted (in shares) | 239,982 | |
Released (in shares) | (165,583) | |
Forfeited (in shares) | 0 | |
Outstanding at end of period (in shares) | 286,479 | |
Restricted Stock, Weighted- Average Grant Date Fair Value | ||
Outstanding at beginning of period (in dollars per share) | $ 40.33 | |
Granted (in dollars per share) | 32.43 | $ 45 |
Released (in dollars per share) | 38.27 | |
Forfeited (in dollars per share) | 0 | |
Outstanding at end of period (in dollars per share) | $ 34.91 |
Stock-Based Compensation - Addi
Stock-Based Compensation - Additional Information Concerning Restricted Stock Activity (Details) - Restricted Stock - USD ($) $ / shares in Units, $ in Thousands | 6 Months Ended | |
Jun. 30, 2024 | Jun. 30, 2023 | |
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Additional Disclosures [Abstract] | ||
Weighted-average grant date fair value (in dollars per share) | $ 32.43 | $ 45 |
Total fair value of restricted shares that vested | $ 6,180 | $ 9,622 |
Financing - Financing Activitie
Financing - Financing Activities (Details) | 1 Months Ended | 3 Months Ended | 6 Months Ended | ||||||||||||||||
Jun. 21, 2024 USD ($) | Jun. 10, 2024 USD ($) d deferralPayment $ / shares | Jun. 04, 2024 | May 06, 2024 USD ($) | May 15, 2023 USD ($) | Nov. 10, 2022 USD ($) | Jul. 31, 2024 USD ($) | Jun. 30, 2024 USD ($) $ / shares shares | Jun. 30, 2024 USD ($) $ / shares | Jun. 30, 2023 USD ($) | Jul. 01, 2024 USD ($) | Jun. 03, 2024 USD ($) | May 10, 2024 USD ($) | Mar. 28, 2024 USD ($) debtInstrument | Dec. 31, 2023 USD ($) | Jun. 01, 2023 USD ($) | May 16, 2023 USD ($) | Apr. 28, 2023 USD ($) bond debtInstrument | Dec. 31, 2022 USD ($) | |
Debt Instrument [Line Items] | |||||||||||||||||||
Repayments of long-term debt | $ 737,000,000 | $ 685,000,000 | |||||||||||||||||
At-The-Market | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Distribution agreement | $ 100,000,000 | $ 200,000,000 | |||||||||||||||||
2024 Forward Sale Agreements | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Number of shares issued in transaction (in shares) | shares | 262,025 | ||||||||||||||||||
Sale of stock, price per share (in dollars per share) | $ / shares | $ 37.77 | $ 37.77 | |||||||||||||||||
PNM | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Maturity term over which financings require regulator approval (more than) | 18 months | ||||||||||||||||||
Repayments of long-term debt | $ 198,000,000 | 185,000,000 | |||||||||||||||||
Texas-New Mexico Power Company | FMB Notes Due July 2024 | Subsequent Event | Senior Unsecured Noted, Pollution Control Revenue Bonds | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Stated interest rate | 4.03% | ||||||||||||||||||
Repayments of unsecured debt | $ 80,000,000 | ||||||||||||||||||
Line of credit | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Ratio of debt to capital (less than or equal to) | 70% | ||||||||||||||||||
Line of credit | PNMR 2021 Delayed-Draw Term Loan | Revolving credit facility | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Repayments of debt | $ 449,000,000 | ||||||||||||||||||
Line of credit | PNM 2023 Term Loan | Revolving credit facility | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Repayments of debt | 90,000,000 | ||||||||||||||||||
Line of credit | PNM and TNMP | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Ratio of debt to capital (less than or equal to) | 65% | ||||||||||||||||||
Line of credit | PNM | PNM 2024 Term Loan, Due November 2025 | Secured Debt | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Aggregate principal amount | $ 200,000,000 | ||||||||||||||||||
Variable interest rate | 6.33% | 6.33% | |||||||||||||||||
Unsecured Debt | PNM, Due May 2026 | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Aggregate principal amount | $ 650,000,000 | ||||||||||||||||||
Unsecured Debt | PNM 3.15% Senior Unsecured Notes, Due May 2023 | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Stated interest rate | 3.15% | ||||||||||||||||||
Repayments of long-term debt | $ 55,000,000 | ||||||||||||||||||
Unsecured Debt | PNM | PNM 3.15% Senior Unsecured Notes, Due May 2023 | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Aggregate principal amount | $ 55,000,000 | ||||||||||||||||||
Unsecured Debt | PNM | PNM 2023 Note Purchase Agreement | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Aggregate principal amount | $ 200,000,000 | ||||||||||||||||||
Number of debt issuances | debtInstrument | 2 | ||||||||||||||||||
Unsecured Debt | PNM | PNM 2023 SUNs At 5.1%, Due April 28, 2035 | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Aggregate principal amount | $ 150,000,000 | ||||||||||||||||||
Stated interest rate | 5.51% | ||||||||||||||||||
Unsecured Debt | PNM | PNM 2023 SUNs At 5.92%, Due April 28, 2053 | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Aggregate principal amount | $ 50,000,000 | ||||||||||||||||||
Stated interest rate | 5.92% | ||||||||||||||||||
Unsecured Debt | Texas-New Mexico Power Company | TNMP 2024 Bond Purchase Agreement | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Aggregate principal amount | $ 285,000,000 | ||||||||||||||||||
Number of debt issuances | debtInstrument | 4 | ||||||||||||||||||
Unsecured Debt | Texas-New Mexico Power Company | TNMP 2024 Bond, 5.26%, Due March 28, 2029 | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Aggregate principal amount | $ 32,000,000 | ||||||||||||||||||
Stated interest rate | 5.26% | ||||||||||||||||||
Unsecured Debt | Texas-New Mexico Power Company | TNMP 2024 Bond, 5.55%, Due March 28, 2036 | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Aggregate principal amount | $ 85,000,000 | ||||||||||||||||||
Stated interest rate | 5.55% | ||||||||||||||||||
Unsecured Debt | Texas-New Mexico Power Company | TNMP 2024 Bond, 5.65% | Subsequent Event | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Aggregate principal amount | $ 40,000,000 | ||||||||||||||||||
Stated interest rate | 5.65% | ||||||||||||||||||
Unsecured Debt | Texas-New Mexico Power Company | TNMP 2024 Bond, 5.79% | Subsequent Event | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Aggregate principal amount | $ 128,000,000 | ||||||||||||||||||
Stated interest rate | 5.79% | ||||||||||||||||||
Convertible Debt | Convertible Notes | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Aggregate principal amount | $ 500,000,000 | ||||||||||||||||||
Stated interest rate | 5.75% | ||||||||||||||||||
Conversion ratio | 0.0224911 | ||||||||||||||||||
Debt instrument, convertible, conversion price (in dollars per share) | $ / shares | $ 44.46 | ||||||||||||||||||
Conversion premium percent | 17.50% | ||||||||||||||||||
Number of deferral payments allowed | deferralPayment | 20 | ||||||||||||||||||
Convertible Debt | Convertible Notes | Debt Conversion Terms One | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Debt instrument, redemption price, percentage | 100% | ||||||||||||||||||
Convertible Debt | Convertible Notes | Debt Conversion Terms Two | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Debt instrument, redemption price, percentage | 100% | ||||||||||||||||||
Threshold percentage of stock price trigger | 130% | ||||||||||||||||||
Threshold trading days | d | 20 | ||||||||||||||||||
Threshold consecutive trading days | d | 30 | ||||||||||||||||||
Convertible Debt | Convertible Notes - Option | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Aggregate principal amount | $ 50,000,000 | ||||||||||||||||||
Bonds | PNM 2024 Term Loan, Due November 2025 | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Variable interest rate | 6.33% | 6.33% | |||||||||||||||||
Bonds | PNMR 2021 Delayed-Draw Term Loan | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Long-term debt | $ 51,000,000 | $ 51,000,000 | |||||||||||||||||
Variable interest rate | 6.39% | 6.39% | |||||||||||||||||
Bonds | PCRB 1.10%, Due June 2040 | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Aggregate principal amount | $ 130,000,000 | ||||||||||||||||||
Stated interest rate | 1.10% | ||||||||||||||||||
Bonds | PCRB 3.90%, Due June 2028 | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Aggregate principal amount | $ 130,000,000 | ||||||||||||||||||
Stated interest rate | 3.90% | ||||||||||||||||||
Bonds | PNMR 2023 Delayed-Draw Term Loan | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Variable interest rate | 6.79% | 6.79% | |||||||||||||||||
Bonds | PNM | 3.00% Pollution Control Revenue Bonds Due June 2038 | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Aggregate principal amount | $ 37,000,000 | ||||||||||||||||||
Stated interest rate | 3% | ||||||||||||||||||
Bonds | PNM | 1.15% Pollution Control Revenue Bonds Due June 2038 | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Aggregate principal amount | $ 125,000,000 | ||||||||||||||||||
Stated interest rate | 1.15% | ||||||||||||||||||
Bonds | PNM | Pollution Control Revenue Bonds Due June 2024 | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Aggregate principal amount | $ 36,000,000 | ||||||||||||||||||
Stated interest rate | 3% | ||||||||||||||||||
Bonds | PNM | Pollution Control Revenue Bonds Due June 2029 | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Aggregate principal amount | $ 198,000,000 | ||||||||||||||||||
Stated interest rate | 3.875% | ||||||||||||||||||
Secured Debt | PNM 2023 Term Loan | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Aggregate principal amount | $ 500,000,000 | ||||||||||||||||||
Long-term debt | $ 410,000,000 | $ 410,000,000 | |||||||||||||||||
Variable rate | 6.79% | ||||||||||||||||||
Secured Debt | PNM | TNMP 2023 Bond Purchase Agreement | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Debt instrument, series of bond issuance | bond | 2 | ||||||||||||||||||
Secured Debt | Texas-New Mexico Power Company | TNMP 2023 Bond Purchase Agreement | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Aggregate principal amount | $ 185,000,000 | ||||||||||||||||||
Secured Debt | Texas-New Mexico Power Company | TNMP 2023 Bond Purchase Agreement At 5.01%, Due April 28, 2033 | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Aggregate principal amount | $ 130,000,000 | ||||||||||||||||||
Stated interest rate | 5.01% | ||||||||||||||||||
Secured Debt | Texas-New Mexico Power Company | TNMP 2023 Bond Purchase Agreement At 5.47%, Due July 28, 2053 | |||||||||||||||||||
Debt Instrument [Line Items] | |||||||||||||||||||
Aggregate principal amount | $ 55,000,000 | ||||||||||||||||||
Stated interest rate | 5.47% |
Financing - Schedule of Forward
Financing - Schedule of Forward Contracts (Details) - USD ($) $ / shares in Units, $ in Thousands | 6 Months Ended | 12 Months Ended | |||||
Sep. 26, 2023 | Jun. 30, 2023 | May 30, 2023 | Mar. 20, 2023 | Mar. 15, 2023 | Jun. 30, 2024 | Dec. 31, 2023 | |
Forward Contract Indexed to Issuer's Equity [Line Items] | |||||||
Forward contracts, issuance costs | $ 1,000 | ||||||
Forward contracts, net cash proceeds | $ 198,200 | ||||||
Initial forward price (in shares) | 4,365,510 | ||||||
Settlement amount | $ 199,210 | ||||||
Bank Of America, N.A. | |||||||
Forward Contract Indexed to Issuer's Equity [Line Items] | |||||||
Initial forward price (in dollars per share) | $ 48.49 | ||||||
Initial forward price (in shares) | 504,452 | ||||||
Settlement price (in dollars per share) | $ 49 | ||||||
Settlement amount | $ 24,720 | ||||||
Wells Fargo Bank, N.A. | |||||||
Forward Contract Indexed to Issuer's Equity [Line Items] | |||||||
Initial forward price (in dollars per share) | $ 44.03 | $ 48.30 | |||||
Initial forward price (in shares) | 2,283,860 | 528,082 | |||||
Settlement price (in dollars per share) | $ 44.11 | $ 48.78 | |||||
Settlement amount | $ 100,734 | $ 25,758 | |||||
MUFG Securities EMEA plc | |||||||
Forward Contract Indexed to Issuer's Equity [Line Items] | |||||||
Initial forward price (in dollars per share) | $ 44.87 | $ 47.56 | |||||
Initial forward price (in shares) | 804,477 | 244,639 | |||||
Settlement price (in dollars per share) | $ 45.07 | $ 47.99 | |||||
Settlement amount | $ 36,257 | $ 11,741 |
Financing - Schedule of Hedging
Financing - Schedule of Hedging Arrangements (Details) - Designated as Hedging Instrument - Interest rate contract $ in Millions | Jun. 30, 2024 USD ($) |
Variable Rate Debt, 3.32%, Due December 2024 (1) | |
Derivative Instruments and Hedging Activities Disclosures [Line Items] | |
Derivative asset, notional amount | $ 100 |
Fixed interest rate | 3.32% |
Variable Rate Debt, 3.32%, Due December 2024 (2) | |
Derivative Instruments and Hedging Activities Disclosures [Line Items] | |
Derivative asset, notional amount | $ 100 |
Fixed interest rate | 3.32% |
Variable Rate Debt, 3.38%, Due December 2024 | |
Derivative Instruments and Hedging Activities Disclosures [Line Items] | |
Derivative asset, notional amount | $ 100 |
Fixed interest rate | 3.38% |
Variable Rate Debt, 3.62%, Due December 2024 | |
Derivative Instruments and Hedging Activities Disclosures [Line Items] | |
Derivative asset, notional amount | $ 150 |
Fixed interest rate | 3.62% |
Variable Rate Debt, 3.57%, Due December 2024 | |
Derivative Instruments and Hedging Activities Disclosures [Line Items] | |
Derivative asset, notional amount | $ 150 |
Fixed interest rate | 3.57% |
Variable Rate Debt, 4.18% Due December 2025 | |
Derivative Instruments and Hedging Activities Disclosures [Line Items] | |
Derivative asset, notional amount | $ 100 |
Fixed interest rate | 4.18% |
Variable Rate Debt, 4.18% Due December 2025 (2) | |
Derivative Instruments and Hedging Activities Disclosures [Line Items] | |
Derivative asset, notional amount | $ 100 |
Fixed interest rate | 4.18% |
Variable Rate Debt, 3.99% Due December 2025 | |
Derivative Instruments and Hedging Activities Disclosures [Line Items] | |
Derivative asset, notional amount | $ 100 |
Fixed interest rate | 3.99% |
Financing - Hedging Arrangement
Financing - Hedging Arrangement (Details) $ in Millions | Jun. 30, 2024 USD ($) |
Derivative Instruments and Hedging Activities Disclosures [Line Items] | |
Fair value of hedge agreements, assets | $ 6.2 |
Other Current Assets | |
Derivative Instruments and Hedging Activities Disclosures [Line Items] | |
Fair value of hedge agreements, assets | 5.3 |
Other Deferred Charges | |
Derivative Instruments and Hedging Activities Disclosures [Line Items] | |
Fair value of hedge agreements, assets | $ 0.9 |
Financing - Short-term Debt and
Financing - Short-term Debt and Liquidity (Details) | 1 Months Ended | 6 Months Ended | ||||||
Apr. 01, 2024 USD ($) extension_option | May 31, 2025 USD ($) | Feb. 28, 2025 USD ($) | Aug. 31, 2024 USD ($) | Jun. 30, 2024 USD ($) extension_option | Dec. 31, 2023 USD ($) | May 20, 2022 USD ($) | Mar. 11, 2022 USD ($) | |
Short-term Debt [Line Items] | ||||||||
Letters of credit outstanding | $ 3,100,000 | |||||||
Short-term debt | 326,400,000 | $ 261,900,000 | ||||||
PNMR Development | ||||||||
Short-term Debt [Line Items] | ||||||||
Notes payable | 0 | |||||||
WEB LOC Facility | PNMR Revolving Credit Facility | ||||||||
Short-term Debt [Line Items] | ||||||||
Letters of credit outstanding | 30,300,000 | |||||||
ETBC 1 | Forecast | ||||||||
Short-term Debt [Line Items] | ||||||||
Scheduled payments | $ 3,400,000 | $ 2,500,000 | ||||||
PNM 2023 Note Purchase Agreement | Forecast | ||||||||
Short-term Debt [Line Items] | ||||||||
Scheduled payments | $ 104,000,000 | |||||||
PNMR 2021 Delayed-Draw Term Loan | Bonds | ||||||||
Short-term Debt [Line Items] | ||||||||
Long-term debt | 51,000,000 | |||||||
PNM | ||||||||
Short-term Debt [Line Items] | ||||||||
Letters of credit outstanding | 0 | |||||||
Short-term debt | 70,600,000 | 137,500,000 | ||||||
PNM | Lines of credit | ||||||||
Short-term Debt [Line Items] | ||||||||
NMPRC approved credit facility | $ 40,000,000 | |||||||
TNMP | ||||||||
Short-term Debt [Line Items] | ||||||||
Letters of credit outstanding | 0 | |||||||
Short-term debt | 100,600,000 | 55,100,000 | ||||||
PNMR Development | PNMR | ||||||||
Short-term Debt [Line Items] | ||||||||
Short-term debt | 0 | 2,300,000 | ||||||
PNMR Development | PNMR Revolving Credit Facility | ||||||||
Short-term Debt [Line Items] | ||||||||
Short-term debt | 155,200,000 | $ 69,300,000 | ||||||
Revolving credit facility | ||||||||
Short-term Debt [Line Items] | ||||||||
Financing capacity | 300,000,000 | |||||||
Revolving credit facility | PNM | ||||||||
Short-term Debt [Line Items] | ||||||||
Financing capacity | 400,000,000 | |||||||
Revolving credit facility | PNMR and PNM | ||||||||
Short-term Debt [Line Items] | ||||||||
Number of extensions | extension_option | 2 | |||||||
Extension period | 1 year | |||||||
Revolving credit facility | TNMP | ||||||||
Short-term Debt [Line Items] | ||||||||
Financing capacity | $ 200,000,000 | $ 200,000,000 | $ 100,000,000 | |||||
Number of extensions | extension_option | 2 | |||||||
Extension period | 1 year | |||||||
Revolving credit facility | TNMP | First Mortgage Bonds Due 2029 | ||||||||
Short-term Debt [Line Items] | ||||||||
Collateral amount | $ 200,000,000 | |||||||
Senior Unsecured Noted, Pollution Control Revenue Bonds | TNMP | FMB Notes Due July 2024 | ||||||||
Short-term Debt [Line Items] | ||||||||
Financing capacity | $ 80,000,000 |
Financing - Schedule of Short-T
Financing - Schedule of Short-Term Debt (Details) - USD ($) $ in Thousands | Jun. 30, 2024 | Dec. 31, 2023 |
Short-term Debt [Line Items] | ||
Balance Outstanding | $ 326,400 | $ 261,900 |
PNM | ||
Short-term Debt [Line Items] | ||
Balance Outstanding | 70,600 | 137,500 |
Texas-New Mexico Power Company | ||
Short-term Debt [Line Items] | ||
Balance Outstanding | 100,600 | 55,100 |
PNM Revolving Credit Facility | PNM | ||
Short-term Debt [Line Items] | ||
Balance Outstanding | $ 30,600 | $ 107,500 |
Weighted Average Interest Rate | 6.67% | 6.69% |
PNM New Mexico Credit Facility | PNM | ||
Short-term Debt [Line Items] | ||
Balance Outstanding | $ 40,000 | $ 30,000 |
Weighted Average Interest Rate | 6.69% | 6.71% |
TNMP Revolving Credit Facility | Texas-New Mexico Power Company | ||
Short-term Debt [Line Items] | ||
Balance Outstanding | $ 100,600 | $ 55,100 |
Weighted Average Interest Rate | 6.31% | 6.32% |
PNMR Revolving Credit Facility | PNMR Development | ||
Short-term Debt [Line Items] | ||
Balance Outstanding | $ 155,200 | $ 69,300 |
Weighted Average Interest Rate | 6.93% | 6.96% |
Pension and Other Postretirem_3
Pension and Other Postretirement Benefit Plans - Schedule of Net Periodic Benefit Costs (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
PNM | Pension Plan | ||||
Components of Net Periodic Benefit Cost | ||||
Service cost | $ 0 | $ 0 | $ 0 | $ 0 |
Interest cost | 5,428 | 5,914 | 10,855 | 11,827 |
Expected return on plan assets | (7,757) | (7,299) | (15,514) | (14,598) |
Amortization of net (gain) loss | 2,662 | 2,645 | 5,323 | 5,291 |
Amortization of prior service cost | 0 | 0 | 0 | 0 |
Net Periodic Benefit Cost (Income) | 333 | 1,260 | 664 | 2,520 |
PNM | OPEB Plan | ||||
Components of Net Periodic Benefit Cost | ||||
Service cost | 0 | 0 | 0 | 0 |
Interest cost | 597 | 676 | 1,194 | 1,352 |
Expected return on plan assets | (1,391) | (1,243) | (2,782) | (2,485) |
Amortization of net (gain) loss | 0 | 0 | 0 | 0 |
Amortization of prior service cost | 0 | 0 | 0 | 0 |
Net Periodic Benefit Cost (Income) | (794) | (567) | (1,588) | (1,133) |
PNM | Executive Retirement Program | ||||
Components of Net Periodic Benefit Cost | ||||
Service cost | 0 | 0 | 0 | 0 |
Interest cost | 124 | 135 | 248 | 270 |
Expected return on plan assets | 0 | 0 | 0 | 0 |
Amortization of net (gain) loss | 50 | 38 | 100 | 76 |
Amortization of prior service cost | 0 | 0 | 0 | 0 |
Net Periodic Benefit Cost (Income) | 174 | 173 | 348 | 346 |
Texas-New Mexico Power Company | Pension Plan | ||||
Components of Net Periodic Benefit Cost | ||||
Service cost | 0 | 0 | 0 | 0 |
Interest cost | 554 | 600 | 1,107 | 1,201 |
Expected return on plan assets | (687) | (675) | (1,374) | (1,349) |
Amortization of net (gain) loss | 139 | 109 | 278 | 219 |
Amortization of prior service cost | 0 | 0 | 0 | 0 |
Net Periodic Benefit Cost (Income) | 6 | 34 | 11 | 71 |
Texas-New Mexico Power Company | OPEB Plan | ||||
Components of Net Periodic Benefit Cost | ||||
Service cost | 6 | 6 | 11 | 11 |
Interest cost | 97 | 107 | 193 | 213 |
Expected return on plan assets | (128) | (121) | (257) | (241) |
Amortization of net (gain) loss | (160) | (190) | (321) | (380) |
Amortization of prior service cost | 0 | 0 | 0 | 0 |
Net Periodic Benefit Cost (Income) | (185) | (198) | (374) | (397) |
Texas-New Mexico Power Company | Executive Retirement Program | ||||
Components of Net Periodic Benefit Cost | ||||
Service cost | 0 | 0 | 0 | 0 |
Interest cost | 4 | 3 | 8 | 6 |
Expected return on plan assets | 0 | 0 | 0 | 0 |
Amortization of net (gain) loss | 0 | 0 | 0 | 0 |
Amortization of prior service cost | 0 | 0 | 0 | 0 |
Net Periodic Benefit Cost (Income) | $ 4 | $ 3 | $ 8 | $ 6 |
Pension and Other Postretirem_4
Pension and Other Postretirement Benefit Plans - Narrative (Details) - USD ($) | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Pension Plan | PNM | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Contributions by employer | $ 0 | $ 0 | $ 0 | $ 0 |
Estimated employer contributions for remainder of fiscal year through year four | 0 | $ 0 | ||
Pension Plan | PNM | Maximum | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Assumptions used calculating net periodic benefit cost, discount rate | 5.50% | |||
Pension Plan | Texas-New Mexico Power Company | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Contributions by employer | 0 | 0 | $ 0 | 0 |
Estimated employer contributions for remainder of fiscal year through year four | 0 | 0 | ||
Estimated future contributions, year five | 200,000 | $ 200,000 | ||
Pension Plan | Texas-New Mexico Power Company | Maximum | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Assumptions used calculating net periodic benefit cost, discount rate | 5.50% | |||
OPEB Plan | PNM | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Contributions by employer | 0 | 0 | $ 0 | 0 |
Disbursements by employer | 100,000 | 100,000 | 100,000 | 100,000 |
Estimated disbursement by employer, current year | 200,000 | |||
Disbursements by employer, year one through four | 10,100,000 | |||
OPEB Plan | Texas-New Mexico Power Company | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Contributions by employer | 0 | 0 | 0 | 0 |
Disbursements by employer, year one through four | 0 | |||
Executive Retirement Program | PNM | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Contributions by employer | 300,000 | 200,000 | 600,000 | 600,000 |
Estimated disbursement by employer, current year | 1,200,000 | |||
Disbursements by employer, year one through four | 4,400,000 | |||
Executive Retirement Program | Texas-New Mexico Power Company | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Estimated disbursement by employer, current year | 100,000 | |||
Disbursements by employer, year one through four | 200,000 | |||
Executive Retirement Program | Texas-New Mexico Power Company | Maximum | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Contributions by employer | $ 0 | $ 0 | $ 100,000 | $ 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 | Jun. 30, 2024 | Dec. 31, 2023 |
Public Utilities, Commitments And Contingencies [Line Items] | ||
Estimate of possible loss | $ 55.6 | |
Other deferred credits | ||
Public Utilities, Commitments And Contingencies [Line Items] | ||
Loss contingency accrual | $ 12.2 | $ 11 |
Commitments and Contingencies_2
Commitments and Contingencies - Santa Fe Generating Station (Details) | 1 Months Ended | 24 Months Ended | |
Jan. 01, 2020 fieldReport | Jul. 31, 2020 fieldReport | Dec. 31, 2014 monitoringWell | |
Commitments and Contingencies Disclosure [Abstract] | |||
Number of monitoring wells containing free-phase hydrocarbon products | monitoringWell | 1 | ||
Number of field work reports | fieldReport | 2 | 2 |
Commitments and Contingencies_3
Commitments and Contingencies - Coal Supply (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | 12 Months Ended | |
Jun. 30, 2024 | Jun. 30, 2024 | Dec. 31, 2023 | Jan. 31, 2016 | |
PNM | Four Corners CSA | ||||
Public Utilities, Commitments And Contingencies [Line Items] | ||||
Funds contributed, mine reclamation trust | $ 3.2 | $ 0.2 | ||
Reclamation trust funding, 2025 | 1.9 | |||
Reclamation trust funding, year 2026 | 2.8 | |||
Coal supply | San Juan Generating Station | ||||
Public Utilities, Commitments And Contingencies [Line Items] | ||||
Cash used to support bank letter or credit arrangement | $ 30.3 | |||
Coal supply | NM Capital | San Juan Generating Station | ||||
Public Utilities, Commitments And Contingencies [Line Items] | ||||
Requirement to post reclamation bonds | $ 118.7 | 118.7 | ||
Cash used to support bank letter or credit arrangement | 30.3 | 30.3 | ||
Underground | PNM | Loss on long-term purchase commitment | ||||
Public Utilities, Commitments And Contingencies [Line Items] | ||||
Loss contingency accrual | 48.6 | 48.6 | 26.2 | |
Underground | PNM | San Juan Generating Station | Loss on long-term purchase commitment | ||||
Public Utilities, Commitments And Contingencies [Line Items] | ||||
Estimate of possible loss | 59.7 | 59.7 | ||
Surface | PNM | Loss on long-term purchase commitment | ||||
Public Utilities, Commitments And Contingencies [Line Items] | ||||
Loss contingency accrual | 39.9 | 39.9 | 50 | |
Surface | PNM | San Juan Generating Station | Loss on long-term purchase commitment | ||||
Public Utilities, Commitments And Contingencies [Line Items] | ||||
Estimate of possible loss | 46.5 | 46.5 | ||
San Juan Generating Station | ||||
Public Utilities, Commitments And Contingencies [Line Items] | ||||
Reclamation costs | 20.9 | |||
Regulatory disallowance | 4.5 | |||
San Juan Generating Station | PNM | Loss on long-term purchase commitment | ||||
Public Utilities, Commitments And Contingencies [Line Items] | ||||
Annual funding post-term reclamation trust | $ 2.7 | |||
Annual funding post-term reclamation trust, remainder of year | 21.5 | |||
Annual funding post-term reclamation trust, year one | 3.6 | |||
Annual funding post-term reclamation trust, year two | 3.7 | |||
San Juan Generating Station | Underground | ||||
Public Utilities, Commitments And Contingencies [Line Items] | ||||
Increase in regulatory liabilities | 17 | |||
San Juan Generating Station | Surface | ||||
Public Utilities, Commitments And Contingencies [Line Items] | ||||
Increase in regulatory liabilities | 4 | |||
Decrease in deferred regulatory assets | $ 0.5 | |||
Reclamation, maximum collection from customers | 100 | |||
San Juan Generating Station and Four Corners | PNM | Mine Reclamation Trust | ||||
Public Utilities, Commitments And Contingencies [Line Items] | ||||
Customer reclamation funding cost | $ 100 |
Commitments and Contingencies_4
Commitments and Contingencies - San Juan County Decommissioning Ordinance (Details) - San Juan Generating Station - Coal-Fired Electricity Generating Facility Demolition And Remediation Ordinance - Public Service Company of New Mexico - USD ($) $ in Millions | 1 Months Ended | ||
Dec. 31, 2022 | Sep. 30, 2022 | Nov. 09, 2021 | |
Public Utilities, Commitments And Contingencies [Line Items] | |||
Initial funding requirement | $ 14.7 | ||
Surety bond | $ 46 | ||
Decrease in decommissioning obligation | $ 21.1 |
Commitments and Contingencies_5
Commitments and Contingencies - PVNGS Liability and Insurance Matters (Details) - PNM - Palo Verde Nuclear Generating Station - Nuclear plant $ in Millions | Jun. 30, 2024 USD ($) |
Public Utilities, Commitments And Contingencies [Line Items] | |
Maximum retrospective premium per reactor | $ 165.9 |
Maximum annual premium per incident | 24.7 |
Maximum potential assessment per incident | 36.3 |
Annual payment limitation related to incident | 5.4 |
Aggregate amount of all risk insurance | 2,800 |
Maximum amount under nuclear electric insurance limited | 5.1 |
Commercial providers | |
Public Utilities, Commitments And Contingencies [Line Items] | |
Liability insurance coverage | 500 |
Industry Wide Retrospective Assessment Program | |
Public Utilities, Commitments And Contingencies [Line Items] | |
Liability insurance coverage | 15,800 |
Maximum | |
Public Utilities, Commitments And Contingencies [Line Items] | |
Liability insurance coverage | 16,300 |
Liability insurance coverage sublimit | $ 2,250 |
Commitments and Contingencies_6
Commitments and Contingencies - General Liability Insurance Matters (Details) $ in Millions | Jun. 30, 2024 USD ($) |
Text Block [Abstract] | |
General liability receivable, current | $ 42 |
General liability insurance accrual, current | $ 42 |
Regulatory and Rate Matters - P
Regulatory and Rate Matters - PNM (Details) $ in Thousands | 3 Months Ended | 6 Months Ended | 12 Months Ended | ||||||||
Jun. 14, 2024 USD ($) | Jun. 03, 2024 USD ($) | Jan. 03, 2024 USD ($) | Jan. 01, 2024 USD ($) | Apr. 17, 2023 USD ($) program | Dec. 05, 2022 USD ($) lease MW | Jun. 30, 2024 USD ($) MW | Jun. 30, 2023 USD ($) | Jun. 30, 2024 USD ($) MW | Jun. 30, 2023 USD ($) | Dec. 31, 2023 USD ($) | |
Public Utilities, Commitments And Contingencies [Line Items] | |||||||||||
Increase in non-fuel based rate | $ 15,300 | ||||||||||
Regulatory liabilities return period | 2 years | 2 years | |||||||||
Operating revenues | $ (488,102) | $ (477,156) | $ (924,979) | $ (1,021,233) | |||||||
Excess return on jurisdictional equity that would require refund | 0.50% | 0.50% | |||||||||
PVNGS Leased Interest | |||||||||||
Public Utilities, Commitments And Contingencies [Line Items] | |||||||||||
Regulatory liability | $ 38,400 | ||||||||||
Four Corners | |||||||||||
Public Utilities, Commitments And Contingencies [Line Items] | |||||||||||
Regulatory disallowances | $ 81,000 | ||||||||||
NMPRC | |||||||||||
Public Utilities, Commitments And Contingencies [Line Items] | |||||||||||
Requested return on equity | 10.25% | ||||||||||
Action plan, covered period | 3 years | ||||||||||
NM 2022 Rate Case | |||||||||||
Public Utilities, Commitments And Contingencies [Line Items] | |||||||||||
Requested return on equity | 9.26% | ||||||||||
Requested equity capital structure | 49.61% | ||||||||||
Requested debt capital structure | 50.10% | ||||||||||
Requested equity capital structure, percentage | 0.29% | ||||||||||
NM 2022 Rate Case | Palo Verde Nuclear Generating Station | |||||||||||
Public Utilities, Commitments And Contingencies [Line Items] | |||||||||||
Approved regulatory asset | $ 51,300 | ||||||||||
Request regulatory asset | 96,300 | ||||||||||
Disallowance of return | $ 45,000 | ||||||||||
2024 Rate Change | |||||||||||
Public Utilities, Commitments And Contingencies [Line Items] | |||||||||||
Requested return on equity | 10.45% | ||||||||||
Requested equity capital structure | 52.50% | ||||||||||
Regulatory liability | $ 19,200 | ||||||||||
Deferred regulatory liability | 19,200 | ||||||||||
2024 Rate Change | PVNGS Leased Interest | |||||||||||
Public Utilities, Commitments And Contingencies [Line Items] | |||||||||||
Operating revenues | 38,400 | ||||||||||
2024 Rate Change | Four Corners | |||||||||||
Public Utilities, Commitments And Contingencies [Line Items] | |||||||||||
Regulatory disallowances | 55,500 | ||||||||||
2024 Rate Change | Palo Verde Nuclear Generating Station | |||||||||||
Public Utilities, Commitments And Contingencies [Line Items] | |||||||||||
Regulatory disallowances | $ 8,200 | ||||||||||
PNM | |||||||||||
Public Utilities, Commitments And Contingencies [Line Items] | |||||||||||
Number of leases renewed | lease | 5 | ||||||||||
Number of megawatts purchased (in megawatts) | MW | 64.1 | ||||||||||
Operating revenues | $ (333,671) | (338,242) | $ (641,786) | (768,407) | |||||||
PNM | NMPRC | |||||||||||
Public Utilities, Commitments And Contingencies [Line Items] | |||||||||||
Proposed revision to rider that will allow for recovery | $ 58,700 | $ 59,000 | |||||||||
PNM | NM 2022 Rate Case | |||||||||||
Public Utilities, Commitments And Contingencies [Line Items] | |||||||||||
Recovery of base rate | $ 2,700,000 | ||||||||||
PNM | NM 2022 Rate Case | Non-Fuel Energy | |||||||||||
Public Utilities, Commitments And Contingencies [Line Items] | |||||||||||
Requested rate increase (decrease) | $ 63,800 | ||||||||||
PNM | 2024 Rate Change | |||||||||||
Public Utilities, Commitments And Contingencies [Line Items] | |||||||||||
Recovery of base rate | $ 3,000,000 | ||||||||||
Requested rate increase (decrease) | 174,300 | ||||||||||
Increase in base rate | 92,200 | ||||||||||
Increase in revenues from FPPAC | $ 82,100 | ||||||||||
PNM | Renewable Portfolio Standard | |||||||||||
Public Utilities, Commitments And Contingencies [Line Items] | |||||||||||
Number of megawatts of Solar PV facilities | MW | 158 | 158 | |||||||||
Current output in the geothermal facility (in megawatts) | MW | 11 | 11 | |||||||||
Solar generation capacity (in megawatts) | MW | 295.7 | 295.7 | |||||||||
PNM | Renewable Portfolio Standard | La Joya Wind | |||||||||||
Public Utilities, Commitments And Contingencies [Line Items] | |||||||||||
Number of megawatts for wind energy | MW | 140 | ||||||||||
PNM | Renewable Portfolio Standard 2014 | New Mexico Wind | |||||||||||
Public Utilities, Commitments And Contingencies [Line Items] | |||||||||||
Number of megawatts for wind energy | MW | 200 | ||||||||||
PNM | Renewable Portfolio Standard 2014 | Red Mesa Wind | |||||||||||
Public Utilities, Commitments And Contingencies [Line Items] | |||||||||||
Number of megawatts for wind energy | MW | 102 | ||||||||||
PNM | Renewable Energy Rider | NMPRC | |||||||||||
Public Utilities, Commitments And Contingencies [Line Items] | |||||||||||
Recorded revenues from renewable rider | $ 15,300 | $ 15,400 | $ 30,600 | $ 34,000 | |||||||
PNM | 2024 Plan | |||||||||||
Public Utilities, Commitments And Contingencies [Line Items] | |||||||||||
Program costs related to energy efficiency, number of programs | program | 10 | ||||||||||
Program costs related to energy efficiency, in year one | $ 34,500 | ||||||||||
Program costs related to energy efficiency, in year two | 35,400 | ||||||||||
Program costs related to energy efficiency, in year three | $ 36,500 | ||||||||||
PNM | Energy Efficiency and Load Management Program | Minimum | |||||||||||
Public Utilities, Commitments And Contingencies [Line Items] | |||||||||||
Profit incentive sliding scale multiplier | 0.071 | ||||||||||
PNM | Energy Efficiency and Load Management Program | Maximum | |||||||||||
Public Utilities, Commitments And Contingencies [Line Items] | |||||||||||
Profit incentive sliding scale multiplier | 0.0882 | ||||||||||
PNM | Integrated Resource Plan, 2011 | |||||||||||
Public Utilities, Commitments And Contingencies [Line Items] | |||||||||||
Frequency of IRP filings | 3 years | ||||||||||
Planning period covered of IRP | 20 years |
Regulatory and Rate Matters - F
Regulatory and Rate Matters - Fours Corners, Summer Peak Resource Adequacy, 2026 Resource Application, Grid Modernization Application (Details) $ in Millions | 1 Months Ended | 3 Months Ended | 6 Months Ended | 12 Months Ended | |||
Oct. 25, 2023 MW batteryStorageAgreement | Oct. 03, 2022 USD ($) | Jan. 08, 2021 USD ($) | Nov. 30, 2020 USD ($) | Jun. 30, 2023 USD ($) | Jun. 30, 2023 USD ($) | Dec. 31, 2020 USD ($) | |
Public Utilities, General Disclosures [Line Items] | |||||||
Number of battery storage agreements | batteryStorageAgreement | 3 | ||||||
PNM | |||||||
Public Utilities, General Disclosures [Line Items] | |||||||
Grid modernization investment | $ | $ 344 | ||||||
Grid modernization, initial term | 6 years | ||||||
Grid modernization term | 11 years | ||||||
PNM | Solar Agreement One | |||||||
Public Utilities, General Disclosures [Line Items] | |||||||
Number of megawatts available in purchase power agreement (in megawatts) | MW | 100 | ||||||
PNM | Battery Storage Agreement One | |||||||
Public Utilities, General Disclosures [Line Items] | |||||||
Number of megawatts available in purchase power agreement (in megawatts) | MW | 100 | ||||||
PNM | Battery Storage Agreement Two | |||||||
Public Utilities, General Disclosures [Line Items] | |||||||
Number of megawatts available in purchase power agreement (in megawatts) | MW | 100 | ||||||
PNM | Battery Storage Agreement Three | |||||||
Public Utilities, General Disclosures [Line Items] | |||||||
Number of megawatts available in purchase power agreement (in megawatts) | MW | 50 | ||||||
PNM | Solar Agreement Two | |||||||
Public Utilities, General Disclosures [Line Items] | |||||||
Number of megawatts available in purchase power agreement (in megawatts) | MW | 60 | ||||||
PNM | Four Corners | |||||||
Public Utilities, General Disclosures [Line Items] | |||||||
Payments for relief from obligations | $ | $ 15 | $ 75 | |||||
Final payment for relief from obligations | $ | $ 60 | ||||||
Request issuance of energy transition bonds | $ | $ 300 | ||||||
Regulatory disallowance | $ | $ 3.7 | $ 3.7 | |||||
PNM | Four Corners | PNM | |||||||
Public Utilities, General Disclosures [Line Items] | |||||||
Noncontrolling interest, ownership percentage by noncontrolling owners | 13% |
Regulatory and Rate Matters - T
Regulatory and Rate Matters - Transportation and Electrification Program (TEP) (Details) - Public Service Company of New Mexico - USD ($) $ in Millions | Feb. 23, 2024 | Feb. 02, 2024 | Jun. 01, 2023 |
Public Utilities, General Disclosures [Line Items] | |||
Expected budgeted expenditures | $ 37.1 | ||
Budget period | 3 years | ||
Budge dedication to low-income customers | 22% | ||
Budget dedication to low-income customers | $ 8 | ||
Reduction in approved budget | $ 4 | ||
Total budget | $ 32.9 |
Regulatory and Rate Matters - S
Regulatory and Rate Matters - Schedule of Transmission Cost of Service Rates (Details) - PUCT - TNMP - USD ($) $ in Millions | Mar. 15, 2024 | Sep. 06, 2023 | May 12, 2023 |
Public Utilities, General Disclosures [Line Items] | |||
Approved Increase in Rate Base | $ 97.4 | $ 21.4 | $ 150.5 |
Annual Increase in Revenue | $ 13.1 | $ 4.2 | $ 19.4 |
Regulatory and Rate Matters -_2
Regulatory and Rate Matters - Schedule of Interim Distribution Rate Increases (Details) - Texas-New Mexico Power Company - Periodic Distribution Rate Adjustment - USD ($) $ in Millions | Jul. 28, 2024 | Sep. 01, 2023 | Sep. 01, 2022 |
Public Utilities, General Disclosures [Line Items] | |||
Approved Increase in Rate Base | $ 157 | $ 95.7 | |
Annual Increase in Revenue | $ 14.5 | $ 6.8 | |
Subsequent Event | |||
Public Utilities, General Disclosures [Line Items] | |||
Approved Increase in Rate Base | $ 205.9 | ||
Annual Increase in Revenue | $ 15.6 |
Regulatory and Rate Matters -_3
Regulatory and Rate Matters - TNMP Narrative (Details) - TNMP $ in Millions | Jul. 30, 2024 USD ($) | Jul. 25, 2024 USD ($) | Jul. 08, 2024 customer | Sep. 28, 2023 USD ($) | May 31, 2024 USD ($) | Mar. 01, 2022 USD ($) |
Public Utilities, Commitments And Contingencies [Line Items] | ||||||
Energy efficiency cost recovery, requested change amount | $ 7.3 | |||||
Energy efficiency cost recovery, requested bonus | $ 7 | $ 1.9 | ||||
Energy efficiency cost recovery factor, recovery | $ 6.6 | |||||
Energy efficiency cost recovery factor, approved performance bonus | $ 1.2 | $ 1.3 | ||||
Subsequent Event | ||||||
Public Utilities, Commitments And Contingencies [Line Items] | ||||||
Requested increase annual distribution revenue requirement | $ 20.6 | |||||
Incremental distribution investments | $ 3.9 | |||||
Requested rate increase (decrease) | $ 7.8 | |||||
Recovery of base rate | $ 43.7 | |||||
Subsequent Event | Hurricane | ||||||
Public Utilities, Commitments And Contingencies [Line Items] | ||||||
Number of customers without power | customer | 116,000 |
Lease Commitments - Narrative (
Lease Commitments - Narrative (Details) $ in Thousands | 1 Months Ended | 3 Months Ended | 6 Months Ended | |||||||
Apr. 30, 2024 USD ($) | Jan. 31, 2024 USD ($) | Jan. 31, 2023 USD ($) | Jun. 30, 2024 USD ($) | Jun. 30, 2023 USD ($) | Jun. 30, 2024 USD ($) | Jun. 30, 2023 USD ($) | Dec. 31, 2023 USD ($) | Jan. 15, 2016 lease | Jan. 15, 2015 lease | |
Operating Leased Assets [Line Items] | ||||||||||
Proceeds from sale of productive assets | $ 2,840 | $ 28,372 | ||||||||
Reduction to inventories | 17,110 | 14,283 | ||||||||
Unamortized cost, right-of-way lease payments | $ 69,000 | 69,000 | $ 56,200 | |||||||
Operating lease, right-of-use asset, amortization expense | $ 1,000 | $ 900 | $ 2,100 | 1,800 | ||||||
Non-lease component, percent of lease liability | 25.50% | 25.50% | ||||||||
Lessee, operating lease, unguaranteed residual value | $ 22,800 | $ 22,800 | ||||||||
Lease to be executed, fixed consideration | $ 1,100,000 | $ 1,100,000 | ||||||||
Lease to be executed, term of contract | 20 years | 20 years | ||||||||
Materials, Supplies, and Fuel Stock | ||||||||||
Operating Leased Assets [Line Items] | ||||||||||
Reduction to inventories | $ (600) | $ (5,300) | ||||||||
PNM Owned Assets | ||||||||||
Operating Leased Assets [Line Items] | ||||||||||
Proceeds from sale of productive assets | 3,400 | 33,700 | ||||||||
Net Utility Plant | ||||||||||
Operating Leased Assets [Line Items] | ||||||||||
Proceeds from sale of productive assets | $ 2,800 | $ 28,400 | ||||||||
Equipment | ||||||||||
Operating Leased Assets [Line Items] | ||||||||||
Operating lease, residual value of leased asset | $ 1,700 | $ 1,700 | ||||||||
Battery Storage | ||||||||||
Operating Leased Assets [Line Items] | ||||||||||
Operating lease, term of contract | 20 years | 20 years | ||||||||
PNM | ||||||||||
Operating Leased Assets [Line Items] | ||||||||||
Proceeds from sale of productive assets | $ 2,840 | 28,372 | ||||||||
Reduction to inventories | 10,671 | 11,334 | ||||||||
Lessee, operating lease, unguaranteed residual value | $ 11,200 | 11,200 | ||||||||
PNM | Equipment | ||||||||||
Operating Leased Assets [Line Items] | ||||||||||
Operating lease, residual value of leased asset | 800 | 800 | ||||||||
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 | |||||||||
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 | |||||||||
PNM | Navajo Nation | ||||||||||
Operating Leased Assets [Line Items] | ||||||||||
Annual lease payments | 6,000 | |||||||||
Right-of-way lease payments | $ 8,600 | |||||||||
TNMP | ||||||||||
Operating Leased Assets [Line Items] | ||||||||||
Reduction to inventories | 6,439 | $ 2,949 | ||||||||
Lessee, operating lease, unguaranteed residual value | 11,600 | 11,600 | ||||||||
TNMP | Equipment | ||||||||||
Operating Leased Assets [Line Items] | ||||||||||
Operating lease, residual value of leased asset | $ 1,000 | $ 1,000 |
Lease Commitments - Operating L
Lease Commitments - Operating Lease Balance Sheet Information (Details) - USD ($) $ in Thousands | Jun. 30, 2024 | Dec. 31, 2023 |
Operating leases: | ||
Operating lease assets, net of amortization | $ 177,285 | $ 182,201 |
Current portion of operating lease liabilities | 10,834 | 12,267 |
Long-term portion of operating lease liabilities | 159,592 | 167,000 |
PNM | ||
Operating leases: | ||
Operating lease assets, net of amortization | 175,363 | 180,370 |
Current portion of operating lease liabilities | 9,963 | 11,371 |
Long-term portion of operating lease liabilities | 158,609 | 166,191 |
TNMP | ||
Operating leases: | ||
Operating lease assets, net of amortization | 1,362 | 1,814 |
Current portion of operating lease liabilities | 835 | 895 |
Long-term portion of operating lease liabilities | $ 457 | $ 809 |
Lease Commitments - Finance Lea
Lease Commitments - Finance Lease Balance Sheet Information (Details) - USD ($) $ in Thousands | Jun. 30, 2024 | Dec. 31, 2023 |
Financing leases: | ||
Non-utility property | $ 47,023 | $ 49,981 |
Accumulated depreciation | (23,199) | (23,905) |
Non-utility property, net | 23,824 | 26,076 |
Other current liabilities | 8,268 | 8,776 |
Other deferred credits | 15,601 | 17,326 |
PNM | ||
Financing leases: | ||
Non-utility property | 22,594 | 25,425 |
Accumulated depreciation | (10,859) | (11,984) |
Non-utility property, net | 11,735 | 13,441 |
Other current liabilities | 3,710 | 4,146 |
Other deferred credits | 8,045 | 9,300 |
TNMP | ||
Financing leases: | ||
Non-utility property | 24,054 | 24,487 |
Accumulated depreciation | (12,261) | (11,869) |
Non-utility property, net | 11,793 | 12,618 |
Other current liabilities | 4,476 | 4,616 |
Other deferred credits | $ 7,338 | $ 8,023 |
Lease Commitments - Schedule of
Lease Commitments - Schedule of Weighted Average Remaining Lease Terms and Discount Rates (Details) | Jun. 30, 2024 |
Weighted average remaining lease term (years): | |
Operating leases | 16 years 7 months 6 days |
Financing leases | 3 years 3 months |
Weighted average discount rate: | |
Operating leases | 5.64% |
Financing leases | 4.87% |
PNM | |
Weighted average remaining lease term (years): | |
Operating leases | 16 years 8 months 26 days |
Financing leases | 3 years 6 months 14 days |
Weighted average discount rate: | |
Operating leases | 5.65% |
Financing leases | 4.77% |
TNMP | |
Weighted average remaining lease term (years): | |
Operating leases | 1 year 4 months 28 days |
Financing leases | 2 years 11 months 12 days |
Weighted average discount rate: | |
Operating leases | 4.26% |
Financing leases | 4.96% |
Lease Commitments - Components
Lease Commitments - Components of Lease Expense (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Lease, Cost [Line Items] | ||||
Operating lease cost | $ 2,869 | $ 7,206 | ||
Amounts capitalized | $ (237) | (434) | $ (505) | (947) |
Total operating lease expense | 4,867 | 2,435 | 9,874 | 6,259 |
Financing lease cost: | ||||
Amortization of right-of-use assets | 2,463 | 2,235 | 5,005 | 4,329 |
Interest on lease liabilities | 294 | 252 | 591 | 486 |
Amounts capitalized | (1,917) | (1,477) | (3,940) | (3,167) |
Total financing lease expense | 840 | 1,010 | 1,656 | 1,648 |
Variable lease expense | 433 | 360 | 793 | 622 |
Short-term lease expense | 165 | 149 | 381 | 299 |
Total lease expense for the period | 6,305 | 3,954 | 12,704 | 8,828 |
Battery storage leases | ||||
Lease, Cost [Line Items] | ||||
Operating lease cost | 2,947 | 5,893 | ||
Other operating leases | ||||
Lease, Cost [Line Items] | ||||
Operating lease cost | 2,157 | 4,486 | ||
PNM | ||||
Lease, Cost [Line Items] | ||||
Operating lease cost | 2,468 | 6,376 | ||
Amounts capitalized | (28) | (103) | (63) | (263) |
Total operating lease expense | 4,827 | 2,365 | 9,797 | 6,113 |
Financing lease cost: | ||||
Amortization of right-of-use assets | 1,120 | 1,123 | 2,337 | 2,132 |
Interest on lease liabilities | 143 | 140 | 287 | 262 |
Amounts capitalized | (756) | (778) | (1,597) | (1,469) |
Total financing lease expense | 507 | 485 | 1,027 | 925 |
Variable lease expense | 433 | 360 | 793 | 622 |
Short-term lease expense | 148 | 145 | 352 | 292 |
Total lease expense for the period | 5,915 | 3,355 | 11,969 | 7,952 |
PNM | Battery storage leases | ||||
Lease, Cost [Line Items] | ||||
Operating lease cost | 2,947 | 5,893 | ||
PNM | Other operating leases | ||||
Lease, Cost [Line Items] | ||||
Operating lease cost | 1,908 | 3,967 | ||
TNMP | ||||
Lease, Cost [Line Items] | ||||
Operating lease cost | 401 | 830 | ||
Amounts capitalized | (209) | (331) | (442) | (684) |
Total operating lease expense | 28 | 70 | 65 | 146 |
Financing lease cost: | ||||
Amortization of right-of-use assets | 1,315 | 1,098 | 2,631 | 2,162 |
Interest on lease liabilities | 147 | 112 | 299 | 223 |
Amounts capitalized | (1,161) | (699) | (2,343) | (1,699) |
Total financing lease expense | 301 | 511 | 587 | 686 |
Variable lease expense | 0 | 0 | 0 | 0 |
Short-term lease expense | 7 | 1 | 12 | 1 |
Total lease expense for the period | 336 | $ 582 | 664 | $ 833 |
TNMP | Battery storage leases | ||||
Lease, Cost [Line Items] | ||||
Operating lease cost | 0 | 0 | ||
TNMP | Other operating leases | ||||
Lease, Cost [Line Items] | ||||
Operating lease cost | $ 237 | $ 507 |
Lease Commitments - Schedule _2
Lease Commitments - Schedule of Supplemental Cash Flows Related to Leases (Details) - USD ($) $ in Thousands | 6 Months Ended | |
Jun. 30, 2024 | Jun. 30, 2023 | |
Cash paid for amounts included in the measurement of lease liabilities: | ||
Operating cash flows from operating leases | $ 13,737 | $ 16,363 |
Operating cash flows from financing leases | 152 | 127 |
Finance cash flows from financing leases | 1,487 | 1,474 |
Non-cash information related to right-of-use assets obtained in exchange for lease obligations: | ||
Operating leases | 663 | 100 |
Financing leases | 2,885 | 6,576 |
PNM | ||
Cash paid for amounts included in the measurement of lease liabilities: | ||
Operating cash flows from operating leases | 13,701 | 16,208 |
Operating cash flows from financing leases | 94 | 88 |
Finance cash flows from financing leases | 919 | 792 |
Non-cash information related to right-of-use assets obtained in exchange for lease obligations: | ||
Operating leases | 27 | 94 |
Financing leases | 831 | 4,793 |
TNMP | ||
Cash paid for amounts included in the measurement of lease liabilities: | ||
Operating cash flows from operating leases | 26 | 155 |
Operating cash flows from financing leases | 53 | 38 |
Finance cash flows from financing leases | 533 | 646 |
Non-cash information related to right-of-use assets obtained in exchange for lease obligations: | ||
Operating leases | 69 | 6 |
Financing leases | $ 1,736 | $ 1,783 |
Lease Commitments - Schedule _3
Lease Commitments - Schedule of Future Expected Lease Payments (Details) $ in Thousands | Jun. 30, 2024 USD ($) |
Financing | |
Remainder of 2024 | $ 4,846 |
2025 | 8,357 |
2026 | 6,592 |
2027 | 3,914 |
2028 | 1,426 |
Later years | 728 |
Total minimum lease payments | 25,863 |
Less: Imputed interest | 1,994 |
Lease liabilities | 23,869 |
Battery Storage | |
Operating | |
Remainder of 2024 | 5,893 |
2025 | 11,786 |
2026 | 11,786 |
2027 | 11,786 |
2028 | 11,786 |
Later years | 172,254 |
Total minimum lease payments | 225,291 |
Less: Imputed interest | 90,546 |
Lease liabilities | 134,745 |
Other | |
Operating | |
Remainder of 2024 | 648 |
2025 | 7,935 |
2026 | 7,190 |
2027 | 7,120 |
2028 | 7,122 |
Later years | 11,013 |
Total minimum lease payments | 41,028 |
Less: Imputed interest | 5,347 |
Lease liabilities | 35,681 |
PNM | |
Financing | |
Remainder of 2024 | 2,202 |
2025 | 3,797 |
2026 | 3,269 |
2027 | 2,026 |
2028 | 913 |
Later years | 614 |
Total minimum lease payments | 12,821 |
Less: Imputed interest | 1,066 |
Lease liabilities | 11,755 |
PNM | Battery Storage | |
Operating | |
Remainder of 2024 | 5,893 |
2025 | 11,786 |
2026 | 11,786 |
2027 | 11,786 |
2028 | 11,786 |
Later years | 172,254 |
Total minimum lease payments | 225,291 |
Less: Imputed interest | 90,546 |
Lease liabilities | 134,745 |
PNM | Other | |
Operating | |
Remainder of 2024 | 161 |
2025 | 7,082 |
2026 | 7,031 |
2027 | 7,035 |
2028 | 7,038 |
Later years | 10,587 |
Total minimum lease payments | 38,934 |
Less: Imputed interest | 5,107 |
Lease liabilities | 33,827 |
TNMP | |
Financing | |
Remainder of 2024 | 2,595 |
2025 | 4,471 |
2026 | 3,235 |
2027 | 1,800 |
2028 | 501 |
Later years | 113 |
Total minimum lease payments | 12,715 |
Less: Imputed interest | 901 |
Lease liabilities | 11,814 |
Operating | |
Remainder of 2024 | 454 |
2025 | 787 |
2026 | 90 |
2027 | 14 |
2028 | 11 |
Later years | 0 |
Total minimum lease payments | 1,356 |
Less: Imputed interest | 64 |
Lease liabilities | $ 1,292 |
Income Taxes (Details)
Income Taxes (Details) - USD ($) $ in Millions | 6 Months Ended | 12 Months Ended |
Jun. 30, 2024 | Dec. 31, 2017 | |
Income Tax Contingency [Line Items] | ||
Effective tax rate | 15.29% | |
Regulatory disallowances, tax effect | $ 1.1 | |
Sale of equity method investee, tax effect | 19.5 | |
Income tax assessment | 0.1 | |
Deferred federal, state and local, income taxes | $ 23.3 | |
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 | 5 years | 23 years |
Unprotected excess deferred income taxes | $ 62.7 | |
PNM | ||
Income Tax Contingency [Line Items] | ||
Effective tax rate | 14.31% | |
Income tax assessment | $ 0.1 | |
Deferred federal, state and local, income taxes | $ 20.7 | |
TNMP | ||
Income Tax Contingency [Line Items] | ||
Effective tax rate | 20.71% | |
Income tax assessment | $ 0.1 | |
Deferred federal, state and local, income taxes | $ 2.6 |
Related Party Transactions (Det
Related Party Transactions (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Services billings: | PNMR to PNM | ||||
Related Party Transaction [Line Items] | ||||
Amount of related party transaction | $ 31,023 | $ 29,142 | $ 66,430 | $ 60,642 |
Services billings: | PNMR to TNMP | ||||
Related Party Transaction [Line Items] | ||||
Amount of related party transaction | 12,885 | 11,333 | 27,121 | 23,727 |
Services billings: | PNM to TNMP | ||||
Related Party Transaction [Line Items] | ||||
Amount of related party transaction | 109 | 104 | 190 | 169 |
Services billings: | TNMP to PNMR | ||||
Related Party Transaction [Line Items] | ||||
Amount of related party transaction | 0 | 35 | 10 | 71 |
Services billings: | PNMR to NMRD | ||||
Related Party Transaction [Line Items] | ||||
Amount of related party transaction | 0 | 82 | 66 | 164 |
Renewable energy purchases: | PNM from NMRD | ||||
Related Party Transaction [Line Items] | ||||
Amount of related party transaction | 0 | 3,748 | 1,523 | 6,109 |
Interest billings: | PNMR to PNM | ||||
Related Party Transaction [Line Items] | ||||
Amount of related party transaction | 25 | 7 | 39 | 10 |
Interest billings: | PNMR to TNMP | ||||
Related Party Transaction [Line Items] | ||||
Amount of related party transaction | 22 | 117 | 179 | 128 |
Interest billings: | PNM to PNMR | ||||
Related Party Transaction [Line Items] | ||||
Amount of related party transaction | 154 | 143 | 309 | 273 |
Income tax sharing payments: | PNMR to PNM | ||||
Related Party Transaction [Line Items] | ||||
Amount of related party transaction | 0 | 0 | 0 | 0 |
Income tax sharing payments: | TNMP to PNMR | ||||
Related Party Transaction [Line Items] | ||||
Amount of related party transaction | $ 0 | $ 0 | $ 0 | $ 0 |
Equity Method Investment - Narr
Equity Method Investment - Narrative (Details) - USD ($) $ in Thousands | 6 Months Ended | ||
Feb. 27, 2024 | Jun. 30, 2024 | Jun. 30, 2023 | |
Business Acquisition [Line Items] | |||
Gain on sale of NMRD | $ 4,400 | $ 4,449 | $ 0 |
Investment tax credit | 15,700 | ||
PNMR Development | NMRD | |||
Business Acquisition [Line Items] | |||
Contribution to construction activities | $ 12,600 | $ 14,800 | |
Disposal Group, Disposed of by Sale, Not Discontinued Operations | NMRD | |||
Business Acquisition [Line Items] | |||
Proceeds from interests | $ 117,000 |
Equity Method Investment - Summ
Equity Method Investment - Summarized Financial Information (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | Dec. 31, 2023 | |
Results of Operations | |||||
Operating revenues | $ 488,102 | $ 477,156 | $ 924,979 | $ 1,021,233 | |
Financial Position | |||||
Net property, plant, and equipment | 727,130 | 727,130 | $ 589,834 | ||
Total assets | 10,583,410 | 9,626,970 | 10,583,410 | 9,626,970 | 10,252,605 |
Total PNM common stockholder’s equity | 2,402,748 | 2,402,748 | 2,349,093 | ||
NMRD | |||||
Results of Operations | |||||
Operating revenues | 0 | 3,975 | 3,204 | 6,505 | |
Operating expenses | 0 | 1,965 | 3,378 | 4,384 | |
Net Earnings Attributable to PNM | 0 | $ 2,010 | (174) | $ 2,121 | |
Financial Position | |||||
Current assets | 0 | 0 | 2,589 | ||
Net property, plant, and equipment | 0 | 0 | 235,791 | ||
Non-current assets | 0 | 0 | 1,849 | ||
Total assets | 0 | 0 | 240,229 | ||
Current liabilities | 0 | 0 | 730 | ||
Non-current liabilities | 0 | 0 | 358 | ||
Total PNM common stockholder’s equity | $ 0 | $ 0 | $ 239,141 |
Goodwill (Details)
Goodwill (Details) - USD ($) $ in Thousands | Jun. 30, 2024 | Apr. 01, 2024 | Dec. 31, 2023 | Jun. 30, 2023 | Apr. 01, 2020 | Apr. 01, 2018 |
Goodwill [Line Items] | ||||||
Goodwill | $ 278,297 | $ 278,297 | $ 278,297 | |||
PNM | ||||||
Goodwill [Line Items] | ||||||
Goodwill | 51,632 | $ 51,600 | 51,632 | $ 51,600 | ||
Goodwill fair value exceeded by its carrying value | 54% | 19% | ||||
TNMP | ||||||
Goodwill [Line Items] | ||||||
Goodwill | $ 226,665 | $ 226,665 | $ 226,700 | |||
Goodwill fair value exceeded by its carrying value | 38% |