Public Service Company of New Mexico PFD 4.58% (PNMXO) 10-K 28 Feb 17 2016 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2016	Feb. 21, 2017	Jun. 30, 2016
Document Information [Line Items]
Entity Registrant Name	PNM RESOURCES INC
Entity Central Index Key	1,108,426
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-K
Document Period End Date	Dec. 31, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Common Stock, Shares Outstanding		79,653,624
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 2,822,924,435
Public Service Company of New Mexico [Member]
Document Information [Line Items]
Entity Registrant Name	PUBLIC SERVICE CO OF NEW MEXICO
Entity Central Index Key	81,023
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Document Type	10-K
Document Period End Date	Dec. 31, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Common Stock, Shares Outstanding		39,117,799
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Texas-New Mexico Power Company [Member]
Document Information [Line Items]
Entity Registrant Name	TEXAS NEW MEXICO POWER CO
Entity Central Index Key	22,767
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Document Type	10-K
Document Period End Date	Dec. 31, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Common Stock, Shares Outstanding		6,358
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	Yes
Entity Current Reporting Status	No

Consolidated Statements of Earn

Consolidated Statements of Earnings - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Electric Operating Revenues	$ 1,362,951	$ 1,439,082	$ 1,435,853
Operating Expenses:
Cost of energy	380,596	464,649	471,556
Administrative and general	191,514	179,100	171,111
Energy production costs	146,187	176,752	185,638
Regulatory disallowances and restructuring costs	15,011	167,471	1,062
Depreciation and amortization	209,110	185,919	172,634
Transmission and distribution costs	66,227	69,157	66,571
Taxes other than income taxes	76,321	71,684	67,584
Total operating expenses	1,084,966	1,314,732	1,136,156
Operating income	277,985	124,350	299,697
Other Income and Deductions:
Interest income	22,293	6,498	8,483
Gains on available-for-sale securities	19,517	16,060	10,527
Other income	17,796	26,833	12,048
Other (deductions)	(13,784)	(12,728)	(10,481)
Net other income and deductions	45,822	36,663	20,577
Interest Charges	128,633	114,860	119,627
Earnings before Income Taxes	195,174	46,153	200,647
Income Taxes	63,278	15,075	69,738
Net Earnings	131,896	31,078	130,909
(Earnings) Attributable to Valencia Non-controlling Interest	(14,519)	(14,910)	(14,127)
Preferred Stock Dividend Requirements of Subsidiary	(528)	(528)	(528)
Net Earnings Attributable to Company	116,849	15,640	116,254
Net Earnings (Loss) Available for PNM Common Stock	$ 116,849	$ 15,640	$ 116,254
Net Earnings Attributable to PNMR per Common Share:
Basic (dollars per share)	$ 1.47	$ 0.20	$ 1.46
Diluted (dollars per share)	$ 1.46	$ 0.20	$ 1.45
Public Service Company of New Mexico [Member]
Electric Operating Revenues	$ 1,035,913	$ 1,131,195	$ 1,147,914
Operating Expenses:
Cost of energy	299,714	391,131	403,626
Administrative and general	169,209	161,953	152,645
Energy production costs	146,187	176,752	185,638
Regulatory disallowances and restructuring costs	15,011	167,471	1,062
Depreciation and amortization	133,447	115,717	109,524
Transmission and distribution costs	39,657	43,642	43,128
Taxes other than income taxes	44,598	41,149	39,578
Total operating expenses	847,823	1,097,815	935,201
Operating income	188,090	33,380	212,713
Other Income and Deductions:
Interest income	10,173	6,574	8,557
Gains on available-for-sale securities	19,517	16,060	10,527
Other income	12,088	19,347	8,949
Other (deductions)	(9,539)	(8,493)	(7,218)
Net other income and deductions	32,239	33,488	20,815
Interest Charges	87,469	79,950	79,442
Earnings before Income Taxes	132,860	(13,082)	154,086
Income Taxes	40,922	(12,758)	52,633
Net Earnings	91,938	(324)	101,453
(Earnings) Attributable to Valencia Non-controlling Interest	(14,519)	(14,910)	(14,127)
Preferred Stock Dividend Requirements of Subsidiary	(528)	(528)	(528)
Net Earnings Attributable to Company	77,419	(15,234)	87,326
Net Earnings (Loss) Available for PNM Common Stock	76,891	(15,762)	86,798
Texas-New Mexico Power Company [Member]
Electric Operating Revenues	327,038	307,887	287,939
Operating Expenses:
Cost of energy	80,882	73,518	67,930
Administrative and general	39,423	36,755	36,982
Depreciation and amortization	61,126	56,285	50,056
Transmission and distribution costs	26,570	25,515	23,443
Taxes other than income taxes	27,396	25,781	23,940
Total operating expenses	235,397	217,854	202,351
Operating income	91,641	90,033	85,588
Other Income and Deductions:
Other income	4,629	4,240	2,865
Other (deductions)	(1,427)	(504)	(727)
Net other income and deductions	3,202	3,736	2,138
Interest Charges	29,335	27,681	27,396
Earnings before Income Taxes	65,508	66,088	60,330
Income Taxes	23,836	24,125	22,523
Net Earnings Attributable to Company	$ 41,672	$ 41,963	$ 37,807

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income (Loss) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Net Earnings	$ 131,896	$ 31,078	$ 130,909
Net Earnings	116,849	15,640	116,254
Unrealized Gains on Available-for-Sale Securities:
Unrealized holding gains (losses) arising during the period, net of income tax (expense) benefit	474	6,688	10,661
Reclassification adjustment for (gains) included in net earnings (loss), net of income tax expense	(13,500)	(17,350)	(8,401)
Pension Liability Adjustment:
Experience gain (loss), net of income tax (expense) benefit	(11,282)	(2,679)	(9,258)
Reclassification adjustment for amortization of experience (gain) loss recognized as net periodic benefit cost, net of income tax (expense) benefit	3,356	3,620	3,120
Fair Value Adjustment for Cash Flow Hedges:
Change in fair market value, net of income tax (expense) benefit	(533)	44	(100)
Reclassification adjustment for (gains) losses included in net earnings (loss), net of income tax expense (benefit)	466	0	363
Total Other Comprehensive Income (Loss)	(21,019)	(9,677)	(3,615)
Comprehensive Income (Loss)	110,877	21,401	127,294
Comprehensive (Income) Attributable to Valencia Non-controlling Interest	(14,519)	(14,910)	(14,127)
Preferred Stock Dividend Requirements of Subsidiary	(528)	(528)	(528)
Comprehensive Income (Loss) Attributable to PNM	95,830	5,963	112,639
Public Service Company of New Mexico [Member]
Net Earnings	91,938	(324)	101,453
Net Earnings	77,419	(15,234)	87,326
Unrealized Gains on Available-for-Sale Securities:
Unrealized holding gains (losses) arising during the period, net of income tax (expense) benefit	474	6,688	10,661
Reclassification adjustment for (gains) included in net earnings (loss), net of income tax expense	(13,500)	(17,350)	(8,401)
Pension Liability Adjustment:
Experience gain (loss), net of income tax (expense) benefit	(11,282)	(2,679)	(9,258)
Reclassification adjustment for amortization of experience (gain) loss recognized as net periodic benefit cost, net of income tax (expense) benefit	3,356	3,620	3,120
Fair Value Adjustment for Cash Flow Hedges:
Total Other Comprehensive Income (Loss)	(20,952)	(9,721)	(3,878)
Comprehensive Income (Loss)	70,986	(10,045)	97,575
Comprehensive (Income) Attributable to Valencia Non-controlling Interest	(14,519)	(14,910)	(14,127)
Preferred Stock Dividend Requirements of Subsidiary	(528)	(528)	(528)
Comprehensive Income (Loss) Attributable to PNM	56,467	(24,955)	83,448
Texas-New Mexico Power Company [Member]
Net Earnings	41,672	41,963	37,807
Fair Value Adjustment for Cash Flow Hedges:
Change in fair market value, net of income tax (expense) benefit	0	0	(100)
Reclassification adjustment for (gains) losses included in net earnings (loss), net of income tax expense (benefit)	0	0	363
Total Other Comprehensive Income (Loss)	0	0	263
Comprehensive Income (Loss) Attributable to PNM	$ 41,672	$ 41,963	$ 38,070

Consolidated Statements of Com4

Consolidated Statements of Comprehensive Income (Loss) (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Unrealized holding gains (losses) arising during the period, income tax (expense)	$ (304)	$ (4,310)	$ (6,812)
Reclassification adjustment for (gains) included in net earnings (loss), income tax expense	8,639	11,181	5,461
Experience gain (loss), income tax (expense) benefit	7,219	1,726	6,024
Reclassification adjustment for amortization of experience (gain) loss recognized as net periodic benefit cost, income tax (expense) benefit	(2,148)	(2,332)	(2,032)
Change in fair market value, income tax (expense)	341	(28)	53
Reclassification adjustment for (gains) losses included in net earnings (loss), income tax expense (benefit)	(298)	0	(195)
Public Service Company of New Mexico [Member]
Unrealized holding gains (losses) arising during the period, income tax (expense)	(304)	(4,310)	(6,812)
Reclassification adjustment for (gains) included in net earnings (loss), income tax expense	8,639	11,181	5,461
Experience gain (loss), income tax (expense) benefit	7,219	1,726	6,024
Reclassification adjustment for amortization of experience (gain) loss recognized as net periodic benefit cost, income tax (expense) benefit	(2,148)	(2,332)	(2,032)
Texas-New Mexico Power Company [Member]
Change in fair market value, income tax (expense)	0	0	53
Reclassification adjustment for (gains) losses included in net earnings (loss), income tax expense (benefit)	$ 0	$ 0	$ (195)

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cash Flows From Operating Activities:
Net Earnings	$ 131,896,000	$ 31,078,000	$ 130,909,000
Net Earnings	116,849,000	15,640,000	116,254,000
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	242,033,000	222,861,000	209,867,000
Net unrealized (gains) losses on commodity derivatives	1,577,000	5,188,000	(6,504,000)
Realized (gains) on available-for-sale securities	(19,517,000)	(16,060,000)	(10,527,000)
Stock based compensation expense	5,634,000	4,863,000	5,931,000
Regulatory disallowances and restructuring costs	15,011,000	167,471,000	1,062,000
Deferred income tax expense	63,805,000	16,451,000	72,481,000
Allowance for equity funds used during construction	(4,949,000)	(10,430,000)	(5,563,000)
Other, net	3,060,000	3,934,000	4,045,000
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	2,543,000	(3,298,000)	(4,975,000)
Materials, supplies, and fuel stock	(4,169,000)	(180,000)	5,504,000
Other current assets	(2,469,000)	29,370,000	(30,436,000)
Other assets	(42,864,000)	2,369,000	290,000
Accounts payable	3,159,000	(32,269,000)	(2,311,000)
Accrued interest and taxes	3,345,000	4,957,000	2,040,000
Other current liabilities	(12,509,000)	2,633,000	(2,453,000)
Other liabilities	29,868,000	(42,064,000)	45,516,000
Net cash flows from operating activities	415,454,000	386,874,000	414,876,000
Cash Flows From Investing Activities:
Additions to utility and non-utility plant	(600,076,000)	(558,589,000)	(460,658,000)
Proceeds from sales of available-for-sale securities	522,601,000	252,174,000	117,989,000
Purchases of available-for-sale securities	(538,383,000)	(262,548,000)	(127,016,000)
Return of principal on PVNGS lessor notes	8,547,000	21,694,000	20,758,000
Purchase of Rio Bravo	0	0	(36,235,000)
Investment in Westmoreland Loan	(122,250,000)	0	0
Principal repayments on Westmoreland Loan	30,000,000	0	0
Other, net	186,000	2,741,000	(167,000)
Net cash flows from investing activities	(699,375,000)	(544,528,000)	(485,329,000)
Cash Flows From Financing Activities:
Short-term loan	100,000,000	50,000,000	0
Repayment of short-term loan	(150,000,000)	0	0
Revolving credit facilities borrowings (repayments), net	86,500,000	95,000,000	(43,600,000)
Long-term borrowings	603,500,000	463,605,000	355,000,000
Repayment of long-term debt	(303,793,000)	(333,066,000)	(125,000,000)
Proceeds from stock option exercise	7,028,000	5,619,000	6,999,000
Awards of common stock	(15,451,000)	(17,720,000)	(17,319,000)
Dividends paid	(70,623,000)	(64,251,000)	(59,468,000)
Valencia’s transactions with its owner	(17,006,000)	(17,049,000)	(17,610,000)
Other, net	2,237,000	(6,707,000)	(2,808,000)
Net cash flows from financing activities	242,392,000	175,431,000	96,194,000
Change in Cash and Cash Equivalents	(41,529,000)	17,777,000	25,741,000
Cash and Cash Equivalents at Beginning of Period	46,051,000	28,274,000	2,533,000
Cash and Cash Equivalents at End of Period	4,522,000	46,051,000	28,274,000
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	115,043,000	103,382,000	108,741,000
Income taxes paid (refunded), net	(307,000)	(1,890,000)	(2,597,000)
Supplemental schedule of noncash investing and financing activities:
(Increase) decrease in accrued plant additions	18,345,000	(19,080,000)	(3,089,000)
Public Service Company of New Mexico [Member]
Cash Flows From Operating Activities:
Net Earnings	91,938,000	(324,000)	101,453,000
Net Earnings	77,419,000	(15,234,000)	87,326,000
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	166,047,000	150,538,000	143,303,000
Net unrealized (gains) losses on commodity derivatives	1,577,000	5,188,000	(6,504,000)
Realized (gains) on available-for-sale securities	(19,517,000)	(16,060,000)	(10,527,000)
Regulatory disallowances and restructuring costs	15,011,000	167,471,000	1,062,000
Deferred income tax expense	53,119,000	(2,836,000)	55,787,000
Allowance for equity funds used during construction	(4,163,000)	(10,430,000)	(5,563,000)
Other, net	3,046,000	2,794,000	4,172,000
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	4,769,000	(2,515,000)	(5,919,000)
Materials, supplies, and fuel stock	(3,924,000)	381,000	5,570,000
Other current assets	1,127,000	23,693,000	(29,146,000)
Other assets	(23,880,000)	4,194,000	7,150,000
Accounts payable	5,614,000	(31,139,000)	212,000
Accrued interest and taxes	(9,601,000)	(5,343,000)	(3,599,000)
Other current liabilities	(12,136,000)	(275,000)	(659,000)
Other liabilities	20,119,000	(33,503,000)	42,325,000
Net cash flows from operating activities	289,146,000	251,834,000	299,117,000
Cash Flows From Investing Activities:
Additions to utility and non-utility plant	(445,464,000)	(404,840,000)	(316,800,000)
Proceeds from sales of available-for-sale securities	522,601,000	252,174,000	117,989,000
Purchases of available-for-sale securities	(538,383,000)	(262,548,000)	(127,016,000)
Return of principal on PVNGS lessor notes	8,547,000	21,694,000	20,758,000
Purchase of Rio Bravo	0	0	(36,235,000)
Other, net	171,000	2,935,000	(363,000)
Net cash flows from investing activities	(452,528,000)	(390,585,000)	(341,667,000)
Cash Flows From Financing Activities:
Revolving credit facilities borrowings (repayments), net	61,000,000	0	(49,200,000)
Short-term borrowings (repayments) - affiliate, net	0	0	(32,500,000)
Long-term borrowings	321,000,000	313,605,000	275,000,000
Repayment of long-term debt	(271,000,000)	(214,300,000)	(75,000,000)
Equity contribution from parent	28,142,000	175,000,000	0
Dividends paid	(4,670,000)	(94,968,000)	(30,791,000)
Valencia’s transactions with its owner	(17,006,000)	(17,049,000)	(17,610,000)
Other, net	3,102,000	(5,879,000)	(1,890,000)
Net cash flows from financing activities	120,568,000	156,409,000	68,009,000
Change in Cash and Cash Equivalents	(42,814,000)	17,658,000	25,459,000
Cash and Cash Equivalents at Beginning of Period	43,138,000	25,480,000	21,000
Cash and Cash Equivalents at End of Period	324,000	43,138,000	25,480,000
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	82,514,000	69,936,000	73,787,000
Income taxes paid (refunded), net	(967,000)	(1,450,000)	(228,000)
Supplemental schedule of noncash investing and financing activities:
(Increase) decrease in accrued plant additions	22,433,000	(17,469,000)	(1,616,000)
Texas-New Mexico Power Company [Member]
Cash Flows From Operating Activities:
Net Earnings	41,672,000	41,963,000	37,807,000
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	62,866,000	57,909,000	52,847,000
Deferred income tax expense	12,662,000	20,883,000	20,549,000
Allowance for equity funds used during construction	(800,000)	0	0
Allowance for equity funds used during construction and other, net	(772,000)	18,000	(10,000)
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	(2,226,000)	(783,000)	944,000
Materials, supplies, and fuel stock	(245,000)	(561,000)	(66,000)
Other current assets	(621,000)	3,928,000	380,000
Other assets	(19,126,000)	(2,310,000)	(6,607,000)
Accounts payable	(2,040,000)	(1,782,000)	2,514,000
Accrued interest and taxes	12,690,000	4,317,000	4,796,000
Other current liabilities	298,000	1,019,000	(203,000)
Other liabilities	6,822,000	(9,823,000)	3,112,000
Net cash flows from operating activities	111,980,000	114,778,000	116,063,000
Cash Flows From Investing Activities:
Additions to utility and non-utility plant	(122,518,000)	(124,584,000)	(127,191,000)
Net cash flows from investing activities	(122,518,000)	(124,584,000)	(127,191,000)
Cash Flows From Financing Activities:
Revolving credit facilities borrowings (repayments), net	(59,000,000)	54,000,000	5,000,000
Short-term borrowings (repayments) - affiliate, net	(7,200,000)	(10,900,000)	(6,700,000)
Long-term borrowings	60,000,000	0	80,000,000
Repayment of long-term debt	0	0	(50,000,000)
Equity contribution from parent	50,000,000	0	0
Dividends paid	(31,817,000)	(33,248,000)	(16,336,000)
Other, net	(775,000)	(46,000)	(836,000)
Net cash flows from financing activities	11,208,000	9,806,000	11,128,000
Change in Cash and Cash Equivalents	670,000	0	0
Cash and Cash Equivalents at Beginning of Period	1,000	1,000	1,000
Cash and Cash Equivalents at End of Period	671,000	1,000	1,000
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	26,766,000	26,216,000	22,803,000
Income taxes paid (refunded), net	660,000	290,000	(355,000)
Supplemental schedule of noncash investing and financing activities:
(Increase) decrease in accrued plant additions	$ (1,271,000)	$ (5,000)	$ 854,000

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($)	Dec. 31, 2016	Dec. 31, 2015
Current Assets:
Cash and cash equivalents	$ 4,522,000	$ 46,051,000
Accounts receivable, net of allowance for uncollectible accounts	87,012,000	98,699,000
Unbilled revenues	58,284,000	52,012,000
Other receivables	28,245,000	28,590,000
Current portion of Westmoreland Loan	38,360,000	0
Materials, supplies, and fuel stock	73,027,000	67,386,000
Regulatory assets	3,855,000	1,070,000
Commodity derivative instruments	5,224,000	3,813,000
Income taxes receivable	6,066,000	5,845,000
Other current assets	73,444,000	82,104,000
Total current assets	378,039,000	385,570,000
Other Property and Investments:
Long-term portion of Westmoreland Loan	56,640,000	0
Available-for-sale securities	272,977,000	259,042,000
Other investments	547,000	604,000
Non-utility property	3,404,000	3,404,000
Total other property and investments	333,568,000	263,050,000
Utility Plant:
Plant in service, held for future use, and to be abandoned	6,944,534,000	6,307,261,000
Less accumulated depreciation and amortization	2,334,938,000	2,058,772,000
Net plant in service and plant held for future use	4,609,596,000	4,248,489,000
Construction work in progress	208,206,000	204,766,000
Nuclear fuel, net of accumulated amortization	86,913,000	82,117,000
Net utility plant	4,904,715,000	4,535,372,000
Deferred Charges and Other Assets:
Regulatory assets	501,223,000	470,664,000
Goodwill	278,297,000	278,297,000
Commodity derivative instruments	0	2,622,000
Other deferred charges	75,238,000	73,753,000
Total deferred charges and other assets	854,758,000	825,336,000
Total assets	6,471,080,000	6,009,328,000
Current Liabilities:
Short-term debt	287,100,000	250,600,000
Current installments of long-term debt	273,348,000	124,979,000
Accounts payable	86,705,000	100,419,000
Customer deposits	11,374,000	12,216,000
Accrued interest and taxes	61,871,000	58,306,000
Regulatory liabilities	3,609,000	15,591,000
Commodity derivative instruments	2,339,000	1,859,000
Dividends declared	19,448,000	17,656,000
Other current liabilities	59,314,000	59,494,000
Total current liabilities	805,108,000	641,120,000
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs	2,119,364,000	1,966,969,000
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	940,650,000	877,393,000
Regulatory liabilities	455,649,000	467,413,000
Asset retirement obligations	127,519,000	111,895,000
Accrued pension liability and postretirement benefit cost	125,844,000	73,097,000
Other deferred credits	140,545,000	133,692,000
Total deferred credits and other liabilities	1,790,207,000	1,663,490,000
Total liabilities	4,714,679,000	4,271,579,000
Commitments and Contingencies (See Note 16)
Cumulative Preferred Stock of Subsidiary without mandatory redemption requirements ($100 stated value; 10,000,000 shares authorized; issued and outstanding 115,293 shares)	11,529,000	11,529,000
Company common stockholders’ equity:
Common stock outstanding	1,163,661,000	1,166,465,000
Accumulated other comprehensive income (loss), net of income taxes	(92,451,000)	(71,432,000)
Retained earnings	604,742,000	559,780,000
Total PNMR common stockholders’ equity	1,675,952,000	1,654,813,000
Non-controlling interest in Valencia	68,920,000	71,407,000
Total equity	1,744,872,000	1,726,220,000
Total liabilities and stockholders' equity	6,471,080,000	6,009,328,000
Public Service Company of New Mexico [Member]
Current Assets:
Cash and cash equivalents	324,000	43,138,000
Accounts receivable, net of allowance for uncollectible accounts	65,003,000	78,291,000
Unbilled revenues	48,289,000	42,641,000
Other receivables	25,514,000	24,725,000
Affiliate receivables	8,886,000	15,105,000
Materials, supplies, and fuel stock	64,401,000	60,477,000
Regulatory assets	3,442,000	0
Commodity derivative instruments	5,224,000	3,813,000
Income taxes receivable	25,807,000	14,577,000
Other current assets	67,355,000	74,990,000
Total current assets	314,245,000	357,757,000
Other Property and Investments:
Available-for-sale securities	272,977,000	259,042,000
Other investments	316,000	366,000
Non-utility property	96,000	96,000
Total other property and investments	273,389,000	259,504,000
Utility Plant:
Plant in service, held for future use, and to be abandoned	5,359,211,000	4,833,303,000
Less accumulated depreciation and amortization	1,809,528,000	1,569,549,000
Net plant in service and plant held for future use	3,549,683,000	3,263,754,000
Construction work in progress	158,122,000	172,238,000
Nuclear fuel, net of accumulated amortization	86,913,000	82,117,000
Net utility plant	3,794,718,000	3,518,109,000
Deferred Charges and Other Assets:
Regulatory assets	365,413,000	342,910,000
Goodwill	51,632,000	51,632,000
Commodity derivative instruments	0	2,622,000
Other deferred charges	68,149,000	66,810,000
Total deferred charges and other assets	485,194,000	463,974,000
Total assets	4,867,546,000	4,599,344,000
Current Liabilities:
Short-term debt	61,000,000	0
Short-term debt - affiliate	0
Current installments of long-term debt	231,880,000	124,979,000
Accounts payable	55,566,000	72,386,000
Affiliate payables	23,183,000	14,318,000
Customer deposits	11,374,000	12,216,000
Accrued interest and taxes	34,819,000	33,189,000
Regulatory liabilities	3,517,000	15,591,000
Commodity derivative instruments	2,339,000	1,859,000
Dividends declared	132,000	132,000
Other current liabilities	33,551,000	42,251,000
Total current liabilities	457,361,000	316,921,000
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs	1,399,489,000	1,455,698,000
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	748,666,000	696,384,000
Regulatory liabilities	423,701,000	434,863,000
Asset retirement obligations	126,601,000	111,049,000
Accrued pension liability and postretirement benefit cost	114,427,000	66,285,000
Other deferred credits	118,980,000	117,275,000
Total deferred credits and other liabilities	1,532,375,000	1,425,856,000
Total liabilities	3,389,225,000	3,198,475,000
Commitments and Contingencies (See Note 16)
Cumulative Preferred Stock of Subsidiary without mandatory redemption requirements ($100 stated value; 10,000,000 shares authorized; issued and outstanding 115,293 shares)	11,529,000	11,529,000
Company common stockholders’ equity:
Common stock outstanding	1,264,918,000	1,236,776,000
Accumulated other comprehensive income (loss), net of income taxes	(92,428,000)	(71,476,000)
Retained earnings	225,382,000	152,633,000
Total PNMR common stockholders’ equity	1,397,872,000	1,317,933,000
Non-controlling interest in Valencia	68,920,000	71,407,000
Total equity	1,466,792,000	1,389,340,000
Total liabilities and stockholders' equity	4,867,546,000	4,599,344,000
Texas-New Mexico Power Company [Member]
Current Assets:
Cash and cash equivalents	671,000	1,000
Accounts receivable, net of allowance for uncollectible accounts	22,009,000	20,408,000
Unbilled revenues	9,995,000	9,371,000
Other receivables	2,090,000	811,000
Materials, supplies, and fuel stock	8,626,000	6,909,000
Regulatory assets	413,000	1,070,000
Other current assets	1,031,000	1,053,000
Total current assets	44,835,000	39,623,000
Other Property and Investments:
Other investments	231,000	238,000
Non-utility property	2,240,000	2,240,000
Total other property and investments	2,471,000	2,478,000
Utility Plant:
Plant in service, held for future use, and to be abandoned	1,380,584,000	1,285,727,000
Less accumulated depreciation and amortization	429,397,000	406,516,000
Net plant in service and plant held for future use	951,187,000	879,211,000
Construction work in progress	16,978,000	16,561,000
Net utility plant	968,165,000	895,772,000
Deferred Charges and Other Assets:
Regulatory assets	135,810,000	127,754,000
Goodwill	226,665,000	226,665,000
Other deferred charges	5,277,000	4,847,000
Total deferred charges and other assets	367,752,000	359,266,000
Total assets	1,383,223,000	1,297,139,000
Current Liabilities:
Short-term debt	0	59,000,000
Short-term debt - affiliate	4,600,000	11,800,000
Accounts payable	16,709,000	16,006,000
Affiliate payables	3,793,000	3,681,000
Accrued interest and taxes	45,581,000	32,891,000
Regulatory liabilities	92,000	0
Other current liabilities	2,134,000	2,044,000
Total current liabilities	72,909,000	125,422,000
Long-term Debt, net of Unamortized Premiums, Discounts, and Debt Issuance Costs	420,875,000	361,411,000
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	245,785,000	232,791,000
Regulatory liabilities	31,948,000	32,550,000
Asset retirement obligations	754,000	695,000
Accrued pension liability and postretirement benefit cost	11,417,000	6,812,000
Other deferred credits	6,300,000	4,078,000
Total deferred credits and other liabilities	296,204,000	276,926,000
Total liabilities	789,988,000	763,759,000
Commitments and Contingencies (See Note 16)
Company common stockholders’ equity:
Common stock outstanding	64,000	64,000
Paid-in-capital	454,166,000	404,166,000
Retained earnings	139,005,000	129,150,000
Total PNMR common stockholders’ equity	593,235,000	533,380,000
Total liabilities and stockholders' equity	$ 1,383,223,000	$ 1,297,139,000

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Allowance for uncollectible accounts	$ 1,209	$ 1,397
Accumulated depreciation, nuclear fuel	$ 43,905	$ 44,455
Cumulative preferred stock of subsidiary, stated value (in dollars per share)	$ 100	$ 100
Cumulative preferred stock of subsidiary, shares authorized	10,000,000	10,000,000
Cumulative preferred stock of subsidiary, shares issued	115,293	115,293
Cumulative preferred stock of subsidiary, shares outstanding	115,293	115,293
Common stock, no par value (in dollars per share)	$ 0	$ 0
Common stock, shares authorized	120,000,000	120,000,000
Common stock, shares issued	79,653,624	79,653,624
Common stock, shares outstanding	79,653,624	79,653,624
Public Service Company of New Mexico [Member]
Allowance for uncollectible accounts	$ 1,209	$ 1,397
Accumulated depreciation, nuclear fuel	$ 43,905	$ 44,455
Cumulative preferred stock of subsidiary, stated value (in dollars per share)	$ 100	$ 100
Cumulative preferred stock of subsidiary, shares authorized	10,000,000	10,000,000
Cumulative preferred stock of subsidiary, shares issued	115,293	115,293
Cumulative preferred stock of subsidiary, shares outstanding	115,293	115,293
Common stock, no par value (in dollars per share)	$ 0	$ 0
Common stock, shares authorized	40,000,000	40,000,000
Common stock, shares issued	39,117,799	39,117,799
Common stock, shares outstanding	39,117,799	39,117,799
Texas-New Mexico Power Company [Member]
Cumulative preferred stock of subsidiary, shares authorized	1,000,000
Common stock, par value (in dollars per share)	$ 10	$ 10
Common stock, shares authorized	12,000,000	12,000,000
Common stock, shares issued	6,358	6,358
Common stock, shares outstanding	6,358	6,358

Consolidated Statements of Chan

Consolidated Statements of Changes in Equity - USD ($) $ in Thousands	Total	Common Stock [Member]	AOCI [Member]	Retained Earnings [Member]	Total Stockholders' Equity [Member]	Non-controlling Interest in Valencia [Member]	Public Service Company of New Mexico [Member]	Public Service Company of New Mexico [Member]Common Stock [Member]	Public Service Company of New Mexico [Member]AOCI [Member]	Public Service Company of New Mexico [Member]Retained Earnings [Member]	Public Service Company of New Mexico [Member]Total Stockholders' Equity [Member]	Public Service Company of New Mexico [Member]Non-controlling Interest in Valencia [Member]	Texas-New Mexico Power Company [Member]	Texas-New Mexico Power Company [Member]Common Stock [Member]	Texas-New Mexico Power Company [Member]AOCI [Member]	Texas-New Mexico Power Company [Member]Paid-in Capital [Member]	Texas-New Mexico Power Company [Member]Retained Earnings [Member]
Balance at Dec. 31, 2013	$ 1,750,598	$ 1,178,369	$ (58,140)	$ 553,340	$ 1,673,569	$ 77,029	$ 1,287,228	$ 1,061,776	$ (57,877)	$ 206,300	$ 1,210,199	$ 77,029
Beginning Balance at Dec. 31, 2013			(58,140)						(57,877)				$ 502,931	$ 64	$ (263)	$ 404,166	$ 98,964
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net earnings (loss)	130,909			116,782	116,782	14,127	101,453			87,326	87,326	14,127
Net Earnings	116,254						87,326						37,807				37,807
Total other comprehensive income (loss)	(3,615)		(3,615)		(3,615)		(3,878)		(3,878)		(3,878)		263		$ 263
Subsidiary preferred stock dividends/dividends declared on preferred stock	(528)			(528)	(528)		(528)			(528)	(528)
Dividends declared on common stock	(60,138)			(60,138)	(60,138)		(30,263)			(30,263)	(30,263)		(16,336)				(16,336)
Proceeds from stock option exercise	6,999	6,999			6,999
Awards of common stock	(17,319)	(17,319)	0	0	(17,319)	0
Excess tax (shortfall) from stock-based payment arrangements	(135)	(135)			(135)
Stock based compensation expense	5,931	5,931			5,931
Valencia’s transactions with its owner	(17,610)					(17,610)	(17,610)
Balance at Dec. 31, 2014	1,795,092	1,173,845	(61,755)	609,456	1,721,546	73,546	1,336,402	1,061,776	(61,755)	262,835	1,262,856	73,546
Ending Balance at Dec. 31, 2014			(61,755)						(61,755)				524,665	64		404,166	120,435
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net earnings (loss)	31,078			16,168	16,168	14,910	(324)			(15,234)	(15,234)	14,910
Net Earnings	15,640						(15,234)						41,963				41,963
Total other comprehensive income (loss)	(9,677)		(9,677)		(9,677)		(9,721)		(9,721)		(9,721)		0
Subsidiary preferred stock dividends/dividends declared on preferred stock	(528)			(528)	(528)		(528)			(528)	(528)
Dividends declared on common stock	(65,316)			(65,316)	(65,316)		(94,440)			(94,440)	(94,440)		(33,248)				(33,248)
Proceeds from stock option exercise	5,619	5,619			5,619
Awards of common stock	(17,720)	(17,720)	0	0	(17,720)	0
Excess tax (shortfall) from stock-based payment arrangements	(142)	(142)			(142)
Stock based compensation expense	4,863	4,863			4,863
Valencia’s transactions with its owner	(17,049)					(17,049)	(17,049)
Equity contributions from parent							175,000	175,000			175,000
Balance at Dec. 31, 2015	1,726,220	1,166,465	(71,432)	559,780	1,654,813	71,407	1,389,340	1,236,776	(71,476)	152,633	1,317,933	71,407
Ending Balance at Dec. 31, 2015	1,654,813		(71,432)				1,317,933		(71,476)				533,380	64		404,166	129,150
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net earnings (loss)	131,896			117,377	117,377	14,519	91,938			77,419	77,419	14,519
Net Earnings	116,849						77,419						41,672				41,672
Total other comprehensive income (loss)	(21,019)		(21,019)	0	(21,019)		(20,952)		(20,952)		(20,952)		0
Subsidiary preferred stock dividends/dividends declared on preferred stock	(528)			(528)	(528)		(528)			(528)	(528)
Dividends declared on common stock	(71,887)			(71,887)	(71,887)		(4,142)			(4,142)	(4,142)		(31,817)				(31,817)
Proceeds from stock option exercise	7,028	7,028			7,028
Awards of common stock	(15,451)	(15,451)	0	0	(15,451)	0
Excess tax (shortfall) from stock-based payment arrangements	(15)	(15)			(15)
Stock based compensation expense	5,634	5,634			5,634
Valencia’s transactions with its owner	(17,006)					(17,006)	(17,006)
Equity contributions from parent							28,142	28,142			28,142		50,000			50,000
Balance at Dec. 31, 2016	1,744,872	$ 1,163,661	(92,451)	$ 604,742	$ 1,675,952	$ 68,920	1,466,792	$ 1,264,918	(92,428)	$ 225,382	$ 1,397,872	$ 68,920
Ending Balance at Dec. 31, 2016	$ 1,675,952		$ (92,451)				$ 1,397,872		$ (92,428)				$ 593,235	$ 64		$ 454,166	$ 139,005

Summary of the Business and Sig

Summary of the Business and Significant Accounting Policies	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Summary of the Business and Significant Accounting Policies	Summary of the Business and Significant Accounting Policies Nature of Business PNMR is an investor-owned holding company of energy and energy-related businesses. PNMR’s primary subsidiaries are PNM and TNMP. PNM is a public utility with regulated operations primarily engaged in the generation, transmission, and distribution of electricity. TNMP is a wholly owned subsidiary of TNP, which is a holding company that is wholly owned by PNMR. TNMP provides regulated transmission and distribution services in Texas. PNMR’s common stock trades on the New York Stock Exchange under the symbol PNM. Financial Statement Preparation and Presentation The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could ultimately differ from those estimated. The Notes to Consolidated Financial Statements include disclosures for PNMR, PNM, and TNMP. For discussion purposes, 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 2015 and 2014 Consolidated Financial Statements and Notes thereto have been reclassified to conform to the 2016 financial statement presentation. GAAP defines subsequent events as events or transactions that occur after the balance sheet date but before financial statements are issued or are available to be issued. Based on their nature, magnitude, and timing, certain subsequent events may be required to be reflected at the balance sheet date and/or required to be disclosed in the financial statements. The Company has evaluated subsequent events as required by GAAP. Principles of Consolidation The 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 (Note 9) and, through January 15, 2016, the PVNGS Capital Trust. 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 shared services’ administrative and general expenses, which represent costs that are primarily driven by corporate level activities, are charged to the business segments. These services are billed at cost. Other significant intercompany transactions between PNMR, PNM, and TNMP include interest and income tax sharing payments, as well as equity transactions. All intercompany transactions and balances have been eliminated. See Note 3. Accounting for the Effects of Certain Types of Regulation The Company maintains its accounting records in accordance with the uniform system of accounts prescribed by FERC and adopted by the NMPRC and PUCT. Certain of the Company’s operations are regulated by the NMPRC, PUCT, and FERC and the provisions of GAAP for rate-regulated enterprises are applied to the regulated operations. Regulators may assign costs to accounting periods that differ from accounting methods applied by non-regulated utilities. When it is probable that regulators will permit recovery of costs through future rates, costs are deferred as regulatory assets that otherwise would be expensed. Likewise, regulatory liabilities are recognized when it is probable that regulators will require refunds through future rates or when revenue is collected for expenditures that have not yet been incurred. GAAP also provides for the recognition of revenue and regulatory assets and liabilities associated with “alternative revenue programs” authorized by regulators. Such programs allow the utility to adjust future rates in response to past activities or completed events, if certain criteria are met, even for programs that do not otherwise qualify for recognition of regulatory assets and liabilities. Regulatory assets and liabilities are amortized into earnings over the authorized recovery period. Accordingly, the Company has deferred certain costs and recorded certain liabilities pursuant to the rate actions of the NMPRC, PUCT, and FERC. Information on regulatory assets and regulatory liabilities is contained in Note 4. In some circumstances, regulators allow a requested increase in rates to be implemented, subject to refund, before the regulatory process has been completed and a decision rendered by the regulator. When this occurs, the Company assesses the possible outcomes of the rate proceeding. The Company records a provision for refund to the extent the amounts being collected, subject to refund, exceed the amount the Company determines is probable of ultimately being allowed by the regulator. Competition Transition Charge In connection with the adoption of Senate Bill 7 by the Texas Legislature in 1999 that deregulated electric utilities operating within ERCOT, TNMP was allowed to recover its stranded costs through the CTC and to recover a carrying charge on the CTC. The amounts yet to be collected are recorded as regulatory assets by TNMP. TNMP’s calculation of allowable carrying charges on stranded costs recoverable from its transmission and distribution customers is based on a Texas Supreme Court ruling and the PUCT’s application of that ruling. TNMP estimates the CTC will be fully recovered in November 2020. Cash and Cash Equivalents Investments in highly liquid investments with original maturities of three months or less at the date of purchase are considered cash equivalents. Utility Plant Utility plant is stated at cost, which includes capitalized payroll-related costs such as taxes, pension, other fringe benefits, administrative costs, and AFUDC where authorized by rate regulation. Repairs, including major maintenance activities, and minor replacements of property are expensed when incurred, except as required by regulators for ratemaking purposes. Major replacements are charged to utility plant. Gains, losses, and costs to remove resulting from retirements or other dispositions of regulated property in the normal course of business are credited or charged to accumulated depreciation. PNM and TNMP may receive reimbursements, referred to as contributions in aid of construction (“CIAC”), from customers to pay for all or part of certain construction projects to extent that project does not benefit regulated customers in general. PNM and TNMP account for these reimbursements as offsets to utility plant additions based on the requirements of the NMPRC, FERC, and PUCT. Due to the PUCT’s regulatory treatment of CIAC reimbursements, TNMP also receives a financing component that is recognized as other income on the Consolidated Statements of Earnings. Under the NMPRC regulatory treatment, PNM does not receive a financing component. Depreciation and Amortization PNM’s provision for depreciation and amortization of utility plant, other than nuclear fuel, is based upon composite straight-line rates approved by the NMPRC and FERC. Amortization of nuclear fuel is based on units-of-production. TNMP’s provision for depreciation and amortization of utility plant is based upon straight-line rates approved by the PUCT. Depreciation of non-utility property is computed based on the straight-line method. The provision for depreciation of certain equipment is allocated between operating expenses and construction projects based on the use of the equipment. Average straight-line rates used were as follows: Year ended December 31 2016 2015 2014 PNM Electric plant 2.33 % 2.27 % 2.26 % Common, intangible, and general plant 5.40 % 4.66 % 4.64 % TNMP 3.66 % 3.65 % 3.59 % Allowance for Funds Used During Construction As provided by the FERC uniform systems of accounts, AFUDC is charged to regulated utility plant for construction projects. This allowance is a designed to enable a utility to capitalize financing costs during periods of construction of property subject to rate regulation. It represents the cost of borrowed funds (allowance for borrowed funds used during construction or “debt AFUDC”) and a return on other funds (allowance for equity funds used during construction or “equity AFUDC”). The allowance for borrowed funds used during construction is recorded in interest charges and the allowance for equity funds used during construction is recorded in other income on the Consolidated Statements of Earnings. For the years ended December 31, 2016 , 2015 , and 2014 , PNM recorded $5.3 million , $7.8 million , and $4.2 million of allowance for borrowed funds used during construction and $4.2 million , $10.4 million , and $5.6 million of allowance for equity funds used during construction. TNMP recorded $0.9 million , $0.5 million , and $0.5 million of allowance for borrowed funds used during construction and $0.8 million , zero , and zero of allowance for equity funds used during construction. Capitalized Interest The Company capitalizes interest on its construction projects and major computer software projects not subject to the computation of AFUDC. Interest was capitalized at the overall weighted average borrowing rate of 6.1% , 6.6% , and 6.6% for 2016 , 2015 , and 2014 . In 2016 , 2015 , and 2014 , capitalized interest was $1.8 million , $1.5 million , and $1.6 million for PNMR consolidated; $0.8 million , $0.8 million , and $1.1 million for PNM; and less than $0.1 million , $0.1 million , and $0.1 million for TNMP. Materials, Supplies, and Fuel Stock Materials and supplies relate to transmission, distribution, and generating assets. Materials and supplies are charged to inventory when purchased and are expensed or capitalized as appropriate when issued. Materials and supplies are valued using an average costing method. Coal is valued using a rolling weighted average costing method that is updated based on the current period cost per ton. Periodic aerial surveys are performed on the coal piles and adjustments are made. Average cost is equal to net realizable value under the ratemaking process. Inventories consisted of the following at December 31 : PNMR PNM TNMP 2016 2015 2016 2015 2016 2015 (In thousands) Coal $ 19,940 $ 18,356 $ 19,940 $ 18,356 $ — $ — Materials and supplies 53,087 49,030 44,461 42,121 8,626 6,909 $ 73,027 $ 67,386 $ 64,401 $ 60,477 $ 8,626 $ 6,909 Investments In 1985 and 1986, PNM entered into eleven operating leases for interests in certain PVNGS generation facilities (Note 7). The 10.3% and 10.15% lessor notes that were issued by the owners of the assets subject to these leases were subsequently purchased and held by the PVNGS Capital Trust, which was consolidated by PNM. The PVNGS Capital Trust held certain of the lessor notes to their maturities in January 2015 and January 2016. Upon final maturity of the lessor notes, the PVNGS Capital Trust ceased to exist. The PVNGS lessor notes were carried at amortized cost. PNM holds investment securities in the NDT for the purpose of funding its share of the decommissioning costs of PVNGS and trusts for PNM’s share of final reclamation costs related to the coal mines serving SJGS and Four Corners (Note 16). All of these investments are classified as available-for-sale. PNM evaluates the securities for impairment on an on-going basis. Since third party investment managers have sole discretion over the purchase and sales of the securities, PNM records a realized loss as an impairment for any security that has a market value that is less than cost at the end of each quarter. For the years ended December 31, 2016 , 2015 , and 2014 , PNM recorded impairment losses on the available-for-sale securities held in the NDT and coal mine reclamation trusts of $13.9 million , $10.4 million , and $4.8 million . No gains or losses are deferred as regulatory assets or liabilities. Unrealized gains on these investments, net of related tax effects, are included in OCI and AOCI. The available-for-sale securities are primarily comprised of international, United States, state, and municipal government obligations and corporate debt and equity securities. All investments are held in PNM’s name and are in the custody of major financial institutions. The specific identification method is used to determine the cost of securities disposed of, with realized gains and losses reflected in other income and deductions. See New Accounting Pronouncements below. Goodwill Under GAAP, the Company does not amortize goodwill. Goodwill is evaluated for impairment annually, or more frequently if events and circumstances indicate that the goodwill might be impaired. See Note 18. Asset Impairment Tangible long-lived assets are evaluated in relation to the estimated future undiscounted cash flows to assess recoverability when events and circumstances indicate that the assets might be impaired. Revenue Recognition Electric operating revenues are recorded in the period of energy delivery, which includes estimated amounts for service rendered but unbilled at the end of each accounting period. The determination of the energy sales to individual customers is based on the reading of their meters, which occurs on a systematic basis throughout the month. At the end of each month, amounts of energy delivered to customers since the date of the last meter reading and the corresponding unbilled revenue are estimated. Unbilled electric revenue is estimated based on the daily generation volumes, estimated customer usage by class, weather factors, line losses, and applicable customer rates reflecting historical trends and experience. PNM’s wholesale electricity sales are recorded as electric operating revenues and the wholesale electricity purchases are recorded as costs of energy sold. In accordance with GAAP, derivative contracts that are subject to unplanned netting are recorded net in earnings. A “book-out” is the planned or unplanned netting of off-setting purchase and sale transactions. A book-out is a transmission mechanism to reduce congestion on the transmission system or administrative burden. For accounting purposes, a book-out is the recording of net revenues upon the settlement of a derivative contract. Unrealized gains and losses on contracts that do not qualify for the normal purchases or normal sales exception or are not designated for hedge accounting are classified as economic hedges. Economic hedges are defined as derivative instruments, including long-term power and fuel supply agreements, used to hedge generation assets and purchased power costs. Changes in the fair value of economic hedges are reflected in results of operations, with changes related to economic hedges on sales included in operating revenues and changes related to economic hedges on purchases included in cost of energy sold. See New Accounting Pronouncements below. Accounts Receivable and Allowance for Uncollectible Accounts 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 calculates the allowance for uncollectible accounts based on historical experience and estimated default rates. The accounts receivable balances are reviewed monthly and adjustments to the allowance for uncollectible accounts and bad debt expense are made as necessary. Amounts that are deemed uncollectible are written off. Amortization of Debt Acquisition Costs Discount, premium, and expense related to the issuance of long-term debt are amortized over the lives of the respective issues. Gains and losses incurred upon the early retirement of long-term debt are recognized in other income or other deductions, except for amounts recoverable through NMPRC, FERC, or PUCT regulation, which are recorded as regulatory assets or liabilities and amortized over the lives of the respective issues. Unamortized debt premium, discount, and expense are reflected as part of the debt liabilities on the Consolidated Balance Sheets. Derivatives The Company records derivative instruments, including energy contracts, other than those designated as normal purchases or normal sales, in the balance sheet as either an asset or liability measured at their fair value. GAAP requires that changes in the derivatives’ fair value be recognized currently in earnings unless specific hedge accounting or normal purchase or normal sale criteria are met. Normal purchases and normal sales are not marked to market and are reflected in results of operations when the underlying transactions settle. For qualifying hedges, an entity must formally document, designate, and assess the effectiveness of transactions that receive hedge accounting. GAAP provides that the effective portion of the gain or loss on a derivative instrument designated and qualifying as a cash flow hedging instrument be reported as a component of AOCI and be reclassified into earnings in the period during which the hedged forecasted transaction affects earnings. The results of hedge ineffectiveness and the portion of the change in fair value of a derivative that an entity has chosen to exclude from hedge effectiveness are required to be presented in current earnings. See Note 6 and Note 8. The Company treats all forward commodity purchases and sales contracts subject to unplanned netting or book-out by the transmission provider as derivative instruments subject to mark-to-market accounting, unless the contract qualifies for the normal exception by meeting the definition of a capacity contract. Under this definition, the contract cannot permit net settlement, the seller must have the resources to serve the contract, and the buyer must be a load serving entity. GAAP provides guidance on whether realized gains and losses on derivative contracts not held for trading purposes should be reported on a net or gross basis and concludes such classification is a matter of judgment that depends on the relevant facts and circumstances. Decommissioning and Reclamation Costs PNM owns and leases nuclear and fossil-fuel generating facilities. In accordance with GAAP, PNM is only required to recognize and measure decommissioning liabilities for tangible long-lived assets for which a legal obligation exists. Nuclear decommissioning costs and related accruals are based on periodic site-specific estimates of the costs for removing all radioactive and other structures at PVNGS and are dependent upon numerous assumptions, including estimates of future decommissioning costs at current price levels, inflation rates, and discount rates. PNM’s accruals for PVNGS Units 1, 2, and 3, including portions held under leases, have been made based on such estimates, the guidelines of the NRC, and the extended PVNGS license periods. PVNGS Units 1 and 2 are included in PNM’s retail rates while PVNGS Unit 3 is currently excluded. See Note 15 and Note 16. See Note 17 for information concerning the treatment of nuclear decommissioning in the NMPRC’s order in PNM’s NM 2015 Rate Case and PNM’s appeal of that order. In connection with both the SJGS and Four Corners coal supply agreements, the owners are required to reimburse the mining companies for the cost of contemporaneous reclamation, as well as the costs for final reclamation of the coal mines. The reclamation costs are based on periodic site-specific studies that estimate the costs to be incurred in the future and are dependent upon numerous assumptions, including estimates of future reclamation costs at current price levels, inflation rates, and discount rates. PNM considers the contemporaneous reclamation costs part of the cost of its delivered coal costs. See Note 16 for a discussion of the final reclamation costs. Environmental Costs The normal operations of the Company involve activities and substances that expose the Company to potential liabilities under laws and regulations protecting the environment. Liabilities under these laws and regulations can be material and in some instances may be imposed without regard to fault, or may be imposed for past acts, even though the past acts may have been lawful at the time they occurred. The Company records its environmental liabilities when site assessments or remedial actions are probable and a range of reasonably likely cleanup costs can be estimated. The Company reviews its sites and measures the liability by assessing a range of reasonably likely costs for each identified site using currently available information and the probable level of involvement and financial condition of other potentially responsible parties. These estimates are based on assumptions regarding the costs for site investigations, remediation, operations and maintenance, monitoring, and site closure. The ultimate cost to clean up the Company’s identified sites may vary from its recorded liability due to numerous uncertainties inherent in the estimation process. Amounts recorded for environmental expense in the years ended December 31, 2016 , 2015 , and 2014 , as well as the amounts of environmental liabilities at December 31, 2016 and 2015 were insignificant. Pension and Other Postretirement Benefits See Note 12 for a discussion of pension and postretirement benefits expense, including a discussion of the actuarial assumptions. Stock-Based Compensation See Note 13 for a discussion of stock-based compensation expense. Income Taxes Income taxes are recognized using the asset and liability method of accounting for income taxes. Deferred tax assets and liabilities are recognized for the estimated future tax consequences attributable to differences between the financial statement carrying value of existing assets and liabilities and their respective tax basis. In accordance with GAAP, all deferred taxes are reflected as non-current on the Consolidated Balance Sheets. Current NMPRC, FERC, and PUCT approved rates include the tax effects of the majority of these differences. GAAP requires that rate-regulated enterprises record deferred income taxes for temporary differences accorded flow-through treatment at the direction of a regulatory commission. The resulting deferred tax assets and liabilities are recorded based on the expected cash flow to be reflected in future rates. Because the NMPRC, FERC, and the PUCT have consistently permitted the recovery of tax effects previously flowed-through earnings, the Company has established regulatory liabilities and assets offsetting such deferred tax assets and liabilities. The Company recognizes only the impact of tax positions that, based on their merits, are more likely than not to be sustained upon an IRS audit. The Company defers investment tax credits related to rate regulated assets and amortizes them over the estimated useful lives of those assets. See Note 11. The Company makes an estimate of its anticipated effective tax rate for the year as of the end of each quarterly period within its fiscal year. In interim periods, income tax expense is calculated by applying the anticipated annual effective tax rate to year-to-date earnings before taxes, which includes the earnings attributable to the Valencia non-controlling interest. GAAP also provides that certain unusual or infrequently occurring items, as well as adjustments due to enactment of new tax laws, be excluded from the estimated annual effective tax rate calculation. Excise Taxes The Company pays certain fees or taxes which are either considered to be an excise tax or similar to an excise tax. Substantially all of these taxes are recorded on a net basis in the Consolidated Statements of Earnings. New Accounting Pronouncements Information concerning recently issued accounting pronouncements that have not been adopted by the Company is presented below. Accounting Standards Update 2014-09 – Revenue from Contracts with Customers (Topic 606) In May 2014, the FASB issued ASU No. 2014-09. The core principle of the guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. When it becomes effective, the new standard will replace most existing revenue recognition guidance in GAAP. In August 2015, the FASB issued a one-year deferral in the effective date. Since the issuance of ASU No. 2014-09, the FASB also has issued additional ASUs that clarify implementation guidance regarding principal versus agent considerations, licensing, and identifying performance obligations, as well as adding certain additional practical expedients. The new standard can be applied retrospectively to each prior period presented or on a modified retrospective basis with a cumulative effect adjustment to retained earnings on the date of adoption. The Company has not made a final decision on the transition method, but currently anticipates using the modified retrospective method. The Company will adopt the standard on January 1, 2018, its required effective date. The Company has completed its initial assessment of its revenues for potential changes to the amounts and timing of revenue recognition under the new guidance and does not anticipate significant changes in revenue recognition associated with retail electric service rates. The Company, along with others in the utility industry, is continuing to evaluate the impacts of the new guidance on its accounting for CIAC and the presentation of revenues associated with “alternative revenue programs,” which primarily result from its approved rate rider programs. The Company is continuing to analyze the impacts this new standard and has not yet completely determined the effect of the standard on its financial reporting. Accounting Standards Update 2016-01 – Financial Instruments (Subtopic 825-10) – Recognition and Measurement of Financial Assets and Financial Liabilities In January 2016, the FASB issued ASU No. 2016-01, which makes targeted improvements to GAAP regarding financial instruments. The new standard eliminates the requirement to classify investments in equity securities with readily determinable fair values into trading or available-for-sale categories and will require those equity securities to be measured at fair value with changes in fair value recognized in net income rather than in OCI. Also, the new standard will revise certain presentation and disclosure requirements. Under the new standard, accounting for investments in debt securities remains essentially unchanged. PNM currently classifies the investments held in the NDT and coal mine reclamation trusts as available for sale securities. Unrealized losses on these securities are recorded immediately through earnings and unrealized gains are recorded in AOCI until the securities are sold. The Company will adopt the new standard on January 1, 2018, its required effective date. At that time any unrealized gains, net of income taxes, recorded in AOCI related to equity securities will be reclassified to retained earnings as a cumulative effect adjustment and, thereafter, changes in the value of equity securities will be recorded in the Consolidated Statements of Earnings. The amount of the cumulative adjustment upon adoption will depend on the amounts recorded in AOCI at that time, but PNM had unrealized gains, net of income taxes, recorded in AOCI of $3.8 million at December 31, 2016. Accounting Standards Update 2016-02 – Leases (Topic 842) In February 2016, the FASB issued ASU No. 2016-02, which will change how lessees account for leases. The ASU will require that a liability be recorded on the balance sheet for all leases based on the present value of future lease obligations. A corresponding right-of-use asset will also be recorded. Amortization of the lease obligation and the right-of-use asset for certain leases, primarily those classified as operating leases, will be on a straight-line basis, which is not expected to have a significant impact on the statements of earnings or cash flows, whereas other leases will be required to be accounted for as financing arrangements similar to the accounting treatment for capital leases under current GAAP. Also, the new standard will revise certain disclosure requirements. Although early adoption of the standard is permitted, the Company does not currently plan to adopt this standard prior to January 1, 2019, its required effective date. At adoption of the ASU, leases will be recognized and measured as of the earliest period presented using a modified retrospective approach. The Company is in the process of analyzing the impacts of this new standard. Accounting Standards Update 2016-09 – Compensation – Stock Compensation (Topic 718) In March 2016, the FASB issued ASU No. 2016-09. The ASU simplifies several aspects of the accounting for share-based payment transactions, including income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. Currently, tax benefits resulting from deductions in excess of compensation cost on vested restricted stock and performance awards and on exercised stock options (“excess tax benefits”) are recorded to equity provided these benefits reduce taxes payable. Tax deficiencies resulting from deductions related to awards, which are below realized compensation cost upon vesting and on canceled stock options are recorded to equity. PNMR has not recorded excess tax benefits to equity since 2009 because it is in a net operating loss position for income tax purposes. PNMR will adopt this standard on January 1, 2017, its required effective date, and will record a cumulative effect adjustment to recognize excess tax benefits that have not been recorded due to the PNMR’s net operating loss. The impact of the cumulative effect adjustment will be to increase PNMR’s retained earnings and reduce accumulated deferred income tax liabilities by $8.4 million . PNMR has historically recognized cash flows from employee share withholdings as a financing activity. As a result, implementation of this standard will not result in any retrospective adjustments to the Consolidated Statements of Cash Flows. Subsequent to implementation, all excess tax benefits and deficiencies will be recorded to tax expense on the Consolidated Statements of Earnings and classified as cash flows from operating activities on the Consolidated Statements of Cash Flows. Accounting Standards Update 2016-13 – Financial Instruments – Credit Losses (Topic 326) Measurement of Credit Losses on Financial Instruments In June 2016, the FASB issued ASU No. 2016-13. The ASU changes the way entities recognize impairment of many financial assets, including accounts receivable and investments in debt securities, by requiring immediate recognition of estimated credit losses expected to occur over their remaining lives. The new standard is effective for the Company beginning on January 1, 2020. Early adoption is permitted beginning on January 1, 2019. The Company is in the process of analyzing the impacts of this new standard. Accounting Standards Update 2016-15 – Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments In August 2016, the FASB issued ASU No. 2016-15. The ASU eliminates diversity in practice in how certain cash receipts and cash payments are presented and classified in the statement of cash flows. Although early adoption is permitted, the Company does not currently plan to adopt this standard prior to January 1, 2018, its required effective date. The Company is in the process of analyzing the impacts of this new standard, but does not anticipate it will have a significant impact on the Company’s financial statements. Accounting Standards Update 2016-18 – Statement of Cash Flows (Topic 230): Restricted Cash In November 2016, the FASB issued ASU 2016-18. The ASU requires that the statements of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents during the period. Under the new standard, amounts genera

Segment Information

Segment Information	12 Months Ended
	Dec. 31, 2016
Segment Reporting [Abstract]
Segment Information	Segment Information The following segment presentation is based on the methodology that management uses for making operating decisions and assessing performance of its various business activities. A reconciliation of the segment presentation to the GAAP financial statements is provided. PNM PNM includes the retail electric utility operations of PNM that are subject to traditional rate regulation by the NMPRC. PNM provides integrated electricity services that include the generation, transmission, and distribution of electricity for retail electric customers in New Mexico. PNM also includes the generation and sale of electricity into the wholesale market, as well as providing transmission services to third parties. The sale of electricity includes the asset optimization of PNM’s jurisdictional assets as well as the capacity excluded from retail rates. FERC has jurisdiction over wholesale and transmission rates. TNMP TNMP is an electric utility providing services in Texas under the TECA. TNMP’s operations are subject to traditional rate regulation by the PUCT. TNMP provides transmission and distribution services at regulated rates to various REPs that, in turn, provide retail electric service to consumers within TNMP’s service area. 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 NM Capital are also included in Corporate and Other. 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 2016 PNM TNMP Corporate and Other Consolidated (In thousands) Electric operating revenues $ 1,035,913 $ 327,038 $ — $ 1,362,951 Cost of energy 299,714 80,882 — 380,596 Utility margin 736,199 246,156 — 982,355 Other operating expenses 414,662 93,389 (12,791 ) 495,260 Depreciation and amortization 133,447 61,126 14,537 209,110 Operating income (loss) 188,090 91,641 (1,746 ) 277,985 Interest income 10,173 — 12,120 22,293 Other income (deductions) 22,066 3,202 (1,739 ) 23,529 Interest charges (87,469 ) (29,335 ) (11,829 ) (128,633 ) Segment earnings (loss) before income taxes 132,860 65,508 (3,194 ) 195,174 Income taxes (benefit) 40,922 23,836 (1,480 ) 63,278 Segment earnings (loss) 91,938 41,672 (1,714 ) 131,896 Valencia non-controlling interest (14,519 ) — — (14,519 ) Subsidiary preferred stock dividends (528 ) — — (528 ) Segment earnings (loss) attributable to PNMR $ 76,891 $ 41,672 $ (1,714 ) $ 116,849 At December 31, 2016: Total Assets $ 4,867,546 $ 1,383,223 $ 220,311 $ 6,471,080 Goodwill $ 51,632 $ 226,665 $ — $ 278,297 2015 PNM TNMP Corporate and Other Consolidated Electric operating revenues $ 1,131,195 $ 307,887 $ — $ 1,439,082 Cost of energy 391,131 73,518 — 464,649 Utility margin 740,064 234,369 — 974,433 Other operating expenses 590,967 88,051 (14,854 ) 664,164 Depreciation and amortization 115,717 56,285 13,917 185,919 Operating income 33,380 90,033 937 124,350 Interest income 6,574 — (76 ) 6,498 Other income (deductions) 26,914 3,736 (485 ) 30,165 Interest charges (79,950 ) (27,681 ) (7,229 ) (114,860 ) Segment earnings (loss) before income taxes (13,082 ) 66,088 (6,853 ) 46,153 Income taxes (benefit) (12,758 ) 24,125 3,708 15,075 Segment earnings (loss) (324 ) 41,963 (10,561 ) 31,078 Valencia non-controlling interest (14,910 ) — — (14,910 ) Subsidiary preferred stock dividends (528 ) — — (528 ) Segment earnings (loss) attributable to PNMR $ (15,762 ) $ 41,963 $ (10,561 ) $ 15,640 At December 31, 2015: Total Assets $ 4,599,344 $ 1,297,139 $ 112,845 $ 6,009,328 Goodwill $ 51,632 $ 226,665 $ — $ 278,297 2014 PNM TNMP Corporate and Other Consolidated Electric operating revenues $ 1,147,914 $ 287,939 $ — $ 1,435,853 Cost of energy 403,626 67,930 — 471,556 Utility margin 744,288 220,009 — 964,297 Other operating expenses 422,051 84,365 (14,450 ) 491,966 Depreciation and amortization 109,524 50,056 13,054 172,634 Operating income 212,713 85,588 1,396 299,697 Interest income 8,557 — (74 ) 8,483 Other income (deductions) 12,258 2,138 (2,302 ) 12,094 Interest charges (79,442 ) (27,396 ) (12,789 ) (119,627 ) Segment earnings (loss) before income taxes 154,086 60,330 (13,769 ) 200,647 Income taxes (benefit) 52,633 22,523 (5,418 ) 69,738 Segment earnings (loss) 101,453 37,807 (8,351 ) 130,909 Valencia non-controlling interest (14,127 ) — — (14,127 ) Subsidiary preferred stock dividends (528 ) — — (528 ) Segment earnings (loss) attributable to PNMR $ 86,798 $ 37,807 $ (8,351 ) $ 116,254 At December 31, 2014: Total Assets $ 4,453,114 $ 1,229,417 $ 107,706 $ 5,790,237 Goodwill $ 51,632 $ 226,665 $ — $ 278,297 Major Customers No individual customer accounted for more than 10% of the electric operating revenues of PNMR or PNM. Three REPs accounted for more than 10% of the electric operating revenues of TNMP, as follows: Year Ended December 31, 2016 2015 2014 REP A 16 % 16 % 15 % REP B 11 % 13 % 15 % REP C 11 % 11 % 11 %

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2016
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions PNMR, PNM, and TNMP are considered related parties as defined under GAAP, 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. PNMR files a consolidated federal income tax return with its affiliated companies. A tax allocation agreement exists between PNMR and each of its affiliated companies. These agreements provide that the subsidiary company will compute its taxable income on a stand-alone basis. If the result is a net tax liability, such amount shall be paid to PNMR. If there are net operating losses and/or tax credits, the subsidiary shall receive payment for the tax savings from PNMR to the extent that PNMR is able to utilize those benefits. See Note 6 for information on intercompany borrowing arrangements. The table below summarizes the nature and amount of related party transactions of PNMR, PNM and TNMP: Year Ended December 31, 2016 2015 2014 (In thousands) Services billings: PNMR to PNM $ 94,606 $ 90,827 $ 86,871 PNMR to TNMP 28,907 28,109 28,349 PNM to TNMP 427 554 524 TNMP to PNMR 66 41 31 Income tax sharing payments: PNMR to TNMP — — — PNMR to PNM — 1,450 — TNMP to PNMR — — — Interest payments: PNM to PNMR 11 54 65 PNMR to PNM 150 110 102 TNMP to PNMR 132 276 309

Regulatory Assets and Liabiliti

Regulatory Assets and Liabilities	12 Months Ended
	Dec. 31, 2016
Regulated Operations [Abstract]
Regulatory Assets and Liabilities	Regulatory Assets and Liabilities The operations of PNM and TNMP are regulated by the NMPRC, PUCT, and FERC and the provisions of GAAP for rate-regulated enterprises are applied to its regulated operations. Regulatory assets represent probable future recovery of previously incurred costs that will be collected from customers through the ratemaking process. Regulatory liabilities represent probable future reductions in revenues associated with amounts that are to be credited to customers through the ratemaking process. Regulatory assets and liabilities reflected in the Consolidated Balance Sheets are presented below. PNM TNMP December 31, December 31, 2016 2015 2016 2015 Assets: (In thousands) Current: FPPAC $ 1,451 $ — $ — $ — Energy efficiency costs 1,991 — 413 629 Other — — — 441 3,442 — 413 1,070 Non-Current: CTC, including carrying charges — — 36,328 46,147 Coal mine reclamation costs 22,383 28,303 — — Deferred income taxes 62,918 66,990 9,932 10,244 Loss on reacquired debt 24,404 23,627 34,107 35,405 Pension and OPEB 249,286 218,743 27,661 23,356 AMS surcharge — — 14,669 1,673 AMS retirement costs — — 11,086 8,549 Other 6,422 5,247 2,027 2,380 365,413 342,910 135,810 127,754 Total regulatory assets $ 368,855 $ 342,910 $ 136,223 $ 128,824 PNM TNMP December 31, December 31, 2016 2015 2016 2015 Liabilities: (In thousands) Current: FPPAC $ — $ (11,410 ) $ — $ — Renewable energy rider (3,411 ) (2,584 ) — — Other (106 ) (1,597 ) (92 ) — (3,517 ) (15,591 ) (92 ) — Non-Current: Cost of removal (297,087 ) (284,015 ) (26,900 ) (26,859 ) Deferred income taxes (62,920 ) (77,502 ) (2,644 ) (3,283 ) PVNGS ARO (30,621 ) (33,747 ) — — Renewable energy tax benefits (22,540 ) (23,697 ) — — Nuclear spent fuel reimbursements (8,875 ) (9,214 ) — — Pension and OPEB — — (1,955 ) (1,913 ) Other (1,658 ) (6,688 ) (449 ) (495 ) (423,701 ) (434,863 ) (31,948 ) (32,550 ) Total regulatory liabilities $ (427,218 ) $ (450,454 ) $ (32,040 ) $ (32,550 ) The Company’s regulatory assets and regulatory liabilities are reflected in rates charged to customers or have been addressed in a regulatory proceeding. The Company does not receive or pay a rate of return on the following regulatory assets and regulatory liabilities (and their remaining amortization periods): coal mine reclamation costs (through 2020); deferred income taxes (over the remaining life of the taxable item, up to the remaining life of utility plant); pension and OPEB costs (through 2033); and PVNGS ARO (to be determined in a future regulatory proceeding). In addition, TNMP does not currently receive a return on substantially all of its loss on reacquired debt (through 2043). The Company is permitted, under rate regulation, to accrue and record a regulatory liability for the estimated cost of removal and salvage associated with certain of its assets through depreciation expense. Under GAAP, actuarial losses and prior service costs for pension plans are required to be recorded in AOCI; however, to the extent authorized for recovery through the regulatory process these amounts are recorded as regulatory assets or liabilities. Based on prior regulatory approvals, the amortization of these amounts will be included in the Company’s rates. Based on a current evaluation of the various factors and conditions that are expected to impact future cost recovery, the Company believes that future recovery of its regulatory assets are probable.

Stockholders' Equity

Stockholders' Equity	12 Months Ended
	Dec. 31, 2016
Stockholders' Equity Note [Abstract]
Stockholders' Equity	Stockholders’ Equity Common Stock and Equity Contributions PNMR, PNM, and TNMP did not issue any common stock during the three year period ended December 31, 2016 . PNMR funded cash equity contributions to PNM of $28.1 million and $175.0 million in 2016 and 2015 and $50.0 million to TNMP in 2016. PNMR offers shares of PNMR common stock through the PNMR Direct Plan. PNMR utilizes shares of its common stock purchased on the open market, by an independent agent, rather than issuing additional shares to satisfy subscriptions under the PNMR Direct Plan. The shares of PNMR common stock utilized in the PNMR Direct Plan are offered under a SEC shelf registration statement that expires in August 2018. Dividends on Common Stock The declaration of common dividends by PNMR is dependent upon a number of factors, including the ability of PNMR’s subsidiaries to pay dividends. PNMR’s primary sources of dividends are its operating subsidiaries. PNM declared and paid cash dividends to PNMR of $4.1 million , $94.4 million , and $30.3 million in 2016 , 2015 , and 2014 . TNMP paid cash dividends to PNMR of $31.8 million , $33.2 million , and $16.3 million in 2016 , 2015 , and 2014 . The NMPRC has placed certain restrictions on the ability of PNM to pay dividends to PNMR, including the restriction that PNM cannot pay dividends that cause its debt rating to fall below investment grade. The NMPRC provisions allow PNM to pay dividends, without prior NMPRC approval, from current earnings, which is determined on a rolling four quarter basis, or from equity contributions previously made by PNMR. The Federal Power Act also imposes certain restrictions on dividends by public utilities. The Company’s revolving credit facilities and term loans contain a covenant requiring the maintenance of debt-to-capital ratios of not more than 65% , which could limit amounts of dividends that could be paid. PNM also has other financial covenants that limit the transfer of assets, through dividends or other means, including a requirement to obtain approval of certain financial counterparties to transfer more than five percent of PNM’s assets. As of December 31, 2016 , none of the numerical tests would restrict the payment of dividends from the retained earnings of PNMR, PNM, or TNMP. In addition, the ability of PNMR to declare dividends is dependent upon the extent to which cash flows will support dividends, the availability of retained earnings, financial circumstances and performance, current and future regulatory decisions, Congressional and legislative acts, and economic conditions. Conditions imposed by the NMPRC or PUCT, future growth plans and related capital requirements, and business considerations may also affect PNMR’s ability to pay dividends. Preferred Stock PNM’s cumulative preferred shares outstanding bear dividends at 4.58% per annum. PNM preferred stock does not have a mandatory redemption requirement, but may be redeemed, at PNM’s option, at 102% of the stated value plus accrued dividends. The holders of the PNM preferred stock are entitled to payment before the holders of common stock in the event of any liquidation or dissolution or distribution of assets of PNM. In addition, PNM’s preferred stock is not entitled to a sinking fund and cannot be converted into any other class of stock of PNM. PNMR and TNMP have no preferred stock outstanding. The authorized shares of PNMR and TNMP preferred stock are 10 million shares and 1 million shares.

Financing

Financing	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Financing	Financing The Company’s financing strategy includes both short-term and long-term borrowings. The Company utilizes short-term revolving credit facilities, as well as cash flows from operations, to provide funds for both construction and operating expenditures. Depending on market and other conditions, the Company will periodically sell long-term debt or enter into term loan arrangements and use the proceeds to reduce borrowings under the revolving credit facilities. Each of the revolving credit facilities and the Company’s term loans contains one financial covenant, which requires the maintenance of debt-to-capital ratios of less than or equal to 65% , and generally include 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 short-term financing plan with the NMPRC. Financing Activities PNMR At January 1, 2014, PNMR had outstanding a one-year $100.0 million Term Loan Agreement (as amended and restated, the “PNMR Term Loan Agreement”) due in December 2014. In December 2014 and again in December 2015, PNMR entered into agreements each of which amended and restated the PNMR Term Loan Agreement and extended the maturity date for an additional year. The December 2015 amendment also increased the amount outstanding to $150.0 million . The PNMR Term Loan Agreement was repaid on December 21, 2016. On March 9, 2015, PNMR entered into a $150.0 million Term Loan Agreement (“PNMR 2015 Term Loan Agreement”) between PNMR, the lenders identified therein, and Wells Fargo Bank, National Association, as lender and administrative agent. The PNMR 2015 Term Loan Agreement bears interest at a variable rate, which was 1.55% at December 31, 2016, and must be repaid on or before March 9, 2018. In September 2015, PNMR entered into a hedging agreement whereby it effectively established a fixed interest rate of 1.927% , subject to change if there is a change in PNMR’s credit rating, for borrowings under the PNMR 2015 Term Loan Agreement for the period from January 11, 2016 through March 9, 2018. This hedge is accounted for as a cash-flow hedge and had a fair value loss of less than $0.1 million and a fair value gain of $0.1 million at December 31, 2016 and 2015, using Level 2 inputs under GAAP determined using forward LIBOR curves under the mid-market convention to discount cash flows over the remaining term of the swap agreements. At January 1, 2014, PNMR had an aggregate outstanding principal amount of $118.8 million of its 9.25% Senior Unsecured Notes, Series A, which were due on May 15, 2015. PNMR repaid all of the 9.25% Senior Unsecured Notes, Series A at the scheduled maturity, utilizing proceeds from the PNMR 2015 Term Loan Agreement and borrowings under the PNMR Revolving Credit Facility. As discussed in Note 16, NM Capital, a wholly owned subsidiary of PNMR, entered into a $125.0 million term loan agreement (the “BTMU Term Loan Agreement”) with BTMU, as lender and administrative agent, as of February 1, 2016. The BTMU Term Loan Agreement has a maturity date of February 1, 2021 and bears interest at a rate based on LIBOR plus a customary spread, which aggregated 3.64% at December 31, 2016. PNMR, as parent company of NM Capital, has guaranteed NM Capital’s obligations to BTMU. The BTMU Term Loan Agreement and the guaranty include customary covenants, including requirements for PNMR to not exceed a maximum debt-to-capital ratio of 65% , and customary events of default consistent with PNMR’s other term loan agreements. In addition, the BTMU Term Loan Agreement has a cross default provision and a change of control provision. NM Capital utilized the proceeds of the BTMU Term Loan Agreement to provide funding of $125.0 million (the “Westmoreland Loan”) to a ring-fenced, bankruptcy-remote, special-purpose entity that is a subsidiary of Westmoreland Coal Company to finance the purchase price of the stock of SJCC. The BTMU Term Loan Agreement provides that the amount outstanding thereunder must be reduced by at least $5.0 million quarterly beginning on November 1, 2016. NM Capital is also required to utilize the net proceeds of all amounts received under the Westmoreland Loan, after income taxes and fees, to make principal and interest payments on the BTMU Term Loan Agreement. The principal balance outstanding under the BTMU Term Loan Agreement was $92.2 million at December 31, 2016 and $82.8 million at February 21, 2017. Based on scheduled payments on the Westmoreland Loan, NM Capital estimates it will make principal payments of $42.0 million on the BTMU Term Loan Agreement in the twelve months ended December 31, 2017, including $9.4 million paid on February 1, 2017. On October 21, 2016, PNMR entered into letter of credit arrangements with JPMorgan Chase Bank, N.A. (the “JPM LOC Facility”) under which letters of credit aggregating $30.3 million were issued to replace letters of credit previously issued from available capacity under the PNMR Revolving Credit Facility. The letters of credit facilitate the posting of reclamation bonds, which SJCC is required to post in connection with permits relating to the operation of the San Juan mine (Note 16). On December 21, 2016, PNMR entered into two term loan agreements: (1) a $100.0 million term loan agreement (“PNMR 2016 One-Year Term Loan”) among PNMR, the lenders identified therein, and Wells Fargo Bank, National Association, as administrative agent, that matures on December 21, 2017; and (2) a $100.0 million term loan agreement (“PNMR 2016 Two-Year Term Loan”) among PNMR and JPMorgan Chase Bank, N.A., as lender and administrative agent, that matures on December 21, 2018. The proceeds of the term loans were used to repay the $150.0 million PNMR Term Loan Agreement and to reduce borrowings under the PNMR Revolving Credit Facility. The PNMR 2016 One-Year Term Loan and the PNMR 2016 Two-Year Term Loan bear interest at variable rates, which were 1.60% and 1.69% at December 31, 2016. PNM On March 5, 2014, PNM entered into a $175.0 million Term Loan Agreement (the “PNM 2014 Term Loan Agreement”) among PNM and BTMU, as lender and administrative agent. On March 5, 2014, PNM used a portion of the funds borrowed under the PNM 2014 Term Loan Agreement to repay all amounts outstanding under a $75.0 million term loan and other short-term amounts outstanding. The PNM 2014 Term Loan Agreement was repaid on August 12, 2015. On December 22, 2014, PNM entered into a $125.0 million multi-draw term loan facility (the “PNM Multi-draw Term Loan”) with JPMorgan Chase Bank, N.A., as lender and administrative agent, that had a maturity date of June 21, 2016. At December 31, 2014, outstanding borrowings under the PNM Multi-draw Term Loan were $100.0 million . PNM drew the remaining capacity of $25.0 million on May 8, 2015. The PNM Multi-draw Term Loan was repaid on May 20, 2016. At January 1, 2014, PNM had a $39.3 million series of outstanding Senior Unsecured Notes, Pollution Control Revenue Bonds, which have a final maturity of June 1, 2043. These PCRBs were subject to mandatory tender for remarketing on June 1, 2015 and were successfully remarketed on that date. The notes now bear interest at 2.40% , continue to have an outstanding amount of $39.3 million , and are subject to mandatory tender for remarketing on June 1, 2020. On August 11, 2015, PNM issued $250.0 million aggregate principal amount of its 3.850% Senior Unsecured Notes due 2025. The notes will mature on August 1, 2025. Portions of the proceeds from the offering were used to repay the existing $175.0 million PNM 2014 Term Loan Agreement and to repay outstanding borrowings under the PNM Revolving Credit Facility, the PNM New Mexico Credit Facility, and PNM’s intercompany loan from PNMR. On May 20, 2016, PNM entered into a $175.0 million term loan agreement (the “PNM 2016 Term Loan Agreement”) between PNM and JPMorgan Chase Bank, N.A., as lender and administrative agent. The PNM 2016 Term Loan Agreement bears interest at a variable rate, which was 1.36% at December 31, 2016, and has a maturity date of November 17, 2017. PNM used a portion of the proceeds of the PNM 2016 Term Loan Agreement to prepay without penalty the $125.0 million outstanding under the PNM Multi-draw Term Loan, which had a scheduled maturity of June 21, 2016. On September 27, 2016, PNM participated in the issuance and sale of an aggregate of $146.0 million of PCRBs by the City of Farmington, New Mexico. The proceeds from the sale were utilized to refund an aggregate of $146.0 million of outstanding PCRBs previously issued by the City of Farmington. The arrangements governing the PCRBs result in PNM reflecting the bonds as debt on its financial statements. The PCRBs issued consist of the 2016 Series A in the aggregate principal amount of $46.0 million and the 2016 Series B in the aggregate principal amount of $100.0 million . Both series bear interest at a rate of 1.875% for the period from September 27, 2016 through September 30, 2021, have a mandatory tender for remarketing on October 1, 2021, and a final maturity on April 1, 2033. PNM has a shelf registration statement, which will expire in May 2017, with capacity for the issuance of up to $250.0 million of senior unsecured notes. TNMP On December 9, 2013, TNMP entered into an agreement (the “TNMP 2013 Bond Purchase Agreement”), which provided that TNMP would issue $80.0 million aggregate principal amount of 4.03% first mortgage bonds, due 2024 (the “Series 2014A Bonds”) on or about June 27, 2014, subject to satisfaction of certain conditions. TNMP issued the Series 2014A Bonds on June 27, 2014. TNMP used $50.0 million of the proceeds to repay the full outstanding amount of a term loan and used the remaining $30.0 million of proceeds to reduce short-term debt. On December 17, 2015, TNMP entered into an agreement (the “TNMP 2015 Bond Purchase Agreement”), which provided that TNMP would issue $60.0 million aggregate principal amount of 3.53% first mortgage bonds, due 2026 (the “Series 2016A Bonds”) on or about February 10, 2016, subject to satisfaction of certain conditions. TNMP issued the Series 2016A Bonds on February 10, 2016 and used the proceeds to reduce short-term debt and intercompany debt. Borrowing Arrangements Between PNMR and its Subsidiaries PNMR has one-year intercompany loan agreements with its subsidiaries. Individual subsidiary loan agreements vary in amount up to $100.0 million and have either reciprocal or non-reciprocal terms. Interest charged to the subsidiaries is equivalent to interest paid by PNMR on its short-term borrowings or the money-market interest rate if PNMR does not have any short-term borrowings outstanding. As of December 31, 2016 and 2015 , TNMP had outstanding borrowings of $4.6 million and $11.8 million from PNMR. At February 21, 2017 , TNMP had borrowings of $7.4 million from PNMR. PNM had no outstanding borrowings from PNMR at December 31, 2016 or February 21, 2017. Short-term Debt Currently, the PNMR Revolving Credit Facility has a financing capacity of $300.0 million and the PNM Revolving Credit Facility has a financing capacity of $400.0 million . In November 2016, PNMR and PNM entered into agreements to extend the maturity of both facilities from October 31, 2020 to October 31, 2021. However, one lender, whose current commitment is $10.0 million under the PNMR Revolving Credit Facility and $40.0 million under the PNM Revolving Credit Facility, did not agree to extend its commitment beyond October 31, 2020. Unless one or more of the other current lenders or a new lender assumes the commitments of the non-extending lender, the financing capacities will be reduced to $290.0 million for the PNMR Revolving Credit Facility and $360.0 million for the PNM Revolving Credit Facility from November 1, 2020 through October 31, 2021. The TNMP Revolving Credit Facility is a $75.0 million revolving credit facility, which is secured by $75.0 million aggregate principal amount of TNMP first mortgage bonds and matures on September 18, 2018. On January 8, 2014, PNM entered into a $50.0 million unsecured revolving credit facility (the “PNM New Mexico Credit Facility”) by and among PNM, the lenders identified therein, U.S. Bank National Association, as administrative agent, and BOKF, NA dba Bank of Albuquerque, as Syndication Agent. The nine participating lenders are all banks that have a significant presence in New Mexico and PNM’s service territory or are headquartered in New Mexico. The PNM New Mexico Credit Facility expires on January 8, 2018 and contains covenants and conditions similar to those in the PNM Revolving Credit Facility. At December 31, 2016 , interest rates on outstanding borrowings were 1.98% for the PNMR Revolving Credit Facility, 1.82% for the PNM Revolving Credit Facility, and 1.81% for the PNM New Mexico Credit Facility. The TNMP Revolving Credit Facility had no borrowings outstanding at December 31, 2016 . Short-term debt outstanding consists of: December 31, Short-term Debt 2016 2015 (In thousands) PNM: PNM Revolving Credit Facility $ 35,000 $ — PNM New Mexico Credit Facility 26,000 — 61,000 — TNMP Revolving Credit Facility — 59,000 PNMR: PNMR Revolving Credit Facility 126,100 41,600 PNMR Term Loan Agreement — 150,000 PNMR 2016 One-Year Term Loan $ 100,000 $ 287,100 $ 250,600 In addition to the above borrowings, PNMR, PNM, and TNMP had letters of credit outstanding of $6.2 million , $2.5 million , and $0.1 million at December 31, 2016 that reduce the available capacity under their respective revolving credit facilities. In addition, PNMR had $30.3 million of letters of credit outstanding under the JPM LOC Facility. At February 21, 2017 , PNMR, PNM, and TNMP had $149.5 million , $366.2 million , and $66.9 million of availability under their respective revolving credit facilities, including reductions of availability due to outstanding letters of credit, and PNM had $25.0 million availability under the PNM New Mexico Credit Facility. Total availability at February 21, 2017 , on a consolidated basis, was $607.6 million for PNMR. At February 21, 2017 , PNMR had invested cash of $1.5 million . PNM and TNMP had no invested cash at February 21, 2017 . Long-Term Debt Information concerning long-term debt outstanding and unamortized (premiums), discounts, and debt issuance costs is as follows: December 31, 2016 December 31, 2015 Principal Unamortized Discounts, (Premiums), and Issuance Costs, net Principal Unamortized Discounts, (Premiums), and Issuance Costs, net (In thousands) PNM Debt Senior Unsecured Notes, Pollution Control Revenue Bonds: 4.875% due 2033 $ — $ — $ 146,000 $ 721 1.875% due 2033, mandatory tender at October 1, 2021 146,000 1,807 — — 6.25% due 2038 36,000 239 36,000 251 4.75% due 2040, mandatory tender at June 1, 2017 37,000 25 37,000 82 5.20% due 2040, mandatory tender at June 1, 2020 40,045 147 40,045 190 5.90% due 2040 255,000 2,131 255,000 2,222 6.25% due 2040 11,500 96 11,500 100 2.54% due 2042, mandatory tender at June 1, 2017 20,000 67 20,000 199 2.40% due 2043, mandatory tender at June 1, 2020 39,300 340 39,300 456 5.20% due 2043, mandatory tender at June 1, 2020 21,000 75 21,000 96 Senior Unsecured Notes: 7.95% due 2018 350,000 995 350,000 1,718 7.50% due 2018 100,025 197 100,025 320 5.35% due 2021 160,000 780 160,000 943 3.85% due 2025 250,000 2,574 250,000 2,874 PNM Multi-draw Term Loan due 2016 — — 125,000 21 PNM 2016 Term Loan Agreement due 2017 175,000 28 — — 1,640,870 9,501 1,590,870 10,193 Less current maturities 232,000 120 125,000 21 1,408,870 9,381 1,465,870 10,172 TNMP Debt First Mortgage Bonds: 9.50% due 2019, Series 2009A 172,302 1,857 172,302 2,682 6.95% due 2043, Series 2013A 93,198 (18,773 ) 93,198 (19,490 ) 4.03% due 2024, Series 2014A 80,000 792 80,000 897 3.53% due 2026, Series 2016A 60,000 749 — — 405,500 (15,375 ) 345,500 (15,911 ) Less current maturities — — — — 405,500 (15,375 ) 345,500 (15,911 ) PNMR Debt PNMR 2015 Term Loan Agreement due 2018 150,000 84 150,000 140 BTMU Term Loan Agreement 92,207 1,634 — — PNMR 2016 Two-Year Term Loan due 2018 100,000 21 — — 342,207 1,739 150,000 140 Less current maturities 42,025 557 — — 300,182 1,182 150,000 140 Total Consolidated PNMR Debt 2,388,577 (4,135 ) 2,086,370 (5,578 ) Less current maturities 274,025 677 125,000 21 $ 2,114,552 $ (4,812 ) $ 1,961,370 $ (5,599 ) Reflecting mandatory tender dates, long-term debt matures as follows: PNMR PNM TNMP PNMR Consolidated (In thousands) 2017 $ 42,025 $ 232,000 $ — $ 274,025 2018 257,700 450,025 — 707,725 2019 12,310 — 172,302 184,612 2020 25,900 100,345 — 126,245 2021 4,272 306,000 — 310,272 Thereafter — 552,500 233,198 785,698 Total $ 342,207 $ 1,640,870 $ 405,500 $ 2,388,577

Lease Commitments

Lease Commitments	12 Months Ended
	Dec. 31, 2016
Leases [Abstract]
Leases Commitments	Lease Commitments The Company leases office buildings, vehicles, and other equipment under operating leases. In addition, PNM leases interests in Units 1 and 2 of PVNGS and, through April 1, 2015, leased an interest in the EIP transmission line. 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, and has no significant rights-of-way that will expire within the next five years. 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. All of the Company’s leases, including the Navajo Nation rights-of-way agreement, are accounted for as operating leases. See New Accounting Pronouncements in Note 1. The PVNGS leases were entered into in 1985 and 1986 and initially were scheduled to expire on January 15, 2015 for the four Unit 1 leases and January 15, 2016 for the four Unit 2 leases. Each of the leases provided PNM with an option to purchase the leased assets at fair market value at the end of the leases, but PNM did not have a fixed price purchase option. In addition, the leases provided PNM with options to renew the leases at fixed rates set forth in each of the leases for two years beyond the termination of the original lease terms. The option periods on certain leases could be further extended for up to an additional six years (the “Maximum Option Period”) if the appraised remaining useful lives and fair value of the leased assets were greater than parameters set forth in the leases. The rental payments during the fixed renewal option periods are 50% of the amounts during the original terms of the leases. Gross annual lease payments aggregated $33.0 million for the Unit 1 leases and $23.7 million for the Unit 2 leases prior to the expiration of their original terms. For leases that are extended, the leases provide PNM with the option to purchase the leased assets at fair market value at the end of the extended lease terms. Following procedures set forth in the PVNGS leases, PNM notified each of the four lessors under the Unit 1 leases and the lessor under the one Unit 2 lease containing the Maximum Option Period provision that it would elect to renew those leases for the Maximum Option Period on the expiration date of the original leases. PNM and each of those lessors entered into amendments to each of the leases setting forth the terms and conditions that would implement the extension of the term of the leases through the agreed upon Maximum Option Period. The four Unit 1 leases now expire on January 15, 2023 and the one Unit 2 lease now expires on January 15, 2024. The annual payments during the renewal periods aggregate $16.5 million for the PVNGS Unit 1 leases and $1.6 million for the Unit 2 lease, which are included in the table of future lease payments shown below. For the three PVNGS Unit 2 leases that did not contain the Maximum Option Period provisions, PNM, following procedures set forth in the leases, notified each of the lessors that PNM would elect to purchase the assets underlying those leases on the expiration date of the original leases. PNM and the lessors under these leases entered into agreements that established the purchase price, representing the fair market value, to be paid by PNM for the assets underlying the leases on January 15, 2016. On January 15, 2016, PNM paid $78.1 million to the lessor under one lease for 31.25 MW of the entitlement from PVNGS Unit 2 and $85.2 million to the lessors under the other two leases for 32.76 MW of the entitlement from PVNGS Unit 2. See Note 17 for information concerning the NMPRC’s treatment of the purchased assets and extended leases in PNM’s NM 2015 Rate Case. Covenants in PNM’s PVNGS Units 1 and 2 lease agreements limit PNM’s ability, without consent of the owner participants in the lease transactions, (i) to enter into any merger or consolidation, or (ii) except in connection with normal dividend policy, to convey, transfer, lease or dividend more than 5% of its assets in any single transaction or series of related transactions. PNM is exposed to losses under the PVNGS lease arrangements upon the occurrence of certain events that PNM does not consider to be reasonably likely to occur. Under certain circumstances (for example, the NRC issuing specified violation orders with respect to PVNGS or the occurrence of specified nuclear events), PNM would be required to make specified payments to the owner participants, and take title to the leased interests. Exercise of renewal options under the leases required that amounts payable to the owner participants under the circumstances described above would increase to the fair market value as of the renewal date. If such an event had occurred as of December 31, 2016 , amounts due to the owner participants would be up to approximately $176.1 million on January 15, 2017 in addition to the scheduled lease payments due on January 15, 2017. In such event, PNM would record the acquired assets at the lower of their fair value or the amount paid. PNM owned 60% of the EIP and leased the other 40% , under a lease that expired on April 1, 2015. The lease provided PNM the option of purchasing the leased assets at the end of the lease for fair market value, as well as options to renew the lease. On November 1, 2012, PNM and the lessor entered into a definitive agreement for PNM to exercise the option to purchase on April 1, 2015 the leased capacity at fair market value, which the parties agreed would be $7.7 million . PNM closed on the purchase on April 1, 2015 and recorded the purchase of the assets underlying the lease at that date. PNMR leased a building that was used as part of its corporate headquarters, as well as housing certain support functions for the utility operations of PNM and TNMP. The lease expired on November 30, 2015 and provided for annual rents of $1.9 million , which are included in the operating lease expense table below. Operating lease expense, including the PVNGS and EIP leases, was: PNMR PNM TNMP (In thousands) 2016 $ 51,938 $ 47,349 $ 3,748 2015 $ 68,652 $ 63,558 $ 3,688 2014 $ 82,756 $ 76,745 $ 3,932 Future minimum operating lease payments at December 31, 2016 are shown below: PNMR PNM TNMP (In thousands) 2017 $ 27,873 $ 26,497 $ 1,104 2018 25,809 25,262 267 2019 25,059 24,958 — 2020 25,044 24,958 — 2021 24,958 24,958 — Later years 84,462 84,462 — Total minimum lease payments $ 213,205 $ 211,095 $ 1,371

Fair Value of Derivative and Ot

Fair Value of Derivative and Other Financial Instruments	12 Months Ended
	Dec. 31, 2016
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 Fair value is defined under GAAP 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 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 retail and wholesale customers. PNM is exposed to market risk for its share of PVNGS Unit 3 and the needs of its wholesale customers not covered under a FPPAC. However, as discussed below, PNM has hedging arrangements for the output of PVNGS Unit 3 through December 31, 2017, at which time PVNGS Unit 3 will be included as a jurisdictional resource to serve New Mexico retail customers. 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. Commodity Risk Marketing and procurement of energy often involve market risks associated with managing energy commodities and establishing open 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 in wholesale portfolios. PNM monitors the market risk of its commodity contracts using VaR calculations to maintain total exposure within management-prescribed limits in accordance with approved risk and credit policies. Accounting for Derivatives Under derivative accounting and related rules for energy contracts, the Company accounts for its various derivative instruments for the purchase and sale of energy based on the Company’s intent. During the years ended December 31, 2016 , 2015 , and 2014 , the Company was not hedging its exposure to the variability in future cash flows from commodity derivatives through designated cash flows hedges. The contracts recorded at fair value that do not qualify or are not designated for cash flow hedge accounting are classified as economic hedges. Economic hedges are defined as derivative instruments, including long-term power agreements, used to economically hedge generation assets, purchased power and fuel costs, and customer load requirements. Changes in the fair value of economic hedges are reflected in results of operations and are classified between operating revenues and cost of energy according to the intent of the hedge. The Company has no trading transactions. Commodity Derivatives Commodity derivative instruments that are recorded at fair value, all of which are accounted for as economic hedges, are summarized as follows: Economic Hedges December 31, 2016 2015 (In thousands) PNMR and PNM Current assets $ 5,224 $ 3,813 Deferred charges — 2,622 5,224 6,435 Current liabilities (2,339 ) (1,859 ) Net $ 2,885 $ 4,576 Included in the above table are $2.7 million of current assets at December 31, 2016 and $3.0 million of current assets and $2.6 million of deferred charges at December 31, 2015 related to contracts for the sale of energy from PVNGS Unit 3 through 2017 at market price plus a premium. 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. The Company does not offset fair value, cash collateral, and accrued payable or receivable amounts recognized for derivative instruments under master netting arrangements and the above table reflects the gross amounts of assets and liabilities. The amounts that could be offset under master netting agreements were immaterial at December 31, 2016 and 2015 . At December 31, 2016 and 2015 , PNMR and PNM had no amounts recognized for the legal right to reclaim cash collateral. However, at December 31, 2016 and 2015 , amounts posted as cash collateral under margin arrangements were $2.6 million and $2.7 million for both PNMR and PNM. At December 31, 2016 and 2015 , obligations to return cash collateral were $0.1 million and $0.1 million for both PNMR and PNM. Cash collateral amounts are included in other current assets and other current liabilities on the Consolidated Balance Sheets. PNM has a NMPRC approved hedging plan to manage fuel and purchased power costs related to customers covered by its FPPAC. The table above includes $0.2 million of current assets and $0.1 million of current liabilities at December 31, 2016 and $0.4 million of current assets and $0.2 million of current liabilities at December 31, 2015 related to this plan. The offsets to these amounts are recorded as regulatory assets and liabilities on the Consolidated Balance Sheets. The following table presents the effect of mark-to-market commodity derivative instruments on earnings, excluding income tax effects. Commodity derivatives had no impact on OCI for the periods presented. Economic Hedges Year Ended 2016 2015 2014 (In thousands) PNMR and PNM Electric operating revenues $ (53 ) $ 7,156 $ 4,491 Cost of energy (1,208 ) (293 ) 593 Total gain $ (1,261 ) $ 6,863 $ 5,084 Commodity contract volume positions are presented in MMBTU for gas related contracts and in MWh for power related contracts. The table below presents PNMR’s and PNM’s net buy (sell) volume positions: Economic Hedges MMBTU MWh PNMR and PNM December 31, 2016 254,100 (2,471,600 ) December 31, 2015 577,481 (3,405,843 ) In connection with managing its commodity risks, the Company enters into master agreements with certain counterparties. If the Company is in a net liability position under an agreement, some agreements provide that the counterparties can request collateral from the Company if the Company’s credit rating is downgraded; other agreements provide that the counterparty may request collateral to provide it with “adequate assurance” that the Company will perform; and others have no provision for collateral. The table below presents information about the Company’s contingent requirements to provide collateral under commodity contracts having an objectively determinable collateral provision that are in net liability positions and are not fully collateralized with cash. Contractual Liability represents 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. The table only reflects cash collateral that has been posted under the existing contracts and does not reflect letters of credit under the Company’s revolving credit facilities that have been issued as collateral. Net Exposure is the net contractual liability for all contracts, including those designated as normal purchases and normal sales, offset by existing cash collateral and by any offsets available under master netting agreements, including both asset and liability positions. Contingent Feature – Credit Rating Downgrade Contractual Liability Existing Cash Collateral Net Exposure (In thousands) PNMR and PNM December 31, 2016 $ — $ — $ — December 31, 2015 $ 839 $ — $ 839 Sale of Power from PVNGS Unit 3 Because PNM’s 134 MW share of Unit 3 at PVNGS is not currently included in retail rates, that unit’s power is being sold in the wholesale market. PVNGS Unit 3 will be included as a jurisdictional resource to serve New Mexico retail customers beginning on January 1, 2018. As of December 31, 2016, PNM had contracted to sell 100% of PVNGS Unit 3 output through 2017, at market price plus a premium. Through hedging arrangements that are accounted for as economic hedges, PNM has established fixed rates for substantially all of the sales through 2017, which average approximately $29 per MWh. Non-Derivative Financial Instruments The carrying amounts reflected on the Consolidated Balance Sheets approximate fair value for cash, receivables, and payables due to the short period of maturity. Available-for-sale securities are carried at fair value. Available-for-sale securities for PNMR and PNM consist of PNM assets held in the NDT for its share of decommissioning costs of PVNGS and trusts for PNM’s share of final reclamation costs related to the coal mines serving SJGS and Four Corners (Note 16). At December 31, 2016 and 2015 , the fair value of available-for-sale securities included $253.9 million and $249.1 million for the NDT and $19.1 million and $9.9 million for the mine reclamation trusts. The fair value and gross unrealized gains of investments in available-for-sale securities are presented in the following table. December 31, 2016 December 31, 2015 Unrealized Gains Fair Value Unrealized Gains Fair Value PNMR and PNM (In thousands) Cash and cash equivalents $ — $ 23,683 $ — $ 10,700 Equity securities: Domestic value 1,135 34,796 11,610 44,505 Domestic growth 3,032 47,595 11,163 61,078 International and other 2,029 27,481 1,569 27,961 Fixed income securities: U.S. Government 115 40,962 178 27,880 Municipals 585 43,789 3,672 58,576 Corporate and other 553 54,671 628 28,342 $ 7,449 $ 272,977 $ 28,820 $ 259,042 The proceeds and gross realized gains and losses on the disposition of available-for-sale securities for PNMR and PNM 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 change in realized impairment losses of $(1.2) million , $(4.3) million , and $(0.7) million for the years ended December 31, 2016 , 2015 and 2014 . Year Ended December 31, 2016 2015 2014 (In thousands) Proceeds from sales $ 522,601 $ 252,174 $ 117,989 Gross realized gains $ 46,116 $ 29,663 $ 15,162 Gross realized (losses) $ (25,430 ) $ (9,259 ) $ (3,964 ) Held-to-maturity securities are those investments in debt securities that the Company has the ability and intent to hold until maturity. At December 31, 2016, held-to-maturity securities consist of the Westmoreland Loan. The Company has no available-for-sale or held-to-maturity securities for which carrying value exceeds fair value. There are no impairments considered to be “other than temporary” that are included in AOCI and not recognized in earnings. At December 31, 2016 , the available-for-sale and held-to-maturity debt securities had the following final maturities: Fair Value Available-for-Sale Held-to-Maturity PNMR and PNM PNMR (In thousands) Within 1 year $ 4,291 $ — After 1 year through 5 years 35,884 100,893 After 5 years through 10 years 52,651 — After 10 years through 15 years 5,617 — After 15 years through 20 years 6,924 — After 20 years 34,055 — $ 139,422 $ 100,893 Fair Value Disclosures The Company determines the fair values of its derivative and other financial instruments based on the hierarchy established in GAAP, which requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. GAAP describes 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. Level 3 inputs used in determining fair values for the Company consist of internal valuation models. The Company records any transfers between fair value hierarchy levels as of the end of each calendar quarter. There were no transfers between levels during the years ended December 31, 2016 and 2015 . For available-for-sale securities, Level 2 fair values are provided by the trustee utilizing a pricing service. The pricing provider predominantly uses the market approach using bid side market value based upon a hierarchy of information for specific securities or securities with similar characteristics. 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. For investments categorized as Level 3, including the Westmoreland Loan, PVNGS lessor notes, and certain items in other investments, fair values were determined by discounted cash flow models that take into consideration discount rates that are observable for similar types of assets and liabilities. Management of the Company independently verifies the information provided by pricing services. Items recorded at fair value on the Consolidated Balance Sheets are presented below by level of the fair value hierarchy. There were no Level 3 fair value measurements at December 31, 2016 and 2015 for items recorded at fair value. GAAP Fair Value Hierarchy Total Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs PNMR and PNM (In thousands) December 31, 2016 Available-for-sale securities Cash and cash equivalents $ 23,683 $ 23,683 $ — Equity securities: Domestic value 34,796 34,796 — Domestic growth 47,595 47,595 — International and other 27,481 27,481 — Fixed income securities: U.S. Government 40,962 39,723 1,239 Municipals 43,789 — 43,789 Corporate and other 54,671 23,158 31,513 $ 272,977 $ 196,436 $ 76,541 Commodity derivative assets $ 5,224 $ — $ 5,224 Commodity derivative liabilities (2,339 ) — (2,339 ) Net $ 2,885 $ — $ 2,885 December 31, 2015 Available-for-sale securities Cash and cash equivalents $ 10,700 $ 10,700 $ — Equity securities: Domestic value 44,505 44,505 — Domestic growth 61,078 61,078 — International and other 27,961 27,961 — Fixed income securities: U.S. Government 27,880 26,608 1,272 Municipals 58,576 — 58,576 Corporate and other 28,342 6,500 21,842 $ 259,042 $ 177,352 $ 81,690 Commodity derivative assets $ 6,435 $ — $ 6,435 Commodity derivative liabilities (1,859 ) — (1,859 ) Net $ 4,576 $ — $ 4,576 The carrying amounts and fair values of investments in the Westmoreland Loan, PVNGS lessor notes, other investments, and long-term debt, which are not recorded at fair value on the Consolidated Balance Sheets, are presented below: GAAP Fair Value Hierarchy Carrying Amount Fair Value Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) December 31, 2016 (In thousands) PNMR Long-term debt $ 2,392,712 $ 2,540,693 $ — $ 2,540,693 $ — Westmoreland Loan $ 95,000 $ 100,893 $ — $ — $ 100,893 Other investments $ 547 $ 1,164 $ 547 $ — $ 617 PNM Long-term debt $ 1,631,369 $ 1,730,157 $ — $ 1,730,157 $ — Other investments $ 316 $ 316 $ 316 $ — $ — TNMP Long-term debt $ 420,875 $ 468,329 $ — $ 468,329 $ — Other investments $ 231 $ 231 $ 231 $ — $ — December 31, 2015 PNMR Long-term debt $ 2,091,948 $ 2,264,869 $ — $ 2,264,869 $ — Investment in PVNGS lessor notes $ 8,587 $ 8,947 $ — $ — $ 8,947 Other investments $ 604 $ 1,269 $ 604 $ — $ 665 PNM Long-term debt $ 1,580,677 $ 1,703,209 $ — $ 1,703,209 $ — Investment in PVNGS lessor notes $ 8,587 $ 8,947 $ — $ — $ 8,947 Other investments $ 366 $ 366 $ 366 $ — $ — TNMP Long-term debt $ 361,411 $ 411,661 $ — $ 411,661 $ — Other investments $ 238 $ 238 $ 238 $ — $ — Investments Held by Employee Benefit Plans As discussed in Note 12, PNM and TNMP have trusts that hold investment assets for their pension and other postretirement benefit plans. The fair value of the assets held by the trusts impacts the determination of the funded status of each plan (Note 12), but the assets are not reflected on the Company’s Consolidated Balance Sheets. Both the PNM Pension Plan and the TNMP Pension Plan hold units of participation in the PNM Resources, Inc. Master Trust (the “PNMR Master Trust”), which was established for the investment of assets of the pension plans. GAAP provides a practical expedient that allows the net asset value per share to be used as fair value for investments in certain entities that do not have readily determinable fair values and are considered to be investment companies. Fair values for alternative investments held by the PNMR Master Trust are valued using this practical expedient. Under GAAP, investments for which fair value is measured using that practical expedient are not required to be categorized within the fair value hierarchy. Level 2 and Level 3 fair values are provided by fund managers utilizing a pricing service. For level 2 fair values, the pricing provider predominately uses the market approach using bid side market value based upon a hierarchy of information for specific securities or securities with similar characteristics. Fair values of Level 2 investments in mutual funds are equal to net asset value as of year-end. Level 3 investments are comprised of corporate term loans. Alternative investments include private equity funds, hedge funds, and real estate funds. The private equity funds are not voluntarily redeemable. These investments are realized through periodic distributions occurring over a 10 to 15 year term after the initial investment. The real estate funds and hedge funds may be voluntarily redeemed, but are subject to redemption provisions that may result in the funds not being able to be redeemed in the near term. Audited financial statements are received for each fund and are reviewed by the Company annually. The valuation of Level 3 investments and alternative investments requires significant judgment by the pricing provider due to the absence of quoted market values, changes in market conditions, and the long-term nature of the assets. The significant unobservable inputs include the trading multiples of public companies that are considered comparable to the company being valued, company specific issues, estimates of liquidation value, current operating performance and future expectations of performance, changes in market outlook and the financing environment, capitalization rates, discount rates, and cash flows. The fair values of investments held by the employee benefit plans are as follows: GAAP Fair Value Hierarchy Total Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) December 31, 2016 (In thousands) PNM Pension Plan Participation in PNMR Master Trust Investments: Investments categorized within fair value hierarchy $ 467,965 $ 129,624 $ 337,989 $ 352 Uncategorized investments 75,685 Total Master Trust Investments $ 543,650 TNMP Pension Plan Participation in PNMR Master Trust Investments: Investments categorized within fair value hierarchy $ 50,901 $ 14,447 $ 36,416 $ 38 Uncategorized investments 9,729 Total Master Trust Investments $ 60,630 PNM OPEB Plan Cash and cash equivalents $ 2,567 $ 2,567 $ — $ — Equity securities: International funds 9,300 — 9,300 — Domestic value 10,260 10,260 — — Domestic growth 6,338 6,338 — — Other funds 26,405 — 26,405 — Fixed income securities: Mutual funds 18,959 18,959 — — $ 73,829 $ 38,124 $ 35,705 $ — TNMP OPEB Plan Cash and cash equivalents $ 308 $ 308 $ — $ — Equity securities: International funds 1,279 — 1,279 — Domestic value 449 449 — — Domestic growth 1,089 1,089 — — Other funds 3,060 — 3,060 — Fixed income securities: Mutual funds 2,593 2,593 — — $ 8,778 $ 4,439 $ 4,339 $ — GAAP Fair Value Hierarchy Total Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) December 31, 2015 (In thousands) PNM Pension Plan Participation in PNMR Master Trust Investments: Investments categorized within fair value hierarchy $ 479,858 $ 111,441 $ 367,698 $ 719 Uncategorized investments 78,461 Total Master Trust Investments $ 558,319 TNMP Pension Plan Participation in PNMR Master Trust Investments: Investments categorized within fair value hierarchy $ 52,163 $ 12,199 $ 39,886 $ 78 Uncategorized investments 9,968 Total Master Trust Investments $ 62,131 PNM OPEB Plan Cash and cash equivalents $ 1,512 $ 1,512 $ — $ — Equity securities: International funds 10,604 — 10,604 — Domestic value 9,367 9,367 — — Domestic growth 5,894 5,894 — — Other funds 28,419 — 28,419 — Fixed income securities: Mutual funds 18,343 18,343 — — $ 74,139 $ 35,116 $ 39,023 $ — TNMP OPEB Plan Cash and cash equivalents $ 128 $ 128 $ — $ — Equity securities: International funds 1,310 — 1,310 — Domestic value 367 367 — — Domestic growth 1,013 1,013 — — Other funds 3,397 — 3,397 — Fixed income securities: Mutual funds 3,075 3,075 — — $ 9,290 $ 4,583 $ 4,707 $ — The fair values of investments in the PNMR Master Trust are as follows: GAAP Fair Value Hierarchy Total Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) December 31, 2016 (In thousands) PNMR Master Trust Cash and cash equivalents $ 20,503 $ 20,503 $ — $ — Equity securities: International 38,401 — 38,401 — Domestic value 36,036 36,036 — — Domestic growth 18,484 18,484 — — Other funds 27,532 — 27,532 — Fixed income securities: Corporate 205,419 — 205,029 390 U.S. Government 94,359 69,048 25,311 — Municipals 13,970 — 13,970 — Other funds 64,162 — 64,162 — Total investments categorized within fair value hierarchy 518,866 $ 144,071 $ 374,405 $ 390 Uncategorized investments: Private equity funds 27,060 Hedge funds 42,070 Real estate funds 16,284 $ 604,280 December 31, 2015 PNMR Master Trust Cash and cash equivalents $ 14,525 $ 14,525 $ — $ — Equity securities: International 36,675 — 36,675 — Domestic value 34,769 34,769 — — Domestic growth 25,407 25,407 — — Other funds 30,531 — 30,531 — Fixed income securities: Corporate 214,218 — 213,421 797 U.S. Government 98,138 48,936 49,202 — Municipals 16,647 — 16,647 — Other funds 61,111 3 61,108 — Total investments categorized within fair value hierarchy 532,021 $ 123,640 $ 407,584 $ 797 Uncategorized investments: Private equity funds 32,333 Hedge funds 40,731 Real estate funds 15,365 $ 620,450 A reconciliation of the changes in Level 3 fair value measurements is as follows: Fixed Income - Corporate PNMR Master Trust PNM Pension TNMP Pension Total Master Trust (In thousands) Balance at December 31, 2014 $ 655 $ 72 $ 727 Actual return on assets sold during the period — — — Actual return on assets still held at period end (1 ) — (1 ) Purchases 177 17 194 Sales (112 ) (11 ) (123 ) Balance at December 31, 2015 719 78 797 Actual return on assets sold during the period 1 — 1 Actual return on assets still held at period end 19 2 21 Purchases — — — Sales (387 ) (42 ) (429 ) Balance at December 31, 2016 $ 352 $ 38 $ 390

Variable Interest Entities

Variable Interest Entities	12 Months Ended
	Dec. 31, 2016
Variable Interest Entities [Abstract]
Variable Interest Entities	Variable Interest Entities GAAP determines how an enterprise evaluates and accounts for its involvement with variable interest entities, focusing primarily on whether the enterprise has the power to direct the activities that most significantly impact the economic performance of a variable interest entity (“VIE”). GAAP also requires continual reassessment of the primary beneficiary of a VIE. Valencia PNM has a PPA to purchase all of the electric capacity and energy from Valencia, a 158 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. The total construction cost for the facility was $90.0 million . PNM estimates that the plant will typically operate during peak periods of energy demand in summer. PNM is obligated to pay fixed operations and maintenance and capacity charges in addition to variable operation and maintenance charges under this PPA. For the years ended December 31, 2016 , 2015 , and 2014 , PNM paid $19.3 million , $19.2 million , and $19.1 million for fixed charges and $1.1 million , $1.6 million , and $1.2 million for variable charges. PNM does not have any other financial obligations related to Valencia. The assets of Valencia can only be used to satisfy obligations of Valencia and creditors of Valencia do not have any recourse against PNM’s assets. 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 under GAAP 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 the entity in its financial statements. Accordingly, the assets, liabilities, operating expenses, and cash flows of Valencia are included in the consolidated financial statements of PNM although PNM has no legal ownership interest or voting control of the variable interest entity. The assets and liabilities of Valencia set forth below are immaterial to PNM and, therefore, not shown separately on the Consolidated Balance Sheets. The owner’s equity and net income of Valencia are considered attributable to non-controlling interest. Summarized financial information for Valencia is as follows: Results of Operations Year Ended December 31, 2016 2015 2014 (In thousands) Operating revenues $ 20,371 $ 20,687 $ 20,247 Operating expenses (5,852 ) (5,777 ) (6,120 ) Earnings attributable to non-controlling interest $ 14,519 $ 14,910 $ 14,127 Financial Position December 31, 2016 2015 (In thousands) Current assets $ 2,551 $ 2,588 Net property, plant and equipment 66,947 69,784 Total assets 69,498 72,372 Current liabilities 578 965 Owners’ equity – non-controlling interest $ 68,920 $ 71,407 During the term of the PPA, PNM has the option 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 (i) 50% of book value reduced by related indebtedness or (ii) 50% of fair market value. On October 8, 2013, PNM notified the owner of Valencia that PNM may exercise the option to purchase 50% of the plant. As provided in the PPA, an appraisal process was initiated since the parties failed to reach agreement on fair market value within 60 days. Under the PPA, results of the appraisal process established the purchase price after which PNM was to determine in its sole discretion whether or not to exercise its option to purchase the 50% interest. The PPA also provides that the purchase price may be adjusted to reflect the period between the determination of the purchase price and the closing. The appraisal process determined the purchase price as of October 8, 2013 to be $85.0 million , prior to any adjustment to reflect the period through the closing date. Approval of the NMPRC and FERC would be required, which process could take up to 15 months. On May 30, 2014, after evaluating its alternatives with respect to Valencia, PNM notified the owner of Valencia that PNM intended to purchase 50% of the plant, subject to certain conditions. PNM’s conditions include: agreeing on the purchase price, adjusted to reflect the period between October 8, 2013 and the closing; approval of the NMPRC, including specified ratemaking treatment, and FERC; approval of the Board and PNM’s board of directors; receipt of other necessary approvals and consents; and other customary closing conditions. The parties engaged in periodic discussions concerning the terms of the proposed purchase, but ultimately were unable to reach agreement. Westmoreland San Juan LLC (“WSJ”) and SJCC As discussed in the subheading Coal Supply in Note 16, PNM purchases coal for SJGS from SJCC under a coal supply agreement (“CSA”). That section includes information on the purchase of SJCC by WSJ on January 31, 2016, as well as a $125.0 million loan (the “Westmoreland Loan”) from NM Capital, a subsidiary of PNMR, to WSJ, which loan provided substantially all of the funds required for the SJCC purchase, and the issuance of $30.3 million in letters of credit to facilitate the issuance of reclamation bonds required in order for SJCC to mine coal to be supplied to SJGS. The Westmoreland Loan and the letters of credit support result in PNMR being considered to have a variable interest in WSJ, including its subsidiary, SJCC, since PNMR and NM Capital could be subject to loss in the event WSJ were to default under the Westmoreland Loan and/or performance under the letter of credit support was required. Principal payments under the Westmoreland Loan began on August 1, 2016 and are required quarterly thereafter. Interest is also paid quarterly beginning on May 1, 2016. At December 31, 2016, the amount outstanding under the Westmoreland Loan was $95.0 million and is reflected on the Consolidated Balance Sheet net of unamortized fees. In addition, interest receivable of $1.3 million is included in Other receivables. The Westmoreland Loan requires that all cash flows of WSJ, in excess of normal operating expenses, capital additions, and operating reserves, be utilized for principal and interest payments under the loan until it is fully repaid. As of February 21, 2017, the amount outstanding under the Westmoreland Loan was $85.4 million , reflecting the February 1, 2017 scheduled principal payment of $9.6 million . The Westmoreland Loan is secured by the assets of and the equity interests in SJCC. In the event of a default by WSJ, NM Capital would have the ability to take over the mining operations. In such event, NM Capital would likely engage a third-party mining company to operate SJCC so that operations of the mine are not disrupted. Since the acquisition of SJCC by WSJ for approximately $125.0 million is a recently negotiated, arms-length transaction between Westmoreland and BHP, that amount should approximate the fair value of SJCC. Therefore, if WSJ were to default, NM Capital should be able to acquire assets of approximately the value of the Westmoreland Loan without a significant loss. Furthermore, 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 SJCC performs the required reclamation of the mine site in accordance with applicable regulations and all reclamation costs are reimbursable under the CSA. Also, much of the mine reclamation activities will not be performed for many years in the future, including after the expiration of the CSA and the final maturity of the Westmoreland Loan. In addition, each of the SJGS participants has established, and funds, a trust to meet its future reclamation obligations. Both WSJ and SJCC are considered to be VIEs. PNMR’s analysis of these arrangements concluded that Westmoreland, as the parent of WSJ, has the ability to direct the SJCC mining operations, which is the factor that most significantly impacts the economic performance of WSJ and SJCC. NM Capital’s rights under the Westmoreland Loan are the typical protective rights of a lender, but do not give NM Capital any oversight over mining operations unless there is a default under the loan. Other than PNM being able to ensure that coal is supplied in adequate quantities and of sufficient quality to provide the fuel necessary to operate SJGS in a normal manner, the mining operations are solely under the control of Westmoreland and its subsidiaries, including developing mining plans, hiring of personnel, and incurring operating and maintenance expenses. Neither PNMR nor PNM has any ability to direct or influence the mining operation. Therefore, PNM’s involvement through the CSA is a protective right rather than a participating right and Westmoreland has the power to direct the activities that most significantly impact the economic performance of the SJCC. The CSA requires SJCC to deliver coal required to fuel SJGS in exchange for payment of a set price per ton, which is escalated over time for inflation. If SJCC is able to mine more efficiently than anticipated, its economic performance will be improved. Conversely, if SJCC cannot mine as efficiently as anticipated, its economic performance will be negatively impacted. Accordingly, PNMR believes Westmoreland is the primary beneficiary of WSJ and, therefore, WSJ and SJCC are not consolidated by either PNMR or PNM. The amounts outstanding under the Westmoreland Loan and the letter of credit support constitute PNMR’s maximum exposure to loss from the VIEs. PVNGS Leases PNM leased portions of its interests in Units 1 and 2 of PVNGS under leases, which initially were scheduled to expire on January 15, 2015 for the four Unit 1 leases and January 15, 2016 for the four Unit 2 leases. See Note 7 for additional information regarding the leases and actions PNM has taken with respect to its renewal and purchase options. Each of the lease agreements was with a different trust whose beneficial owners were five different institutional investors. PNM is not the legal or tax owner of the leased assets. The beneficial owners of the trusts possess all of the voting control and pecuniary interests in the trusts. At January 15, 2015, the four Unit 1 leases were extended. At January 15, 2016, one of the Unit 2 leases was extended and PNM purchased the assets underlying the other three Unit 2 leases. See Note 17 for information concerning the NMPRC’s treatment of the purchased assets and extended leases in PNM’s NM 2015 Rate Case. PNM is only obligated to make payments to the trusts for the scheduled semi-annual lease payments and has no other financial obligations or commitments to the trusts or the beneficial owners although PNM is responsible for all decommissioning obligations related to its entire interest in PVNGS both during and after termination of the leases. Creditors of the trusts have no recourse to PNM’s assets other than with respect to the contractual lease payments. PNM has no additional rights to the assets of the trusts other than the use of the leased assets. PNM has no assets or liabilities recorded on its Consolidated Balance Sheets related to the trusts other than accrued lease payments of $8.3 million and $18.4 million at December 31, 2016 and 2015 , which are included in other current liabilities on the Consolidated Balance Sheets. Prior to their exercise or expiration, the fixed rate renewal options were considered to be variable interests in the trusts and resulted in the trusts being considered variable interest entities under GAAP. Upon execution of documents establishing terms of the asset purchases or lease extensions, the fixed rate renewal options ceased to exist as did PNM’s variable interest in the trusts. PNM evaluated the PVNGS lease arrangements, including actions taken with respect to the renewal and purchase options, and concluded that it did not have the power to direct the activities that most significantly impacted the economic performance of the trusts and, therefore, was not the primary beneficiary of the trusts under GAAP. The significant factors considered in reaching this conclusion were: the periods covered by fixed price renewal options were significantly shorter than the anticipated remaining useful lives of the assets since the operating licenses for the plants were extended for 20 years through 2045 for Unit 1 and 2046 for Unit 2 ; PNM’s only financial obligation to the trusts is to make the fixed lease payments and the payments do not vary based on the output of the plants or their performance; during the lease terms, the economic performance of the trusts is substantially fixed due to the fixed lease payments; PNM is only one of several participants in PVNGS and is not the operating agent for the plants, so does not significantly influence the day-to-day operations of the plants; furthermore, the operations of the plants, including plans for their decommissioning, are highly regulated by the NRC, leaving little room for the participants to operate the plants in a manner that impacts the economic performance of the trusts; the economic performance of the trusts at the end of the lease terms is dependent upon the fair value and remaining lives of the plants at that time, which are determined by factors such as power prices, outlook for nuclear power, and the impacts of potential carbon legislation or regulation, all which are outside of PNM’s control; and while PNM had some benefit from its renewal options, the vast majority of the value at the end of the leases will accrue to the beneficial owners of the trusts, particularly given increases in the value of existing nuclear generating facilities, which have no GHG, resulting from potential carbon legislation or regulation. Rio Bravo, formerly known as Delta PNM had a 20 -year PPA expiring in 2020 covering the entire output of Delta, which was a variable interest under GAAP. PNM controlled the dispatch of the generating plant, which impacted the variable payments made under the PPA and impacted the economic performance of the entity that owned Delta. This arrangement was entered into prior to December 31, 2003 and PNM was unsuccessful in obtaining the information necessary to determine if it was the primary beneficiary of the entity that owned Delta, or to consolidate that entity if it were determined that PNM was the primary beneficiary. Accordingly, PNM was unable to make those determinations and, as provided in GAAP, accounted for this PPA as an operating lease. In December 2012, PNM entered into an agreement with the owners of Delta under which PNM would purchase the entity that owned Delta. FERC approved the purchase on February 26, 2013 and the NMPRC approved the purchase on June 26, 2013. Closing was subject to the seller remedying specified operational, NERC compliance, and environmental issues, as well as other customary closing conditions. PNM closed on the purchase on July 17, 2014 and recorded the purchase as of that date. At closing, PNM made a cash payment of $22.8 million , which reflected an adjustment for working capital compared to a targeted working capital. Delta had project financing debt, amounting to $14.6 million at closing, which was retired at closing. PNM changed the name of the facility to Rio Bravo. PNM recorded the acquisition as a business combination and reflected the requirements of the FERC Uniform System of Accounts since the purchased assets are subject to traditional rate regulation by the NMPRC and FERC. Accordingly, as of the acquisition date, PNM recorded plant in service of $58.1 million and accumulated depreciation of $23.5 million , reflecting the original cost of the facilities and the estimated economic life to PNM. PNM also recorded current assets of $3.6 million , deferred charges of $3.4 million , current liabilities of $0.3 million , and non-current regulatory liabilities of $3.4 million . PNM made fixed and variable payments to Delta under the PPA. For the period from January 1, 2014 through July 17, 2014, PNM incurred fixed capacity charges of $3.5 million and variable energy charges of $0.6 million under the PPA. PNM recovered the variable energy charges through its FPPAC. PNM began consolidating Rio Bravo at the date of the acquisition. Prior to the acquisition, consolidation of Delta would have been immaterial to the Consolidated Balance Sheets of PNMR and PNM. Since all of Delta’s revenues and expenses were attributable to its PPA arrangement with PNM, the primary impact of consolidating Delta to the Consolidated Statements of Earnings of PNMR and PNM would have been to reclassify Delta’s net earnings from operating expenses and reflect such amount as earnings attributable to a non-controlling interest, without any impact to net earnings attributable to PNMR and PNM.

Earnings and Dividends Per Shar

Earnings and Dividends Per Share	12 Months Ended
	Dec. 31, 2016
Earnings Per Share [Abstract]
Earnings and Dividends Per Share	Earnings and Dividends Per Share In accordance with GAAP, dual presentation of basic and diluted earnings per share has been presented in the Consolidated Statements of Earnings of PNMR. Information regarding the computation of earnings per share and dividends per share is as follows: Year Ended December 31, 2016 2015 2014 (In thousands, except per share amounts) Earnings Attributable to PNMR $ 116,849 $ 15,640 $ 116,254 Average Number of Common Shares: Outstanding during year 79,654 79,654 79,654 Vested awards of restricted stock 104 105 134 Average Shares – Basic 79,758 79,759 79,788 Dilutive Effect of Common Stock Equivalents: Stock options and restricted stock 374 380 491 Average Shares – Diluted 80,132 80,139 80,279 Net Earnings Per Share of Common Stock: Basic $ 1.47 $ 0.20 $ 1.46 Diluted $ 1.46 $ 0.20 $ 1.45 Dividends Declared per Common Share $ 0.9025 $ 0.8200 $ 0.7550

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes PNMR PNMR’s income taxes consist of the following components: Year Ended December 31, 2016 2015 2014 (In thousands) Current federal income tax $ — $ — $ (2,015 ) Current state income tax (527 ) (1,376 ) (728 ) Deferred federal income tax 60,892 5,488 59,814 Deferred state income tax 3,886 12,305 14,831 Amortization of accumulated investment tax credits (973 ) (1,342 ) (2,164 ) Total income taxes $ 63,278 $ 15,075 $ 69,738 PNMR’s provision for income taxes differed from the federal income tax computed at the statutory rate for each of the years shown. The differences are attributable to the following factors: Year Ended December 31, 2016 2015 2014 (In thousands) Federal income tax at statutory rates $ 68,311 $ 16,154 $ 70,226 Amortization of accumulated investment tax credits (973 ) (1,342 ) (2,164 ) Flow-through of depreciation items 1,227 1,485 1,344 Earnings attributable to non-controlling interest in Valencia (5,082 ) (5,218 ) (4,945 ) State income tax, net of federal benefit 4,537 (1,781 ) 5,723 Impairment of state net operating loss carryforwards (311 ) 5,278 3,129 Impairment of state production tax credits — 3,092 894 Allowance for equity funds used during construction (1,732 ) (3,650 ) (1,947 ) Reversal of deferred items related to BART at SJGS — 1,826 — Impairment of charitable contribution carryforward — 2,042 — Regulatory recovery of prior year impairment of state net operating loss carryforward, net of amortization (1,877 ) — — Other (822 ) (2,811 ) (2,522 ) Total income taxes $ 63,278 $ 15,075 $ 69,738 Effective tax rate 32.42 % 32.66 % 34.76 % The components of PNMR’s net accumulated deferred income tax liability were: December 31, 2016 2015 (In thousands) Deferred tax assets: Net operating loss $ 160,901 $ 161,691 Regulatory liabilities related to income taxes 64,657 80,031 Federal tax credit carryforwards 78,675 77,417 Shutdown of SJGS Units 2 and 3 53,434 53,823 Other 75,805 70,749 Total deferred tax assets 433,472 443,711 Deferred tax liabilities: Depreciation and plant related (1,102,458 ) (1,027,047 ) Investment tax credit (56,017 ) (56,589 ) Regulatory assets related to income taxes (66,378 ) (71,054 ) CTC (12,715 ) (16,151 ) Pension (57,287 ) (65,226 ) Other (79,267 ) (85,037 ) Total deferred tax liabilities (1,374,122 ) (1,321,104 ) Net accumulated deferred income tax liabilities $ (940,650 ) $ (877,393 ) The following table reconciles the change in PNMR’s net accumulated deferred income tax liability to the deferred income tax benefit included in the Consolidated Statement of Earnings: Year Ended December 31, 2016 (In thousands) Net change in deferred income tax liability per above table $ 63,257 Change in tax effects of income tax related regulatory assets and liabilities (10,621 ) Tax effect of mark-to-market adjustments 8,379 Tax effect of excess pension liability 5,071 Adjustment for uncertain income tax positions 297 Reclassification of unrecognized tax benefits (297 ) Regulatory recovery of prior year impairment of state net operating loss carryforward, net of amortization (1,877 ) Other (404 ) Deferred income taxes $ 63,805 PNM PNM’s income taxes (benefit) consist of the following components: Year Ended December 31, 2016 2015 2014 (In thousands) Current federal income tax $ (10,290 ) $ (7,934 ) $ (2,175 ) Current state income tax (1,907 ) (1,988 ) (979 ) Deferred federal income tax 49,123 (6,827 ) 45,890 Deferred state income tax 4,969 5,333 12,061 Amortization of accumulated investment tax credits (973 ) (1,342 ) (2,164 ) Total income taxes (benefit) $ 40,922 $ (12,758 ) $ 52,633 PNM’s provision for income taxes (benefit) differed from the federal income tax computed at the statutory rate for each of the years shown. The differences are attributable to the following factors: Year Ended December 31, 2016 2015 2014 (In thousands) Federal income tax (benefit) at statutory rates $ 46,501 $ (4,579 ) $ 53,930 Amortization of accumulated investment tax credits (973 ) (1,342 ) (2,164 ) Flow-through of depreciation items 1,185 1,465 1,325 Earnings attributable to non-controlling interest in Valencia (5,082 ) (5,218 ) (4,945 ) State income tax, net of federal benefit 3,921 (2,162 ) 5,522 Impairment of state net operating loss carryforwards (213 ) 3,619 2,145 Allowance for equity funds used during construction (1,457 ) (3,650 ) (1,947 ) Reversal of deferred items related to BART at SJGS — 1,826 — Reversal of deferred income taxes accrued at prior tax rates (301 ) (737 ) (737 ) Regulatory recovery of prior year impairment of state net operating loss carryforward, net of amortization (1,877 ) — — Other (782 ) (1,980 ) (496 ) Total income taxes (benefit) $ 40,922 $ (12,758 ) $ 52,633 Effective tax rate 30.80 % 97.52 % 34.16 % The components of PNM’s net accumulated deferred income tax liability were: December 31, 2016 2015 (In thousands) Deferred tax assets: Net operating loss $ 117,922 $ 116,693 Regulatory liabilities related to income taxes 60,940 75,889 Federal tax credit carryforwards 59,156 57,928 Shutdown of SJGS Units 2 and 3 53,434 53,823 Other 41,700 41,210 Total deferred tax assets 333,152 345,543 Deferred tax liabilities: Depreciation and plant related (891,578 ) (828,926 ) Investment tax credit (56,017 ) (56,589 ) Regulatory assets related to income taxes (56,577 ) (61,018 ) Pension (50,134 ) (58,070 ) Other (27,512 ) (37,324 ) Total deferred tax liabilities (1,081,818 ) (1,041,927 ) Net accumulated deferred income tax liabilities $ (748,666 ) $ (696,384 ) The following table reconciles the change in PNM’s net accumulated deferred income tax liability to the deferred income tax benefit included in the Consolidated Statement of Earnings: Year Ended December 31, 2016 (In thousands) Net change in deferred income tax liability per above table $ 52,282 Change in tax effects of income tax related regulatory assets and liabilities (10,510 ) Tax effect of mark-to-market adjustments 8,336 Tax effect of excess pension liability 5,071 Adjustment for uncertain income tax positions 297 Reclassification of unrecognized tax benefits (297 ) Regulatory recovery of prior year impairment of state net operating loss carryforward, net of amortization (1,877 ) Other (183 ) Deferred income taxes $ 53,119 TNMP TNMP’s income taxes consist of the following components: Year Ended December 31, 2016 2015 2014 (In thousands) Current federal income tax $ 9,445 $ 1,603 $ 35 Current state income tax 1,729 1,639 1,939 Deferred federal income tax 12,690 20,904 20,577 Deferred state income tax (28 ) (21 ) (28 ) Total income taxes $ 23,836 $ 24,125 $ 22,523 TNMP’s provision for income taxes differed from the federal income tax computed at the statutory rate for each of the periods shown. The differences are attributable to the following factors: Year Ended December 31, 2016 2015 2014 (In thousands) Federal income tax at statutory rates $ 22,928 $ 23,131 $ 21,115 State income tax, net of federal benefit 1,132 1,065 1,257 Other (224 ) (71 ) 151 Total income taxes $ 23,836 $ 24,125 $ 22,523 Effective tax rate 36.39 % 36.50 % 37.33 % The components of TNMP’s net accumulated deferred income tax liability at December 31, were: December 31, 2016 2015 (In thousands) Deferred tax assets: Regulatory liabilities related to income taxes $ 3,718 $ 4,141 Other 6,016 6,702 Total deferred tax assets 9,734 10,843 Deferred tax liabilities: Depreciation and plant related (201,017 ) (189,322 ) CTC (12,715 ) (16,151 ) Regulatory assets related to income taxes (9,800 ) (10,036 ) Loss on reacquired debt (11,937 ) (12,392 ) Other (20,050 ) (15,733 ) Total deferred tax liabilities (255,519 ) (243,634 ) Net accumulated deferred income tax liabilities $ (245,785 ) $ (232,791 ) The following table reconciles the change in TNMP’s net accumulated deferred income tax liability to the deferred income tax benefit included in the Consolidated Statement of Earnings: Year Ended December 31, 2016 (In thousands) Net change in deferred income tax liability per above table $ 12,994 Change in tax effects of income tax related regulatory assets and liabilities (111 ) Other (221 ) Deferred income taxes $ 12,662 Other Disclosures GAAP requires that the Company recognize only the impact of tax positions that, based on their technical merits, are more likely than not to be sustained upon an audit by the taxing authority. A reconciliation of unrecognized tax benefits (expenses) is as follows: PNMR PNM TNMP (In thousands) Balance at December 31, 2013 $ 19,889 $ 11,073 $ 6,796 Additions based on tax positions related to 2014 623 623 — Additions (reductions) for tax positions of prior years (5,481 ) 532 (6,796 ) Settlement payments — — — Balance at December 31, 2014 15,031 12,228 — Additions based on tax positions related to 2015 1,214 1,214 — Additions (reductions) for tax positions of prior years (9,790 ) (9,790 ) — Settlement payments — — — Balance at December 31, 2015 6,455 3,652 — Additions based on tax positions related to 2016 242 242 — Additions (reductions) for tax positions of prior years 55 55 — Settlement payments — — — Balance at December 31, 2016 $ 6,752 $ 3,949 $ — Included in the balance of unrecognized tax benefits at December 31, 2016 are $6.2 million and $3.4 million that, if recognized, would affect the effective tax rate for PNMR and PNM. The Company does not anticipate that any unrecognized tax expenses or unrecognized tax benefits will be reduced or settled in 2017 . In 2016, the Company undertook an analysis of interest income and interest expense applicable to federal income tax matters. The analysis encompassed the impacts of IRS examinations, amended income tax returns, and filings for carrybacks of tax matters to previous taxable years applicable to all years not closed under the IRS rules. As a result of this effort, PNMR received net refunds from the IRS of $6.5 million . Of the refunds, $2.1 million was recorded as a reduction of the net interest receivable and $5.1 million was recorded as interest income, which was partially offset by $0.7 million of interest expense. In addition, PNMR incurred $0.9 million in professional fees related to the analysis. Of the net pre-tax impacts aggregating $3.5 million , $2.6 million is reflected in the PNM segment, $0.3 million in the TNMP segment, and $0.6 million in the Corporate and Other segment. Estimated interest income related to refunds the Company expects to receive is included in Other income and estimated interest expense and penalties related to potential cash settlements are included in Interest Charges in the Consolidated Statements of Earnings. Interest income (expense) related to income taxes is as follows: PNMR PNM TNMP (In thousands) 2016 $ 4,398 $ 3,625 $ 345 2015 $ — $ — $ — 2014 $ 146 $ 148 $ (2 ) Accumulated accrued interest receivable (payable) related to income taxes is as follows: PNMR PNM TNMP (In thousands) December 31, 2016: Accumulated accrued interest receivable $ — $ — $ — Accumulated accrued interest payable $ — $ — $ — December 31, 2015: Accumulated accrued interest receivable $ 3,236 $ 3,236 $ — Accumulated accrued interest payable $ (1,120 ) $ (24 ) $ (120 ) The Company files a federal consolidated and several consolidated and separate state income tax returns. The tax years prior to 2013 are closed to examination by either federal or state taxing authorities other than Arizona. The tax years prior to 2012 are closed to examination by Arizona taxing authorities. Other tax years are open to examination by federal and state taxing authorities. At December 31, 2016 , the Company has $420.1 million of federal net operating loss carryforwards that expire beginning in 2030 and $78.7 million of federal tax credit carryforwards that expire beginning in 2023. State net operating losses expire beginning in 2017 and vary from federal due to differences between state and federal tax law. In 2013, New Mexico House Bill 641 reduced the New Mexico corporate income tax rate from 7.6% to 5.9% . The rate reduction is being phased-in from 2014 to 2018. In accordance with GAAP, PNMR and PNM adjusted accumulated deferred income taxes to reflect the tax rate at which the balances are expected to reverse during the period that includes the date of enactment, which was in the year ended December 31, 2013. At that time, the portion of the adjustment related to PNM’s regulated activities was recorded as a reduction in deferred tax liabilities, which was offset by an increase in a regulatory liability, on the assumption that PNM will be required to return the benefit to customers over time. PNM’s NM 2016 Rate Case (Note 17) reflects that assumption. In addition, the portion of the adjustment that is not related to PNM’s regulated activities was recorded in PNMR’s Corporate and Other segment as a reduction in deferred tax assets and an increase in income tax expense. Changes in the estimated timing of reversals of deferred tax assets and liabilities will result in refinements of the impacts of this change in tax rates being recorded periodically until 2018, when the rate reduction is fully phased-in. Adjustments to deferred income taxes recorded as increases (decreases) in the regulatory liability and income tax expense are as follows: PNMR PNM TNMP (In thousands) December 31, 2016: Regulatory liability $ (7,132 ) $ (7,132 ) $ — Income tax expense $ 712 $ 804 $ — December 31, 2015: Regulatory liability $ (1,903 ) $ (1,903 ) $ — Income tax expense $ (674 ) $ (470 ) $ — December 31, 2014: Regulatory liability $ (5,106 ) $ (5,106 ) $ — Income tax expense $ (71 ) $ (312 ) $ — In 2008, fifty percent bonus tax depreciation was enacted as a temporary two -year stimulus measure as part of the Economic Stimulus Act of 2008. Bonus tax depreciation in various forms has been continuously extended since that time, most recently by the Protecting Americans from Tax Hikes Act of 2015. The 2015 act extends and phases-out bonus tax depreciation through 2019. As a result of the net operating loss carryforwards for income tax purposes created by bonus depreciation, and reduced future income taxes payable resulting from New Mexico House Bill 641, certain tax carryforwards are not expected to be utilized before their expiration. In accordance with GAAP, PNMR and PNM have impaired the tax carryforwards which were not expected to be utilized prior to their expiration. The impairments, net of federal tax benefit, for 2014 through 2016 are as follows: PNMR PNM TNMP (In thousands) December 31, 2016: State tax credit carryforwards $ — $ — $ — State net operating loss carryforwards $ (311 ) $ (213 ) $ — Charitable contribution carryforwards $ — $ — $ — December 31, 2015: State tax credit carryforwards $ 3,092 $ — $ — State net operating loss carryforwards $ 5,278 $ 3,619 $ — Charitable contribution carryforwards $ 2,042 $ — $ — December 31, 2014: State tax credit carryforwards $ 894 $ — $ — State net operating loss carryforwards $ 3,129 $ 2,145 $ — The impairments of unexpired state tax credits, state net operating loss, and charitable contribution carryforwards are reflected as a valuation allowance against deferred tax assets. The reserve balances, after reflecting expiration of carryforwards under applicable tax laws, at December 31, 2016 and 2015 are as follows: PNMR PNM TNMP (In thousands) December 31, 2016: State tax credit carryforwards $ 3,986 $ — $ — State net operating loss carryforwards $ 361 $ 248 $ — Charitable contribution carryforwards $ 659 $ — $ — December 31, 2015: State tax credit carryforwards $ 6,378 $ — $ — State net operating loss carryforwards $ 361 $ 248 $ — Charitable contribution carryforwards $ 659 $ — $ — The NMPRC’s order in the NM 2015 Rate Case (Note 17) approved PNM’s request to record a regulatory asset, which net of federal income taxes, amounts to $2.1 million , to recover a 2014 impairment of PNM’s New Mexico net operating loss carryforward resulting from an extension of the income tax provision for fifty percent bonus depreciation. The regulatory asset is being recovered through rates over two years. The impact, net of amortization, is reflected as a reduction of income tax expense on the Consolidated Statement of Earnings. In 2014, the Company settled the IRS examination of income tax years 2003 and 2005 through 2008. As a result of the settlement, the Company received net federal tax refunds of $2.0 million . The IRS examination resulted in the settlement of certain issues for which the Company had previously reflected liabilities related to uncertain tax positions. The settlement of the IRS examination, including the uncertain tax position matters, resulted in PNMR recording an income tax benefit of $0.2 million on a consolidated basis in the year ended December 31, 2014. PNM recorded an income tax expense of $1.1 million , TNMP reflected no impact, and an income tax benefit of $1.3 million was recorded in PNMR’s Corporate and Other segment.

Pension and Other Postretiremen

Pension and Other Postretirement Benefits	12 Months Ended
	Dec. 31, 2016
Compensation and Retirement Disclosure [Abstract]
Pension and Other Postretirement Benefits	Pension and Other Postretirement Benefits 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. PNM receives a regulated return on the amount it has funded for its pension plan in excess of the periodic cost or income to the extent included in retail rates. Participants in the PNM Plans include eligible employees and retirees of PNMR and other subsidiaries of PNMR. Participants in the TNMP Plans include eligible employees and retirees of TNMP. The PNM pension plan was frozen at the end of 1997 with regard to new participants, salary levels, and benefits. Through December 31, 2007, additional credited service could be accrued under the PNM pension plan up to a limit determined by age and service. The TNMP pension plan was frozen at December 31, 2005 with regard to new participants, salary levels, and benefits. GAAP requires a plan sponsor to (a) recognize in its statement of financial position an asset for a plan’s overfunded status or a liability for a plan’s underfunded status; (b) measure a plan’s assets and its obligations that determine its funded status as of the end of the employer’s fiscal year; and (c) recognize changes in the funded status of a defined benefit postretirement plan in the year in which the changes occur. GAAP requires unrecognized prior service costs and unrecognized gains or losses to be recorded in AOCI and subsequently amortized. The amortization of these incurred costs is included as pension and postretirement benefit periodic cost or income in subsequent years. To the extent the amortization of these items will ultimately be recovered or returned through future rates, PNM and TNMP record the costs as a regulatory asset or regulatory liability. The Company maintains trust funds for the pension and OBEB plans from which benefits are paid to eligible employees and retirees. The Company’s funding policy is to make contributions to the trusts as determined by independent actuary and that comply with minimum guidelines of the Employee Retirement Income Security Act and the Internal Revenue Code. Information concerning the investments is contained in Note 8. The Company has in place a policy that defines the investment objectives, establishes performance goals of asset managers, and provides procedures for the manner in which investments are to be reviewed. The plans implement investment strategies to achieve the following objectives: • Maximize the return on assets, commensurate with the risk that the Corporate Investment Committee deems appropriate to meet the obligations of the pension plans and OPEB plans, minimize the volatility of expense, and account for contingencies • Transition asset mix over time to a higher proportion of high quality fixed income investments as the plans’ funded statuses improve Management is responsible for the determination of the asset target mix and the expected rate of return. The target asset allocations are determined based on consultations with external investment advisors. The expected long-term rate of return on pension and postretirement plan assets is calculated on the market-related value of assets. GAAP requires that actual gains and losses on pension and postretirement plan assets be recognized in the market-related value of assets equally over a period of not more than five years, which reduces year-to-year volatility. For the PNM Plans and TNMP Plans, the market-related value of assets is equal to the prior year’s market related value of assets adjusted for contributions, benefit payments and investment gains and losses that are within a corridor of plus or minus 4.0% around the expected return on market value. Gains and losses that are outside the corridor are amortized over five years. Pension Plans For defined benefit pension plans, including the executive retirement plans, the PBO represents the actuarial present value of all benefits attributed by the pension benefit formula to employee service rendered prior to that date using assumptions regarding future compensation levels. The ABO represents the PBO without considering future compensation levels. Since the pension plans are frozen, the PBO and ABO are equal. The following table presents information about the PBO, fair value of plan assets, and funded status of the plans: PNM Plan TNMP Plan Year Ended December 31, Year Ended December 31, 2016 2015 2016 2015 (In thousands) PBO at beginning of year $ 597,900 $ 657,557 $ 64,198 $ 72,305 Service cost — — — — Interest cost 30,307 28,255 3,304 3,043 Actuarial (gain) loss 39,463 (38,151 ) 4,318 (5,157 ) Benefits paid (45,919 ) (49,761 ) (4,759 ) (5,993 ) PBO at end of year 621,751 597,900 67,061 64,198 Fair value of plan assets at beginning of year 557,923 587,909 62,082 69,177 Actual return on plan assets 31,597 (10,225 ) 3,301 (1,102 ) Employer contributions — 30,000 — — Benefits paid (45,919 ) (49,761 ) (4,759 ) (5,993 ) Fair value of plan assets at end of year 543,601 557,923 60,624 62,082 Funded status – asset (liability) for pension benefits $ (78,150 ) $ (39,977 ) $ (6,437 ) $ (2,116 ) Actuarial (gain) loss results from changes in: PNM Plan TNMP Plan Year Ended December 31, Year Ended December 31, 2016 2015 2016 2015 (in thousands) Discount rates $ 41,849 $ (45,918 ) $ 5,055 $ (6,090 ) Demographic experience (334 ) 2,778 (556 ) 877 Other assumption and experience (2,052 ) 4,989 (181 ) 56 $ 39,463 $ (38,151 ) $ 4,318 $ (5,157 ) The following table presents pre-tax information about prior service cost and net actuarial (gain) loss in AOCI as of December 31, 2016 . PNM Plan TNMP Plan December 31, 2016 December 31, 2016 Prior service cost Net actuarial (gain) loss Net actuarial (gain) loss (In thousands) Amounts in AOCI not yet recognized in net periodic benefit cost (income) at beginning of year $ (1,855 ) $ 146,775 $ — Experience (gain) loss — 43,283 4,960 Regulatory asset (liability) adjustment — (25,104 ) (4,960 ) Amortization recognized in net periodic benefit cost (income) 405 (5,805 ) — Amounts in AOCI not yet recognized in net periodic benefit cost (income) at end of year $ (1,450 ) $ 159,149 $ — Amortization expected to be recognized in 2017 $ (405 ) $ 6,320 $ — The following table presents the components of net periodic benefit cost (income): Year Ended December 31, 2016 2015 2014 (In thousands) PNM Plan Service cost $ — $ — $ — Interest cost 30,307 28,255 30,163 Expected return on plan assets (35,416 ) (39,323 ) (38,044 ) Amortization of net (gain) loss 13,820 14,820 13,020 Amortization of prior service cost (965 ) (965 ) (965 ) Net periodic benefit cost $ 7,746 $ 2,787 $ 4,174 TNMP Plan Service cost $ — $ — $ — Interest cost 3,304 3,043 3,193 Expected return on plan assets (3,943 ) (4,420 ) (4,526 ) Amortization of net (gain) loss 700 782 665 Amortization of prior service cost — — — Net periodic benefit cost (income) $ 61 $ (595 ) $ (668 ) The following significant weighted-average assumptions were used to determine the PBO and net periodic benefit cost (income). Should actual experience differ from actuarial assumptions, the PBO and net periodic benefit cost (income) would be affected. Year Ended December 31, PNM Plan 2016 2015 2014 Discount rate for determining December 31 PBO 4.51 % 5.29 % 4.48 % Discount rate for determining net periodic benefit cost (income) 5.29 % 4.48 % 5.27 % Expected return on plan assets 6.50 % 6.80 % 7.20 % Rate of compensation increase N/A N/A N/A TNMP Plan Discount rate for determining December 31 PBO 4.49 % 5.39 % 4.39 % Discount rate for determining net periodic benefit cost (income) 5.39 % 4.39 % 5.06 % Expected return on plan assets 6.50 % 6.80 % 7.20 % Rate of compensation increase N/A N/A N/A The assumed discount rate for determining the PBO was determined based on a review of long-term high-grade bonds and management’s expectations. The expected long-term rate of return on plan assets reflects the average rate of earnings expected on the funds invested, or to be invested, to provide for the benefits included in the PBO. Factors that are considered include, but are not limited to, historic returns on plan assets, current market information on long-term returns (e.g., long-term bond rates) and current and target asset allocations between asset categories. If all other factors were to remain unchanged, a 1% decrease in the expected long-term rate of return would cause PNM’s and TNMP’s 2017 net periodic cost to increase $5.3 million and $0.6 million (analogous changes would result from a 1% increase). The actual rate of return for the PNM and TNMP pension plans was 5.9% and 5.5% for the year ended December 31, 2016 . The Company’s long-term pension investment strategy is to invest in assets whose interest rate sensitivity is correlated with the pension liability. The Company has chosen to implement this strategy known as Liability Driven Investing (“LDI”) by increasing the liability matching investments as the funded status of the pension plans improves. These liability matching investments are currently fixed income securities. The pension plans current targeted asset allocation is 21% equities, 65% fixed income, and 14% alternative investments. Equity investments are primarily in domestic securities that include large, mid, and small capitalization companies. The pension plans have a 6% targeted allocation to equities of companies domiciled primarily in developed countries outside of the United States. This category includes actively managed international and domestic equity securities that are benchmarked against a variety of style indices. Fixed income investments are primarily corporate bonds of companies from diversified industries and government securities. Alternative investments include investments in hedge funds, real estate funds, and private equity funds. The hedge funds and private equity funds are structured as multi-manager multi-strategy fund of funds to achieve a diversified position in these asset classes. The hedge funds pursue various absolute return strategies such as relative value, long-short equity, and event driven. Private equity fund strategies include mezzanine financing, buy-outs, and venture capital. The real estate investment is structured as an open-ended, commingled private real estate portfolio that invests in a diversified portfolio of assets including commercial property and multi-family housing. See Note 8 for fair value information concerning assets held by the pension plans. The following pension benefit payments are expected to be paid: PNM Plan TNMP Plan (In thousands) 2017 $ 50,244 $ 5,526 2018 48,398 5,728 2019 47,696 5,086 2020 46,879 5,042 2021 45,348 5,294 2022 – 2026 209,331 22,509 The Company does not expect to make any cash contributions to the pension plans in 2017-2021, based on current law, including recent amendments to funding requirements, and estimates of portfolio performance. These anticipations were developed using current funding assumptions with discount rates of 4.1% to 4.9% . Actual amounts to be funded in the future will be dependent on the actuarial assumptions at that time, including the appropriate discount rate. PNM and TNMP may make additional contributions at their discretion. Other Postretirement Benefit Plans For postretirement benefit plans, the APBO is the actuarial present value of all future benefits attributed under the terms of the postretirement benefit plan to employee service rendered to date. The following table presents information about the APBO, the fair value of plan assets, and the funded status of the plans: PNM Plan TNMP Plan Year Ended December 31, Year Ended December 31, 2016 2015 2016 2015 (In thousands) APBO at beginning of year $ 84,674 $ 95,175 $ 13,106 $ 14,070 Service cost 140 204 186 247 Interest cost 4,346 4,089 677 608 Participant contributions 2,690 2,439 520 320 Actuarial (gain) loss 17,877 (6,565 ) (96 ) (575 ) Benefits paid (11,734 ) (10,668 ) (1,563 ) (1,564 ) Plan design changes (3,724 ) — — — APBO at end of year 94,269 84,674 12,830 13,106 Fair value of plan assets at beginning of year 72,952 78,175 9,111 10,094 Actual return on plan assets 5,923 (617 ) 476 (82 ) Employer contributions 2,863 3,623 — 343 Participant contributions 2,690 2,439 520 320 Benefits paid (11,734 ) (10,668 ) (1,563 ) (1,564 ) Fair value of plan assets at end of year 72,694 72,952 8,544 9,111 Funded status – asset (liability) $ (21,575 ) $ (11,722 ) $ (4,286 ) $ (3,995 ) Actuarial (gain) loss results from changes in: PNM Plan TNMP Plan Year Ended December 31, Year Ended December 31, 2016 2015 2016 2015 (in thousands) Discount rates $ 6,569 $ (7,345 ) $ 1,112 $ (1,322 ) Claims, contributions, and demographic experience 19,562 780 (102 ) 747 Assumed participation rate (6,335 ) — (1,013 ) — Mortality rate (691 ) — (93 ) — Medical benefits (1,228 ) — — — $ 17,877 $ (6,565 ) $ (96 ) $ (575 ) In the year ended December 31, 2016 , actuarial losses of $17.4 million were recorded as adjustments to regulatory assets for the PNM Plan. For the TNMP Plan, actuarial gains of less than $0.1 million were recorded as adjustments to regulatory liabilities. The following table presents the components of net periodic benefit cost: Year Ended December 31, 2016 2015 2014 (In thousands) PNM Plan Service cost $ 140 $ 204 $ 181 Interest cost 4,346 4,089 4,630 Expected return on plan assets (5,483 ) (5,610 ) (5,638 ) Amortization of net (gain) loss 1,145 1,966 2,225 Amortization of prior service credit (30 ) (642 ) (1,343 ) Net periodic benefit cost $ 118 $ 7 $ 55 TNMP Plan Service cost $ 186 $ 247 $ 237 Interest cost 677 608 619 Expected return on plan assets (490 ) (520 ) (534 ) Amortization of net (gain) loss (40 ) — (122 ) Amortization of prior service cost — — 32 Net periodic benefit cost $ 333 $ 335 $ 232 The following significant weighted-average assumptions were used to determine the APBO and net periodic benefit cost. Should actual experience differ from actuarial assumptions, the APBO and net periodic benefit cost would be affected. Year Ended December 31, PNM Plan 2016 2015 2014 Discount rate for determining December 31 APBO 4.47 % 5.34 % 4.45 % Discount rate for determining net periodic benefit cost 5.34 % 4.45 % 5.21 % Expected return on plan assets 7.70 % 7.70 % 8.50 % Rate of compensation increase N/A N/A N/A TNMP Plan Discount rate for determining December 31 APBO 4.47 % 5.34 % 4.45 % Discount rate for determining net periodic benefit cost 5.34 % 4.45 % 5.21 % Expected return on plan assets 5.70 % 5.70 % 6.50 % Rate of compensation increase N/A N/A N/A The assumed discount rate for determining the APBO was determined based on a review of long-term high-grade bonds and management’s expectations. The expected long-term rate of return on plan assets reflects the average rate of earnings expected on the funds invested, or to be invested, to provide for the benefits included in the APBO. Factors that are considered include, but are not limited to, historic returns on plan assets, current market information on long-term returns (e.g., long-term bond rates), and current and target asset allocations between asset categories. If all other factors were to remain unchanged, a 1% decrease in the expected long-term rate of return would cause PNM’s and TNMP’s 2017 postretirement benefit cost to increase $0.7 million and $0.1 million (analogous changes would result from a 1% increase). The actual rate of return for the PNM and TNMP postretirement benefit plans was 8.5% and 5.5% for the year ended December 31, 2016 . The following table shows the assumed health care cost trend rates for the PNM postretirement benefit plan: PNM Plan December 31, 2016 2015 Health care cost trend rate assumed for next year 6.8 % 7.0 % Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) 5.0 % 5.0 % Year that the rate reaches the ultimate trend rate 2024 2024 The following table shows the impact of a one-percentage-point change in assumed health care cost trend rates: PNM Plan 1-Percentage- Point Increase 1-Percentage- Point Decrease (In thousands) Effect on total of service and interest cost $ 259 $ (226 ) Effect on APBO $ 1,575 $ (2,193 ) TNMP’s exposure to cost increases in the postretirement benefit plan is minimized by a provision that limits TNMP’s share of costs under the plan. Costs of the plan in excess of the limit are wholly borne by the participants. TNMP reached the cost limit at the end of 2001. As a result, a one-percentage-point change in assumed health care cost trend rates would have no effect on either the net periodic expense or the year-end APBO. The Company’s other postretirement benefit plans invest in a portfolio that is diversified by asset class and style strategies. The other postretirement benefit plans generally use the same pension fixed income and equity investment managers and utilize the same overall investment strategy as described above for the pension plans, except there is no allocation to alternative investments. The other postretirement benefit plans have a target asset allocation of 70% equities and 30% fixed income. See Note 8 for fair value information concerning assets held by the other postretirement benefit plans. The following other postretirement benefit payments, which reflect expected future service and are net of participant contributions, are expected to be paid: PNM Plan TNMP Plan (In thousands) 2017 $ 8,425 $ 803 2018 8,327 818 2019 8,092 827 2020 7,965 839 2021 7,792 859 2022 - 2026 33,891 4,466 PNM expects to make no cash contributions to the PNM postretirement benefit plan totaling for 2017-2021. TNMP expects to make contributions to the TNMP postretirement benefit plan totaling $0.4 million in 2017 and $1.4 million for 2018-2021. Executive Retirement Programs For the executive retirement programs, the following table presents information about the PBO and funded status of the plans: PNM Plan TNMP Plan Year Ended Year Ended 2016 2015 2016 2015 (In thousands) PBO at beginning of year $ 16,105 $ 17,730 $ 794 $ 878 Service cost — — — — Interest cost 812 760 40 36 Actuarial (gain) loss 768 (908 ) 47 (26 ) Benefits paid (1,473 ) (1,477 ) (94 ) (94 ) PBO at end of year – funded status 16,212 16,105 787 794 Less current liability 1,510 1,519 93 93 Non-current liability $ 14,702 $ 14,586 $ 694 $ 701 The following table presents pre-tax information about net actuarial loss in AOCI as of December 31, 2016 . December 31, 2016 PNM Plan TNMP Plan (In thousands) Amount in AOCI not yet recognized in net periodic benefit cost at beginning of year $ 2,084 $ — Experience (gain) loss 768 47 Regulatory asset (liability) adjustment (445 ) (47 ) Amortization recognized in net periodic benefit cost (income) (108 ) — Amount in AOCI not yet recognized in net periodic benefit cost at end of year $ 2,299 $ — Amortization expected to be recognized in 2017 $ 132 $ — The following table presents the components of net periodic benefit cost: Year Ended December 31, 2016 2015 2014 (In thousands) PNM Plan Service cost $ — $ — $ — Interest cost 812 760 822 Amortization of net (gain) loss 256 325 210 Amortization of prior service cost — — — Net periodic benefit cost $ 1,068 $ 1,085 $ 1,032 TNMP Plan Service cost $ — $ — $ — Interest cost 40 36 39 Amortization of net (gain) loss 2 5 — Amortization of prior service cost — — — Net periodic benefit cost $ 42 $ 41 $ 39 The following significant weighted-average assumptions were used to determine the PBO and net periodic benefit cost. Should actual experience differ from actuarial assumptions, the PBO and net periodic benefit cost would be affected. Year Ended December 31, PNM Plan 2016 2015 2014 Discount rate for determining December 31 PBO 4.51 % 5.29 % 4.48 % Discount rate for determining net periodic benefit cost 5.29 % 4.48 % 5.27 % Long-term rate of return on plan assets N/A N/A N/A Rate of compensation increase N/A N/A N/A TNMP Plan Discount rate for determining December 31 PBO 4.49 % 5.39 % 4.39 % Discount rate for determining net periodic benefit cost 5.39 % 4.39 % 5.06 % Long-term rate of return on plan assets N/A N/A N/A Rate of compensation increase N/A N/A N/A The assumed discount rate for determining the PBO was determined based on a review of long-term high-grade bonds and management’s expectations. The impacts of changes in assumptions or experience were not significant. The following executive retirement plan payments, which reflect expected future service, are expected: PNM Plan TNMP Plan (In thousands) 2017 $ 1,510 $ 93 2018 1,487 92 2019 1,459 89 2020 1,427 86 2021 1,391 83 2022 – 2026 6,228 341 Other Retirement Plans PNMR sponsors a 401(k) defined contribution plan for eligible employees, including those of its subsidiaries. PNMR’s contributions to the 401(k) plan consist of a discretionary matching contribution equal to 75% of the first 6% of eligible compensation contributed by the employee on a before-tax basis. PNMR also makes a non-matching contribution ranging from 3% to 10% of eligible compensation based on the eligible employee’s age. PNMR also provides executive deferred compensation benefits through an unfunded, non-qualified plan. The purpose of this plan is to permit certain key employees of PNMR who participate in the 401(k) defined contribution plan to defer compensation and receive credits without reference to the certain limitations on contributions. Eligible employees had been allowed to save on an after-tax basis. This plan has been amended and the after-tax provision was eliminated as of June 30, 2015. A summary of expenses for these other retirement plans is as follows: Year Ended December 31, 2016 2015 2014 (In thousands) PNMR 401(k) plan $ 17,762 $ 16,725 $ 16,703 Non-qualified plan $ 2,017 $ 1,436 $ 2,257 PNM 401(k) plan $ 13,397 $ 12,679 $ 12,745 Non-qualified plan $ 1,535 $ 1,090 $ 1,722 TNMP 401(k) plan $ 4,365 $ 4,046 $ 3,958 Non-qualified plan $ 482 $ 346 $ 535

Stock-Based Compensation

Stock-Based Compensation	12 Months Ended
	Dec. 31, 2016
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Stock-Based Compensation	Stock-Based Compensation PNMR has various stock-based compensation programs, including stock options, restricted stock, and performance shares granted under the Performance Equity Plan (“PEP”). Although certain PNM and TNMP employees participate in the PNMR plans, PNM and TNMP do not have separate employee stock-based compensation plans. In 2011, the Company changed its approach to awarding stock-based compensation. As a result, no stock options have been granted since 2010 and awards of restricted stock have increased. Certain restricted stock awards are subject to achieving performance or market targets. Other awards of restricted stock are only subject to time vesting requirements. Performance Equity Plan The PEP provides for the granting of non-qualified stock options, restricted stock rights, performance shares, performance units, and stock appreciation rights to officers, key employees, and non-employee board members. 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 in 2017 and thereafter will be one year. The total number of shares of PNMR common stock subject to all awards under the PEP, as approved by PNMR’s shareholders in May 2014, may not exceed 13.5 million shares, subject to adjustment and certain share counting rules set forth in the PEP. This current share pool is charged five shares for each share subject to restricted stock or other full value award. Re-pricing of stock options is prohibited unless specific shareholder approval is obtained. Source of Shares The source of shares for exercised stock options and vested restricted stock is shares acquired on the open market by an independent agent, rather than newly issued shares. Accounting for Stock Awards The stock-based compensation expense related to restricted stock awards without performance or market conditions to participants that are retirement eligible on the grant date is recognized immediately at the grant date and is not amortized. Compensation expense for other such awards is amortized to compensation expense over the shorter of the requisite vesting period or the period until the participant becomes retirement eligible. Compensation expense for performance-based shares is recognized ratably over the performance period and is adjusted periodically to reflect the level of achievement expected to be attained. Compensation expense related to market-based shares is recognized ratably over the measurement period, regardless of the actual level of achievement, provided the employees meet their service requirements. Total compensation expense for stock-based payment arrangements recognized by PNMR for the years ended December 31, 2016 , 2015 , and 2014 was $5.6 million , $4.9 million , and $5.9 million . Stock compensation expense of $4.2 million , $3.6 million , and $4.2 million was charged to PNM and $1.5 million , $1.3 million , and $1.7 million was charged to TNMP. At December 31, 2016 , PNMR had unrecognized compensation expense related to stock awards of $4.5 million , which are expected to be recognized over an average of 1.82 years. PNMR receives a tax deduction for certain stock option exercises during the period the options are exercised, generally for the excess of the price at which the options are sold over the exercise prices of the options, and a tax deduction for the value of restricted stock at the vesting date. See New Accounting Pronouncements in Note 1. The grant date fair value for restricted stock and stock awards with Company internal 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, which will not be received prior to vesting, applied to the total number of shares that are anticipated to vest, although the number of performance shares that ultimately vest cannot be determined until after the performance periods end. The grant date fair value of stock awards with market targets is determined using Monte Carlo simulation models, which provide grant date fair values that include an expectation of the number of shares to vest at the end of the measurement period. The following table summarizes the weighted-average assumptions used to determine the awards grant date fair value: Year Ended December 31, Restricted Shares and Performance-Based Shares 2016 2015 2014 Expected quarterly dividends per share $ 0.2200 $ 0.2000 $ 0.1850 Risk-free interest rate 0.94 % 0.92 % 0.62 % Market-Based Shares Dividend yield 2.74 % 2.87 % 2.82 % Expected volatility 20.44 % 18.73 % 25.11 % Risk-free interest rate 0.97 % 1.00 % 0.64 % The following table summarizes activity in restricted stock awards, including performance-based and market-based shares, and stock options: Restricted Stock Stock Options Shares Weighted-Average Grant Date Fair Value Shares Weighted Average Exercise Price Outstanding at December 31, 2015 245,094 $ 24.81 569,342 $ 19.35 Granted 190,276 $ 26.49 — $ — Exercised (216,340 ) $ 23.47 (253,268 ) $ 27.75 Forfeited (714 ) $ 29.54 (2,000 ) $ 12.22 Expired — — (8,200 ) $ 24.85 Outstanding at December 31, 2016 218,316 $ 27.59 305,874 $ 12.29 PNMR’s stock-based compensation program provides for performance and market targets through 2018. Included as restricted stock granted and exercised in the above table are 79,619 previously awarded shares that were earned for the 2013 through 2015 performance measurement period and ratified by the Board in February 2016 (based upon achieving market targets at “target” levels, weighted at 60% , and performance targets at “threshold” levels, weighted at 40% ). Excluded from the above table are 49,682 previously awarded shares that were earned for the 2014 through 2016 performance measurement period and ratified by the Board in February 2017 (based upon achieving market targets at “target” levels, weighted at 60% , and not meeting performance targets, weighted at 40% ), as well as maximums of 163,712 and 137,036 shares for the three -year performance periods ending in 2017 and 2018 that would be awarded if all performance and market criteria are achieved at maximum levels and all executives remain eligible. In March 2012, the Company entered into a retention award agreement with its Chairman, President, and Chief Executive Officer under which she would receive 135,000 shares of PNMR’s common stock if PNMR meets specific market targets at the end of 2016 and she remains an employee of the Company. Under the agreement, she would receive 35,000 of the total shares if PNMR achieved specific market targets at the end of 2014. The specified market target was achieved at the end of 2014 and the Board ratified her receiving the 35,000 shares in February 2015. The specified market target was achieved at the end of 2016 and the Board ratified her receiving the 100,000 shares in February 2017. The above table does not include the restricted stock shares issued in February 2017. The retention award was made under the PEP and was approved by the Board on February 28, 2012. Effective as of January 1, 2015, the Company entered into a retention award agreement with its Executive Vice President and Chief Financial Officer under which he would receive awards of restricted stock if PNMR meets specific performance targets at the end of 2016 and 2017 and he remains an employee of the Company. If PNMR achieves the specific performance target for the period from January 1, 2015 through December 31, 2016, he would receive $100,000 of PNMR common stock based on the market value per share on the grant date in early 2017. The specified market target was achieved at the end of 2016 and the Board ratified him receiving $100,000 of PNMR common stock in February 2017 based on the market value per share on the grant date in early 2017. Similarly, if PNMR achieves the specific performance target for the period from January 1, 2015 through December 31, 2017, he would receive $275,000 of PNMR common stock based on the market value per share on the grant date in early 2018. The above table does not include any restricted stock shares under this retention award agreement. The retention award was made under the PEP and was approved by the Board on December 9, 2014. In March 2015, the Company entered into an additional retention award agreement with its Chairman, President, and Chief Executive Officer under which she would receive 53,859 shares of PNMR’s common stock if PNMR meets certain performance targets at the end of 2019 and she remains an employee of the Company. Under the agreement, she would receive 17,953 of the total shares if PNMR achieves specific performance targets at the end of 2017. The above table does not include any restricted stock shares under this retention award agreement. The retention award was made under the PEP and was approved by the Board on February 26, 2015. At December 31, 2016 , the aggregate intrinsic value of stock options outstanding, all of which are exercisable, was $6.7 million with a weighted-average remaining contract life of 2.04 years. At December 31, 2016 , no outstanding stock options had an exercise price greater than the closing price of PNMR common stock on that date. The following table provides additional information concerning stock options, and restricted stock activity including performance-based and market-based shares: Year Ended December 31, Restricted Stock 2016 2015 2014 Weighted-average grant date fair value $ 26.49 $ 20.34 $ 21.27 Total fair value of restricted shares that vested (in thousands) $ 5,079 $ 6,507 $ 4,933 Stock Options Weighted-average grant date fair value of options granted $ — $ — $ — Total fair value of options that vested (in thousands) $ — $ — $ — Total intrinsic value of options exercised (in thousands) $ 1,242 $ 2,350 $ 2,473

Construction Program and Jointl

Construction Program and Jointly-Owned Electric Generating Plants	12 Months Ended
	Dec. 31, 2016
Construction Program and Jointly-Owned Electric Generating Plants [Abstract]
Construction Program and Jointly-Owned Electric Generating Plants	Construction Program and Jointly-Owned Electric Generating Plants PNM is a participant in several jointly-owned power plant projects. The primary operating or participation agreements for the joint projects expire in July 2022 for SJGS, July 2041 for Four Corners, December 2046 for Luna, and November 2047 for PVNGS. PNM’s expenditures for additions to utility plant were $445.5 million in 2016 , including expenditures on jointly-owned projects. TNMP does not participate in the ownership or operation of any generating plants, but incurred expenditures for additions to utility plant of $122.5 million during 2016 . On a consolidated basis, PNMR’s expenditures for additions to utility plant were $600.1 million in 2016 . Joint Projects Under the agreements for the jointly-owned projects, PNM has an undivided interest in each asset and liability of the project and records its pro-rata share of each item in the corresponding asset and liability account on PNM’s Consolidated Balance Sheets. Likewise, PNM records its pro-rata share of each item of operating and maintenance expenses for its jointly-owned plants within the corresponding operating expense account in its Consolidated Statements of Earnings. PNM is responsible for financing its share of the capital and operating costs of the joint projects. At December 31, 2016 , PNM’s interests and investments in jointly-owned generating facilities are: Station (Fuel Type) Plant in Service Accumulated Depreciation (1) Construction Work in Progress Composite Interest (In thousands) SJGS (Coal) (2) $ 1,082,537 $ (445,597 ) $ 4,406 46.30 % PVNGS (Nuclear) (3) $ 797,793 $ (334,887 ) $ 38,946 10.20 % Four Corners Units 4 and 5 (Coal) $ 188,026 $ (103,584 ) $ 52,869 13.00 % Luna (Gas) $ 69,678 $ (25,386 ) $ 259 33.33 % (1) Includes cost of removal. (2) As discussed in Note 16, the NMPRC has approved the shutdown of SJGS Units 2 and 3 as of December 31, 2017. At December 31, 2016, PNM’s carrying value for its current ownership share of SJGS Units 2 and 3 included plant in service of $471.8 million and accumulated depreciation and amortization (including cost of removal) of $203.9 million for a net undepreciated net book value of $267.9 million , which amounts are included in the table above. At December 31, 2015, PNM recorded a regulatory disallowance of $127.6 million representing its estimate of the portion of the December 31, 2017 net book value of SJGS Units 2 and 3 that will not be recovered from ratepayers, which is reflected as a reduction of plant in service on the Consolidated Balance Sheets. (3) Includes interest in PVNGS Unit 3 , interest in common facilities for all PVNGS units, and owned interests in PVNGS Units 1 and 2 . San Juan Generating Station PNM operates and jointly owns SJGS. Currently, SJGS Units 1 and 2 are owned on a 50% shared basis with Tucson; SJGS Unit 3 is owned 50% by PNM, 41.8% by SCPPA, and 8.2% by Tri-State; and SJGS Unit 4 is owned 38.457% by PNM, 28.8% by MSR, 10.04% by Anaheim, 8.475% by Farmington, 7.2% by Los Alamos, and 7.028% by UAMPS. See Note 16 for additional information about SJGS, including the agreement for restructuring of SJGS ownership. Under the restructuring agreement, PNM would own 64.5% of Unit 4, PNMR Development would own 12.8% of Unit 4, and SCPPA, Tri-State, MSR, and Anaheim would no longer have any ownership interest in SJGS following the December 31, 2017 restructuring. PNMR anticipates that the interest of PNMR Development will be transferred to PNM, as authorized by the NMPRC, prior to the December 31, 2017 restructuring date. Palo Verde Nuclear Generating Station PNM is a participant in the three units of PVNGS, also known as the Arizona Nuclear Power Project, with APS (the operating agent), SRP, EPE, SCE, SCPPA, and The Department of Water and Power of the City of Los Angeles. PNM has a 10.2% undivided interest in PVNGS, with portions of its interests in Units 1 and 2 held under leases. See Note 7 for additional information concerning the PVNGS leases, including PNM’s purchase of the assets underlying certain of the leases at the expiration of the leases on January 15, 2016, and Note 17 for the NMPRC’s treatment of those purchases in the ratemaking process. Operation of each of the three PVNGS units requires an operating license from the NRC. The NRC issued full power operating licenses for Unit 1 in June 1985, Unit 2 in April 1986, and Unit 3 in November 1987. The full power operating licenses were originally for a period of 40 years and authorize APS, as operating agent for PVNGS, to operate the three PVNGS units. In April 2011, the NRC approved extensions in the operating licenses for the plants for 20 years through June 2045 for Unit 1, April 2046 for Unit 2, and November 2047 for Unit 3. In April 2010, APS entered into a Municipal Effluent Purchase and Sale Agreement that provides effluent water rights necessary for cooling purposes at PVNGS through 2050. Four Corners Power Plant PNM is a participant in two units of Four Corners with APS (the operating agent), an affiliate of APS, SRP, and Tucson. PNM has a 13.0% undivided interest in Units 4 and 5 of Four Corners. The Four Corners plant site is leased from the Navajo Nation and is also subject to an easement from the federal government. APS, on behalf of the Four Corners participants, negotiated amendments to an existing facility lease with the Navajo Nation, which extends the Four Corners leasehold interest from 2016 to 2041. See Note 16 for additional information about Four Corners. Luna Energy Facility Luna is a combined-cycle power plant near Deming, New Mexico. Luna is owned equally by PNM, Tucson, and Samchully Power & Utilities 1, LLC. The operation and maintenance of the facility has been contracted to North American Energy Services. Construction Program The Company anticipates making substantial capital expenditures for the construction and acquisition of utility plant and other property and equipment. An unaudited summary of the budgeted construction expenditures, including expenditures for jointly-owned projects, and nuclear fuel, is as follows: 2017 2018 2019 2020 2021 Total (In millions) PNM $ 308.1 $ 231.0 $ 282.2 $ 252.5 $ 190.7 $ 1,264.5 TNMP 151.0 134.3 137.1 136.2 126.2 684.8 Corporate and Other 58.2 29.7 15.3 15.2 15.4 133.8 Total PNMR $ 517.3 $ 395.0 $ 434.6 $ 403.9 $ 332.3 $ 2,083.1 The construction expenditure estimates are under continuing review and subject to ongoing adjustment, as well as to Board review and approval. The above construction expenditures include $44.2 million for environmental upgrades at Four Corners, $46.9 million for 30 MW of new solar capacity to supply power to a new data center being constructed by Facebook Inc., and $43.7 million for a 40 MW gas-fired peaking generating facility to be completed in 2020.

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2016
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations AROs are recorded based on studies to estimate the amount and timing of future ARO expenditures and refect underlying assumptions, such as discount rates, estimates of the future costs for decommissioning, and the timing of the removal activities to be performed. Any changes in these assumptions underlying the required calculations may require revisions to the estimated AROs when identified. A reconciliation of the ARO liability is as follows: PNMR PNM TNMP (In thousands) Liability at December 31, 2013 $ 96,135 $ 95,225 $ 782 Liabilities incurred — — — Liabilities settled — — — Accretion expense 7,984 7,906 66 Revisions to estimated cash flows 51 51 — Liability at December 31, 2014 104,170 103,182 848 Liabilities incurred — — — Liabilities settled (730 ) (506 ) (224 ) Accretion expense 8,625 8,543 71 Revisions to estimated cash flows (1) (170 ) (170 ) — Liability at December 31, 2015 111,895 111,049 695 Liabilities incurred — — — Liabilities settled (14 ) (14 ) — Accretion expense 9,170 9,098 59 Revisions to estimated cash flows (2) 6,468 6,468 — Liability at December 31, 2016 $ 127,519 $ 126,601 $ 754 (1) PNM has an ARO for Four Corners that includes the obligations for decommissioning of that facility. In 2015, a new decommissioning study for Four Corners was implemented reflecting updated cash flow estimates. The new study resulted in an increase of $1.0 million to the ARO. In addition, a new decommissioning study for SJGS was implemented in 2015, resulting in a $1.2 million decrease to the ARO. (2) PNM has an ARO for PVNGS that includes obligations for nuclear decommissioning of that facility. In 2016, a new decommissioning study for PVNGS was implemented reflecting updated cash flow estimates. The new study resulted in an increase of $6.1 million to the ARO. In addition, an adjustment for SJGS related to the 2015 decommissioning study was implemented in 2016, resulting in a $0.3 million increase to the ARO.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Overview There are various claims and lawsuits pending against the Company. The Company also 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 (Note 17) proceedings in the normal course of its business. 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. Nevertheless, 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. In accordance with GAAP, the Company records liabilities for matters where it is probable a loss has been incurred and the amount of loss is reasonably estimable. The actual outcomes of the items listed below could ultimately differ from the judgments made and the differences could be material. The Company cannot make any assurances that the amount of reserves or potential insurance coverage will be sufficient to cover the cash obligations that might be incurred as a result of litigation or regulatory proceedings. Except as otherwise disclosed, the Company does not expect that any known lawsuits, environmental costs, and commitments will have a material effect on its financial condition, results of operations, or cash flows. Commitments and Contingencies Related to the Environment PVNGS Decommissioning Funding PNM has a program for funding its share of decommissioning costs for PVNGS, including portions held under leases. The nuclear decommissioning funding program is invested in equities and fixed income instruments in qualified and non-qualified trusts. PNM funded $4.2 million , $4.9 million , and $4.9 million for the years ended December 31, 2016, 2015, and 2014 into the qualified and non-qualified trust funds. The market value of the trusts at December 31, 2016 and 2015 was $253.9 million and $249.1 million . Nuclear Spent Fuel and Waste Disposal Nuclear power plant operators are required to enter into spent fuel disposal contracts with the DOE that require the DOE to accept and dispose of all spent nuclear fuel and other high-level radioactive wastes generated by domestic power reactors. Although the Nuclear Waste Policy Act required the DOE to develop a permanent repository for the storage and disposal of spent nuclear fuel by 1998, the DOE announced that it would not be able to open the repository by 1998 and sought to excuse its performance of these requirements. In November 1997, the DC Circuit issued a decision preventing the DOE from excusing its own delay, but refused to order the DOE to begin accepting spent nuclear fuel. Based on this decision and the DOE’s delay, a number of utilities, including APS (on behalf of itself and the other PVNGS owners, including PNM), filed damages actions against the DOE in the Court of Federal Claims. The lawsuits filed by APS alleged that damages were incurred due to DOE’s continuing failure to remove spent nuclear fuel and high level waste from PVNGS. In August 2014, APS and DOE entered into a settlement agreement, which establishes a process for the payment of claims for costs incurred through December 31, 2016. Under the settlement agreement, APS must submit claims annually for payment of allowable costs. PNM’s share of settlements under this process for costs incurred from January 2007 through June 2011, which amounted to $5.9 million , was recorded in the fourth quarter of 2014 and substantially all was credited back to PNM’s customers. In the first quarter of 2015, PNM recorded $4.3 million , including $3.1 million credited back to PNM’s customers, for its share of the settlement under this process for costs incurred from July 2011 through June 2014. In the second quarter of 2015, PNM recorded claims of $1.3 million , including $0.5 million credited back to PNM’s customers, for costs incurred between July 1, 2014 and June 30, 2015. Thereafter, PNM began recording estimated claims quarterly. The settlement agreement, which would have terminated upon payment of costs incurred through December 31, 2016, has been extended to December 31, 2019. PNM estimates that it will incur approximately $57.7 million (in 2016 dollars) for its share of the costs related to the on-site interim storage of spent nuclear fuel at PVNGS during the term of the operating licenses. PNM accrues these costs as a component of fuel expense as the fuel is consumed. At December 31, 2016 and 2015, PNM had a liability for interim storage costs of $12.1 million and $12.2 million included in other deferred credits. PVNGS has sufficient capacity at its on-site 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 United States 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. On June 8, 2012, the DC Circuit issued its decision on a challenge by several states and environmental groups of the NRC’s rulemaking regarding temporary storage and permanent disposal of high level nuclear waste and spent nuclear fuel. The petitioners had challenged the NRC’s 2010 update to the agency’s Waste Confidence Decision and temporary storage rule (the “Waste Confidence Decision”). The DC Circuit found that the Waste Confidence Decision update constituted a major federal action, which, consistent with NEPA, requires either an environmental impact statement or a finding of no significant impact from the NRC’s actions. The DC Circuit found that the NRC’s evaluation of the environmental risks from spent nuclear fuel was deficient and, therefore, remanded the Waste Confidence Decision update for further action consistent with NEPA. On September 6, 2012, the NRC commissioners issued a directive to the NRC staff to proceed with development of a generic EIS to support an updated Waste Confidence Decision. In September 2013, the NRC issued its draft generic EIS to support an updated Waste Confidence Decision. On August 26, 2014, the NRC approved a final rule on the environmental effects of continued storage of spent nuclear fuel. The continued storage rule adopted the findings of the generic EIS regarding the environmental impacts of storing spent fuel at any reactor site after the reactor’s licensed period of operations. As a result, those generic impacts do not need to be re-analyzed in the environmental reviews for individual licenses. The NRC lifted its suspension on final licensing actions on all nuclear power plant licenses and renewals that went into effect when the DC Circuit issued its June 2012 decision although PVNGS had not been involved in any licensing actions affected by that decision. The August 2014 final rule has been subject to continuing legal challenges before the NRC and the United States Court of Appeals. On May 19, 2016, the NRC denied petitions filed by multiple petitioners to revise the August 2014 rule. The DC Circuit issued an order upholding the August 2014 rule on June 3, 2016 and denied a subsequent petition for rehearing on August 8, 2016. In 2011, the National Association of Regulatory Utility Commissioners and the Nuclear Energy Institute challenged, in the DC Circuit, DOE’s 2010 determination of the adequacy of the one tenth of a cent per KWh fee (the “one-mill fee”) paid by the nation’s commercial nuclear power plant owners pursuant to their individual contracts with the DOE. On January 3, 2014, the DOE notified Congress of its intention to suspend collection of the one-mill fee, subject to Congress’ disapproval, as ordered by the DC Circuit. On May 16, 2014, the DOE adjusted the fee to zero . PNM anticipates challenges to this action and is unable to predict its ultimate outcome. The Clean Air Act Regional Haze In 1999, EPA developed a regional haze program and regional haze rules under the CAA. The rule directs each of the 50 states to address regional haze. Pursuant to the CAA, states have the primary role to regulate visibility requirements by promulgating SIPs. 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. The first planning period specifies setting reasonable progress goals for improving visibility in Class I areas by the year 2018. In July 2005, EPA promulgated its final regional haze rule guidelines for states to conduct BART determinations for certain covered facilities, including utility boilers, built between 1962 and 1977 that have the potential to emit more than 250 tons per year of visibility impairing pollution. If it is demonstrated that the emissions from these sources cause or contribute to visibility impairment in any Class I area, then BART must be installed by 2018. SJGS BART Compliance – SJGS is a source that is subject to the statutory obligations of the CAA to reduce visibility impacts. The State of New Mexico submitted its SIP on the regional haze and interstate transport elements of the visibility rules for review by EPA in June 2011. The SIP ruled that SJGS was required to reduce NOx emissions by installing selective non-catalytic reduction technology (“SNCR”) as BART. Nevertheless, in August 2011, EPA published a FIP, which included a regional haze BART determination for SJGS that required installation of selective catalytic reduction technology (“SCR”) as BART on all four units by September 21, 2016. PNM, as the operating agent for SJGS, engaged in discussions with NMED and EPA regarding an alternative to the FIP and SIP, which resulted in a non-binding agreement that would include the retirement of SJGS Units 2 and 3 by the end of 2017 and the installation of SNCRs on Units 1 and 4 by the later of January 31, 2016 or 15 months after EPA approval of a revised SIP (the “RSIP”). EPA issued final rules, which became effective on November 10, 2014, approving the RSIP and withdrawing the FIP. In addition to the SNCR equipment required by the RSIP, the NSR permit, which was required to be obtained in order to install the SNCRs, specified that SJGS Units 1 and 4 be converted to balanced draft technology (“BDT”). The requirement to install BDT was made binding and enforceable in the NSR permit issued by NMED that accompanied the RSIP submitted to the EPA. EPA’s rule approving the RSIP specifically references the NSR permit by including a condition that requires “modification of the fan systems on Units 1 and 4 to achieve ‘balanced’ draft configuration ….” Following issuance of the FIP, PNM estimated the total cost to install SCRs on all four units of SJGS to be between approximately $824 million and $910 million , including BDT equipment to assist with compliance with the NAAQS requirements and to eliminate all fugitive boiler emissions. PNM had previously indicated it estimated the cost of SNCRs on all four units of SJGS to be between approximately $85 million and $90 million based on a conceptual design study. Along with the SNCR installation, additional BDT equipment would be required to be installed, the cost of which had been estimated to total between approximately $105 million and $110 million for all four units of SJGS. Based upon its current SJGS ownership interest, PNM’s share of the costs described above would have been about 46.3% . Following the February 2013 development of the alternative BART compliance plan, PNM began taking steps to prepare for the potential installation of SNCR and BDT equipment on Units 1 and 4 and entered into contracts for the work. Installation of SNCRs on Unit 1 and BDT equipment on both Units 1 and 4 was completed in 2015 and installation of SNCRs on Unit 4 was completed in January 2016, which dates were within the timeframe contained in the RSIP. PNM’s share of the total costs for SNCRs and BDT equipment was $77.9 million . See Note 17 for information concerning the NMPRC’s treatment of BDT in PNM’s NM 2015 Rate Case. Although operating costs will be reduced due to the retirement of SJGS Units 2 and 3, the operating costs for SJGS Units 1 and 4 have increased with the installation of SNCR and BDT equipment. On December 20, 2013, PNM made a filing with the NMPRC requesting certain approvals necessary to effectuate the RSIP. In this filing, PNM requested: • Permission to retire SJGS Units 2 and 3 at December 31, 2017 and to recover over 20 years their net book value at that date along with a regulated return on those costs • A CCN to include PNM’s ownership of PVNGS Unit 3, amounting to 134 MW, as a resource to serve New Mexico retail customers at a proposed value of $2,500 per KW, effective January 1, 2018 • An order allowing cost recovery for PNM’s share of the installation of SNCR and BDT equipment to comply with NAAQS requirements on SJGS Units 1 and 4, not to exceed a total cost of $82 million PNM’s filing also addressed replacement of the capacity from the shutdown of SJGS Units 2 and 3, which will reduce PNM’s ownership in SJGS by 340 MW, including a possible increase in PNM’s ownership in SJGS Unit 4, the identification of a new 177 MW natural gas-fired generation source, and 40 MW of new utility-scale solar PV. PNM received approval to construct the 40 MW of solar PV facilities in its 2015 Renewable Energy Plan. See Note 17. PNM’s requests in the December 20, 2013 NMPRC filing were based on the status of the negotiations among the SJGS owners at that time regarding ownership restructuring and other matters (see SJGS Ownership Restructuring Matters below). On October 1, 2014, PNM and certain intervenors filed a stipulation with the NMPRC that would have settled all matters in PNM’s filing. On April 8, 2015, the Hearing Examiner in the case issued a Certification of Stipulation, which recommended the NMPRC reject the stipulation as proposed. In June 2015, a NMPRC Commissioner issued an order designating a facilitator to determine whether an uncontested settlement among some or all of the parties in this case could be accomplished. On August 13, 2015, as a result of the facilitation process, PNM, the staff of the NMPRC, the NMAG, Western Resource Advocates, and the Coalition for Clean Affordable Energy filed a settlement agreement with the NMPRC. NMIEC, Interwest Energy Alliance, and New Mexico Independent Power Producers subsequently joined in this agreement and NEE filed in opposition to the agreement. The stipulating parties agreed that the October 2014 stipulation should be approved, as modified by the settlement agreement (collectively, the “Stipulated Settlement”). The Hearing Examiner scheduled a hearing on PNM’s application concerning BART for SJGS to begin on October 13, 2015. NEE previously filed motions before the NMPRC requesting that four of the five NMPRC commissioners recuse themselves, alleging they had improper ex-parte communications, were biased, and had pre-judged the outcome of the BART case. Each of the four commissioners declined to recuse themselves. On October 5, 2015, NEE filed a Petition for a Writ of Mandamus and Request for Stay in the NM Supreme Court requesting the four commissioners be recused from this case and that PNM’s application be dismissed. On October 9, 2015, the NM Supreme Court issued orders that allowed the hearing conducted by the Hearing Examiner to proceed, but ordered that any action by the NMPRC be stayed, pending a decision by the NM Supreme Court on NEE’s petition. The hearing on the Stipulated Settlement was held from October 13, 2015 through October 20, 2015. Oral argument on NEE’s petition was held before the NM Supreme Court on November 9, 2015. On November 9, 2015, the NM Supreme Court denied NEE’s petition. On December 16, 2015, following oral argument, the NMPRC issued an order adopting the Stipulated Settlement. As provided in that order: • PNM will retire SJGS Units 2 and 3 (PNM’s current ownership interest totals 418 MW) by December 31, 2017 and recover, over 20 years, 50% of their undepreciated net book value at that date and earn a regulated return on those costs • PNM is granted a CCN to acquire an additional 132 MW in SJGS Unit 4, with an initial book value of zero , plus the costs of SNCR and other capital additions • PNM is granted a CCN for 134 MW of PVNGS Unit 3 with an initial rate base value equal to the book value as of December 31, 2017, including transmission assets associated with PVNGS Unit 3, (currently estimated to aggregate approximately $151 million ) • No later than December 31, 2018, and before entering into a binding agreement for post-2022 coal supply for SJGS, PNM will file its position and supporting testimony in a NMPRC case to determine the extent to which SJGS should continue serving PNM’s retail customers’ needs after mid-2022; all parties to the stipulation agree to support this case being decided within six months (to facilitate the 2018 filing PNM is developing two resource portfolios in its 2017 IRP to be filed in July 2017, one with SJGS continuing beyond mid-2022 and one where it is shut down) • PNM is authorized to acquire 65 MW of SJGS Unit 4 as excluded utility plant; PNM and PNMR commit that no further coal-fired merchant plant will be acquired at any time by PNM, PNMR, or any PNM affiliate; PNM is not precluded from seeking a CCN to include the 65 MW or other coal capacity in rate base • Beginning January 1, 2020, for every MWh produced by 197 MW of coal-fired generation from PNM’s ownership share of SJGS, PNM will acquire and retire one MWh of RECs or allowances that include a zero-CO 2 emission attribute compliant with EPA’s Clean Power Plan; this REC retirement is in addition to what is required to meet the RPS; the cost of these RECs are to be capped at $7.0 million per year and will be recovered in rates; PNM should purchase EPA-compliant RECs from New Mexico renewable generation unless those RECs are more costly • PNM will accelerate recovery of SNCR costs on SJGS Units 1 and 4 so that the costs are fully recovered by July 1, 2022 (cost recovery for PNM’s BDT project is discussed in Note 17) • PNM will not recover approximately $20 million of other costs incurred in connection with CAA compliance • PNM’s 2014 IRP docket will be closed without other NMPRC action At December 31, 2015, PNM’s carrying value for its current ownership share of SJGS Units 2 and 3 included plant in service of $468.2 million , accumulated depreciation and amortization (including cost of removal) of $193.3 million , and construction work in progress of $2.2 million for a net undepreciated net book value of $277.1 million . PNM estimated the undepreciated net book value of SJGS Units 2 and 3 at December 31, 2017 would be approximately $255.3 million , 50% of which would be recovered over a 20 -year period, including a return on the unrecovered amount at PNM’s WACC. At December 31, 2015, PNM recorded a $127.6 million regulatory disallowance to reflect the write-off of the 50% of the estimated December 31, 2017 net book value that will not be recovered. The ultimate amount of the disallowance will be dependent on the actual December 31, 2017 net undepreciated book values of SJGS Units 2 and 3. Accordingly, the amount initially recorded will be adjusted periodically to reflect changes in the projected December 31, 2017 net book values. A regulatory disallowance of $21.6 million was also recorded at December 31, 2015 for other unrecoverable costs based on the approved Stipulated Settlement. The new coal mine reclamation arrangement entered into in conjunction with the new coal supply agreement (“CSA”), described under Coal Supply below and in Note 16, resulted in a $16.5 million increase in the liability recorded for coal mine reclamation. The expense recorded for this increase and the above disallowances, aggregating $165.7 million , is included in regulatory disallowances and restructuring costs on the Consolidated Statements of Earnings (Loss). In addition, the shutdown of SJGS Units 2 and 3 will result in the reversal of certain deferred income tax items. The estimated impact of these tax items resulted in an expense of $1.8 million being recorded at December 31, 2015, which amount is included in income tax expense. During 2016, PNM revised its estimates of the December 31, 2017 projected book value of SJGS Units 2 and 3 and the other unrecoverable costs, which resulted in a net expense of $3.7 million , including a $4.5 million expense related to a refinement of the estimated liability for coal mine reclamation resulting from the new coal mine reclamation arrangement, that is reflected in regulatory disallowances and restructuring costs on the Consolidated Statement of Earnings. In addition, PNMR Development recorded an expense of $0.6 million in 2016 for costs it was obligated to reimburse the other SJGS participants under the restructuring arrangement, which is included in other deductions on the Consolidated Statement of Earnings. At December 31, 2016, the carrying value for PNM’s current ownership share of SJGS Units 2 and 3 is comprised of plant in service of $471.8 million and accumulated depreciation and amortization (including cost of removal) of $203.9 million for a net undepreciated book value of $267.9 million , offset by 50% (which equals $128.6 million ) of the anticipated December 31, 2017 net undepreciated book value of SJGS Units 2 and 3 that will not be recovered, resulting in the net carrying value for SJGS Units 2 and 3 being $139.3 million at December 31, 2016. On January 14, 2016, NEE filed a Notice of Appeal with the NM Supreme Court of the NMPRC’s December 16, 2015 order. On July 22, 2016, NEE filed a brief alleging that the NMPRC’s decision violated New Mexico Statutes and NMPRC regulations because PNM did not adequately consider replacement resources other than those proposed by PNM, the NMPRC did not require PNM to adequately address and mitigate ratepayer risk, the NMPRC unlawfully shifted the burden of proof, and the NMPRC’s decision was arbitrary and capricious. Answer briefs refuting NEE’s claims were filed on November 2, 2016 by PNM, the NMPRC, and other intervenors. In addition, on February 5, 2016, NEE filed a motion for reconsideration with the NMPRC of that order based on developments related to the loan made by NM Capital to facilitate the sale of SJCC, which is described under Coal Supply below. NEE alleged the loan is a transaction that, under the New Mexico Public Utility Act, requires prior NMPRC approval. PNM filed its response to NEE’s motion for reconsideration on February 18, 2016. The NEE motion was denied by operation of law because the NMPRC did not act on the motion. On March 31, 2016, NEE filed a complaint with the NMPRC against PNM regarding the financing provided by NM Capital to facilitate the sale of SJCC. The complaint alleges that PNM failed to comply with its discovery obligation in the SJGS abandonment case and requests the NMPRC investigate whether the financing transactions could adversely affect PNM’s ability to provide electric service to its retail customers. PNM responded to the complaint on May 4, 2016. The NMPRC has taken no action on this matter. PNM cannot currently predict the outcome of these matters. SJGS Ownership Restructuring Matters – Currently, SJGS is jointly owned by PNM and eight other entities, including three participants that operate in the State of California. Furthermore, each participant does not have the same ownership interest in each unit. The SJPPA that governs the operation of SJGS expires on July 1, 2022. In connection with requirements to install SNCR and BDT equipment at SJGS, the California participants indicated that, under California law, they may be prohibited from making significant capital improvements to SJGS and expressed the intent to exit their ownership in SJGS by December 31, 2017. One other participant also expressed a similar intent to exit ownership in the plant. As a result, the SJGS participants negotiated a restructuring of the ownership in SJGS and addressed the obligations of the exiting participants for plant decommissioning, mine reclamation, environmental matters, and certain future operating costs, among other items. The exiting participants currently own 50.0% of SJGS Unit 3 and 38.8% of SJGS Unit 4, but none of SJGS Units 1 and 2. PNM currently owns 50.0% of SJGS Units 1, 2, and 3 and 38.5% of SJGS Unit 4. Following mediated negotiations, the SJGS participants executed the San Juan Project Restructuring Agreement (“RA”) on July 31, 2015. The RA provides the essential terms of restructured ownership and addresses other related matters, including that the exiting participants remain obligated for their proportionate shares of environmental, mine reclamation, and certain other legacy liabilities that are attributable to activities that occurred prior to their exit. PNMR Development became a party to the RA and agreed to acquire a 65 MW ownership interest in SJGS Unit 4 on the exit date, which is anticipated to be December 31, 2017, but has obligations related to Unit 4 before then. On the exit date, PNM and PNMR Development would acquire 132 MW and 65 MW of the capacity in SJGS Unit 4 from the exiting owners for no initial cost other than funding capital improvements, including the costs of installing SNCR and BDT equipment. PNMR Development’s share of the costs of installing SNCR and BDT equipment amounted to $7.6 million . PNMR currently anticipates that PNMR Development will transfer the rights and obligations related to the 65 MW to PNM prior to December 31, 2017 in order to facilitate dispatch of power from that capacity. As ordered by the NMPRC, PNM would treat the 65 MW as merchant utility plant that would be excluded from retail rates. Reflecting the additions of the 132 MW and 65 MW, PNM’s ownership share would be 77.3% in SJGS Unit 4 and an aggregate of 66.3% in SJGS Units 1 and 4. The RA became effective contemporaneously with the effectiveness of the new CSA. The effectiveness of the new CSA was dependent on the closing of the purchase of the existing coal mine operation by a new mine operator, which as discussed in Coal Supply below, occurred at 11:59 PM on January 31, 2016. The RA sets forth the terms under which PNM acquired the coal inventory of the exiting SJGS participants as of January 1, 2016 and will supply coal to the exiting participants for the period from January 1, 2016 through December 31, 2017, which arrangement provides economic benefits that are being passed on to PNM’s customers through the FPPAC. The RA also includes provisions whereby the exiting owners will make payments to certain of the remaining participants, not including PNM, related to the restructuring. PNMR Development’s share of the restructuring fee was recorded at December 31, 2015 and the $3.1 million impact is included in other income on the Consolidated Statements of Earnings. On September 25, 2015, PNM made an application at FERC seeking certain approvals necessary for implementation of the restructured SJGS participation agreements. FERC approved the application on December 30, 2015. Other SJGS Matters – The SJPPA requires PNM, as operating agent, to obtain approval of capital improvement project expenditures from participants who have an ownership interest in the relevant unit or property common to more than one unit. The SJPPA also obligates PNM to take reasonable and prudent actions necessary for the successful and proper operation of SJGS if the participants fail to approve the requested expenditures. PNM presented the SNCR project, including BDT equipment, to the SJGS participants in Unit 1 and Unit 4 for approval in October 2013. The project was approved for Unit 1, but the Unit 4 project, which includes some of the California participants, was not approved. PNM subsequently submitted several requests to the owners of Unit 4 for approval of certain expenditures critical to comply with the time frame in the RSIP, as well as requests to approve the total forecasted project expenses. The required majority of Unit 4 owners did not approve these requests. PNM, in its capacity as operating agent, subsequently issued several “Prudent Utility Practice” notices under the SJPPA indicating PNM was undertaking certain critical activities to comply with regulatory requirements and keep the Unit 4 SNCR project on schedule. Although the RA results in an agreement among the SJGS participants enabling compliance with current CAA requirements, it is possible that the financial impact of climate change regulation or legislation, other environmental regulations, the result of litigation, and other business considerations, could jeopardize the economic viability of SJGS or the ability or willingness of individual participants to continue participation in the plant. Four Corners On August 6, 2012, EPA issued its Four Corners FIP with a final BART determination for Four Corners. The rule included two compliance alternatives. On December 30, 2013, APS notified EPA that the Four Corners participants selected the alternative that required APS to permanently close Units 1-3 by January 1, 2014 and install SCR post-combustion NOx controls on each of Units 4 and 5 by July 31, 2018. PNM owns a 13% interest in Units 4 and 5, but had no ownership interest in Units 1, 2, and 3, which were shut down by APS on December 30, 2013. For particulate matter emissions, EPA is requiring Units 4 and 5 to meet an emission limit of 0.015 lb/MMBTU and the plant to meet a 20% opacity limit, both of which are achievable through operation of the existing baghouses. Although unrelated to BART, the final BART rule also imposes a 20% opacity limitation on certain fugitive dust emissions from Four Corners’ coal and material handling operations. PNM estimates its share of costs for post-combustion controls at Four Corners Units 4 and 5 to be up to $90.4 million , including amounts incurred through December 31, 2016 and PNM’s AFUDC. PNM is seeking recovery from its ratepayers of these costs in its NM 2016 Rate Case discussed in Note 17. PNM is unable to predict the ultimate outcome of this matter. The Four Corners plant site is leased from the Navajo Nation. APS, on behalf of the Four Corners participants, negotiated amendments to the existing facility lease with the Navajo Nation, which extends the Four Corners leasehold interest from 2016 to 2041. The Navajo Nation approved these amendments in March 2011. The effectiveness of the amendments also required the approval of the DOI, as did a related federal rights-of-way grant that culminated in the issuance of a DOI Record of Decision on July 17, 2015. The Record of Decision approves the 25 -year site lease extension with the Navajo Nation for Four Corners, authorizes continued mining operations to supply the remaining units at Four Corners, renews transmission line and access road rights-of-way on the Navajo and Hopi Reservations, and accepts the proposed mining plan for the Navajo Mine. The Record of Decision provides the authority for the Bureau of Indian Affairs to sign the lease amendments and rights-of-way renewals, which occurred in July 2015. In addition, installation of SCR control technology at Four Corners required a PSD permit, which APS received in December 2014. T

Regulatory and Rate Matters

Regulatory and Rate Matters	12 Months Ended
	Dec. 31, 2016
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 16. PNM New Mexico General Rate Cases New Mexico 2015 General Rate Case (“NM 2015 Rate Case”) On December 11, 2014, PNM filed an application for revision of electric retail rates based upon a calendar year 2016 future test year (“FTY”) period. The application proposed a revenue increase of $107.4 million , effective January 1, 2016. Several parties filed briefs, which alleged that PNM’s application was incomplete and challenged other aspects of PNM’s filing. On April 17, 2015, the Hearing Examiner in the case issued an Initial Recommended Decision to the NMPRC recommending that the NMPRC find PNM’s application incomplete and reject it on the grounds that it did not comply with the FTY rule. The Hearing Examiner cited procedural defects in the filing, including a lack of fully functional electronic files and appropriate justification of certain costs in the future test year period. On May 13, 2015, the NMPRC voted to accept the Initial Recommended Decision regarding the completeness of PNM’s application and dismissed PNM’s application. On August 27, 2015, PNM filed a new application with the NMPRC for a general increase in retail electric rates. The application proposed a revenue increase of $123.5 million , including base non-fuel revenues of $121.7 million . PNM’s new application was based on a FTY period beginning October 1, 2015, which met the NMPRC’s May 2015 interpretation of the FTY statute discussed below, and proposed a ROE of 10.5% . The primary drivers of PNM’s identified revenue deficiency were the cost of infrastructure investments, including depreciation expense based on an updated depreciation study, and a decline in energy sales as a result of PNM’s successful energy efficiency programs and economic factors. The new application included several proposed changes in rate design to establish fair and equitable pricing across rate classes and to better align cost recovery with cost causation. Specific rate design proposals included higher customer and demand charges, a revenue decoupling pilot program applicable to residential and small commercial customers, a re-allocation of revenue among PNM’s customer classes, a new economic development rate, and continuation of PNM’s renewable energy rider. PNM requested that the proposed new rates become effective beginning in July 2016. On March 2, 2016, the NMPRC required PNM to file supplemental testimony regarding the treatment of renewable energy in PNM’s FPPAC due to issues identified in PNM’s 2016 renewable energy procurement plan. As ordered by the NMPRC, PNM filed supplemental testimony in the NM 2015 Rate Case demonstrating that PNM’s FPPAC is designed to properly recover its fuel and purchased power expenses. See Renewable Portfolio Standard below. A public hearing on the proposed new rates was held in April 2016. Subsequent to this hearing, the NMPRC ordered PNM to file additional testimony regarding PNM’s interests in PVNGS, including the 64.1 MW of PVNGS Unit 2 that PNM repurchased in January 2016, pursuant to the terms of the initial sales-leaseback transactions (Note 7). A subsequent public hearing was held in June 2016. After the June hearing, PNM and other parties were ordered to file supplemental briefs and to provide final recommended revenue requirements that incorporated fuel savings that PNM implemented effective January 1, 2016 from PNM’s SJGS coal supply agreement (“CSA”). PNM’s filing indicated that recovery for fuel related costs would be reduced by approximately $42.9 million reflecting the current CSA (Note 16), which also reduced the request for base non-fuel related revenues by $0.2 million to $121.5 million . On August 4, 2016, the Hearing Examiner in the case issued a recommended decision (“RD”). The RD proposed an increase in non-fuel revenues of $41.3 million compared to the $121.5 million increase requested by PNM. Major components of the difference in the increase in non-fuel revenues proposed in the RD, included: • A ROE of 9.575% compared to the 10.5% requested by PNM • Disallowing recovery of the entire $163.3 million purchase price for the January 15, 2016 purchases of the assets underlying three leases of portions of PVNGS Unit 2 (Note 7); the RD proposed that power from the previously leased assets, aggregating 64.1 MW of capacity, be dedicated to serving New Mexico retail customers with those customers being charged for the costs of fuel and operating and maintenance expenses (other than property taxes, which were $0.8 million per year at that time), but the customers would not bear any capital or depreciation costs other than those related to improvements made after the date of the original leases • Disallowing recovery from retail customers of the rent expense, which aggregates $18.1 million per year, under the four leases of capacity in PVNGS Unit 1 that were extended for eight years beginning January 15, 2015 and the one lease of capacity in PVNGS Unit 2 that was extended for eight years beginning January 15, 2016 (Note 7) and related property taxes, which were $1.5 million per year at that time; the RD proposed that power from the leased assets, aggregating 114.6 MW of capacity, be dedicated to serving New Mexico retail customers with those customers being charged for the costs of fuel and operating and maintenance expense, except that customers would not bear rental costs or property taxes • Disallowing recovery of the costs of converting SJGS Units 1 and 4 to BDT, which is required by the NSR permit for SJGS, (Note 16); PNM’s share of the costs of installing the BDT equipment was $52.3 million of which $40.0 million was included in rate base in PNM’s rate request • Disallowing recovery of $4.5 million of amounts recorded as regulatory assets and deferred charges from retail customers The RD recommended that the NMPRC find PNM was imprudent in the actions taken to purchase the previously leased 64.1 MW of capacity in PVNGS Unit 2, extending the leases for 114.6 MW of capacity of PVNGS Units 1 and 2, and installing the BDT equipment on SJGS Units 1 and 4. The RD also proposed that all fuel costs be removed from base rates and be recovered through the FPPAC. The RD would credit retail customers with 100% of the New Mexico jurisdictional portion of revenues from refined coal (a third-party pre-treatment process) at SJGS. In addition, the RD would remove recovery of the costs of power obtained from New Mexico Wind from the FPPAC and include recovery of those costs through PNM’s renewable energy rider discussed below. The RD recommended continuation of the renewable energy rider and certain aspects of PNM’s proposals regarding rate design, but would not approve certain other rate design proposals or PNM’s request for a revenue decoupling pilot program. The RD proposed approving PNM’s proposals for revised depreciation rates (with one exception), the inclusion of CWIP in rate base, and ratemaking treatment of the prepaid pension asset. The RD did not preclude PNM from supporting the prudence of the PVNGS purchases and lease renewals in its next general rate case and seeking recovery of those costs. PNM disagreed with many of the key conclusions reached by the Hearing Examiner in the RD and filed exceptions to defend its prudent utility investments. Other parties also filed exceptions to the RD. The NMPRC issued an order on September 28, 2016 that authorized PNM to implement an increase in non-fuel rates of $61.2 million , effective for bills sent to customers after September 30, 2016. The order generally approved the RD, but with certain significant modifications. The modifications to the RD included: • Inclusion of the January 2016 purchase of the assets underlying three leases of capacity, aggregating 64.1 MW, of PVNGS Unit 2 at an initial rate base value of $83.7 million ; and disallowance of the recovery of the undepreciated costs of capitalized improvements made during the period the 64.1 MW was being leased by PNM, which aggregated $43.8 million when the order was issued • Full recovery of the rent expense and property taxes associated with the extended leases for capacity, aggregating 114.6 MW, in Palo Verde Units 1 and 2 • Disallowance of the recovery of any future contribution for PVNGS decommissioning costs related to the 64.1 MW of capacity purchased in January 2016 and the 114.6 MW of capacity under the extended leases • Recovery of assumed operating and maintenance expense savings of $0.3 million annually related to BDT On September 30, 2016, PNM filed a Notice of Appeal with the NM Supreme Court regarding the order in the NM 2015 Rate Case. Subsequently, NEE, NMIEC, and ABCWUA filed notices of cross-appeal. On October 26, 2016, PNM filed a statement of issues related to its appeal with the NM Supreme Court, which states PNM is appealing the NMPRC’s determination that PNM was imprudent in the actions taken to purchase the previously leased 64.1 MW of capacity in PVNGS Unit 2, extending the leases for 114.6 MW of capacity of PVNGS Units 1 and 2, and installing the BDT equipment on SJGS Units 1 and 4. Specifically, PNM’s statement indicated it is appealing the following elements of the NMPRC’s order: • Disallowance of recovery of the full purchase price, representing fair market value, of the 64.1 MW of capacity in PVNGS Unit 2 purchased in January 2016 • Disallowance of the recovery of the undepreciated costs of capitalized improvements made during the period the 64.1 MW of capacity was leased by PNM • Disallowance of recovery of future contributions for PVNGS decommissioning attributable to the 64.1 MW of purchased capacity and the 114.6 MW of capacity under the extended leases • Disallowance of recovery of the costs of converting SJGS Units 1 and 4 to BDT The issues that are being appealed by the various cross-appellants include: • The NMPRC allowing PNM to recover the costs of the lease extensions for the 114.6 MW of PVNGS Units 1 and 2 and any of the purchase price for the 64.1 MW in PVNGS Unit 2 • The NMPRC allowing PNM to recover the costs incurred under the new coal supply contract for Four Corners • The revised method to collect PNM’s fuel and purchased power costs under the FPPAC • The final rate design • The NMPRC allowing PNM to include the prepaid pension asset in rate base NEE subsequently filed a motion for a partial stay of the order at the NM Supreme Court. This motion was denied. The NM Supreme Court stated that the court’s intent was to request that PNM reimburse ratepayers for any amount overcharged should the cross-appellants prevail on the merits. Otherwise, the court has taken no action with respect to the appeals. On February 17, 2017, PNM filed its Brief in Chief, and pursuant to the court’s rules, the briefing schedule is anticipated to be completed by June 7, 2017. Although appeals of regulatory actions of the NMPRC have a priority at the NM Supreme Court under New Mexico law, there is no required time frame for the court to act on the appeals. GAAP requires that a loss is to be recognized when it is probable that a loss has been incurred and the amount of loss can be reasonably estimated. When there is a range of the amount of the probable loss, the minimum amount of the range is to be accrued unless an amount within the range is a better estimate than any other amount. PNM evaluated the accounting consequences of the order in the NM 2015 Rate Case and the likelihood of being successful on the issues it is appealing in the NM Supreme Court as required under GAAP. The evaluation indicates it is reasonably possible that PNM will be successful on the issues it is appealing. If the NM Supreme Court rules in PNM’s favor on some or all of the issues, those issues would be remanded back to the NMPRC for further action. PNM estimates that it will take a minimum of 15 months, from the date PNM filed its appeal, for the NM Supreme Court to render a decision and for the NMPRC to take action on any remanded issues. During such time, the rates specified in the order will remain in effect. PNM has concluded that a range of probable loss resulted from the NMPRC order in the NM 2015 Rate Case, that the minimum amount of loss is 15 months of capital cost recovery that the order disallowed for its investments in the PVNGS Unit 2 purchases, PVNGS Unit 2 capitalized improvements, and BDT, and that no amount within the range of possible loss is a better estimate than any other amount. Accordingly, PNM recorded a pre-tax regulatory disallowance of $6.8 million for the capital costs that will not be covered during that 15 month appeal period. In addition, PNM recorded a pre-tax regulatory disallowance for $4.5 million of costs recorded as regulatory assets and deferred charges (which the order disallowed and which PNM did not propose to challenge in its appeal) since PNM can no longer assert that those assets are probable of being recovered through the ratemaking process. The NMPRC’s order approved PNM’s request to record a regulatory asset to recover a 2014 impairment of PNM’s New Mexico net operating loss carryforward resulting from an extension of the income tax provision for fifty percent bonus depreciation. The impact, net of federal income taxes, amounts to $2.1 million , which is reflected as a reduction of income tax expense on the Consolidated Statement of Earnings. PNM continues to believe that the disallowed investments, which are the subject of PNM’s appeal, were prudently incurred and that PNM is entitled to full recovery of those investments through the ratemaking process. Although PNM believes it is reasonably possible that its appeals will be successful, it cannot predict what decision the NM Supreme Court will reach or what further actions the NMPRC will take on any issues remanded to it by the court. If PNM’s appeal is unsuccessful, PNM would record further pre-tax losses related to the capitalized costs for any unsuccessful issues. The impacts of not recovering future contributions for decommissioning would be recorded in future periods. The amounts of any such losses to be recorded would depend on the ultimate outcome of the appeal and NMPRC process, as well as the actual amounts reflected on PNM books at the time of the resolution. However, based on the book values recorded by PNM as of December 31, 2016, such losses could include: • The remaining costs to acquire the assets previously leased under three leases aggregating 64.1 MW of PVNGS Unit 2 capacity in excess of the recovery permitted under the NMPRC’s order; the net book value of such excess amount was $76.9 million , after considering the loss recorded in 2016 • The undepreciated costs of capitalized improvements made during the period the 64.1 MW of capacity in PVNGS Unit 2 purchased by PNM in January 2016 was being leased by PNM; the net book value of these improvements was $39.9 million , after considering the loss recorded in 2016 • The remaining costs to convert SJGS Units 1 and 4 to BDT; the net book value of these assets was $50.0 million , after considering the loss recorded in 2016 Also, PNM has evaluated the accounting consequences of the issues that are being appealed by the cross-appellants. Although PNM does not believe the issues raised in the cross-appeals have substantial merit, PNM is unable to predict what decision the NM Supreme Court will reach. PNM does not believe that the likelihood of the cross-appeals being successful is probable. However, if the Supreme Court were to overturn all of the issues subject to the cross-appeals and, upon remand, the NMPRC did not provide any recovery of those items, PNM would write-off all of the costs to acquire the assets previously leased under three leases aggregating 64.1 MW of PVNGS Unit 2 capacity, totaling $155.6 million (which amount includes $76.9 million that is the subject of PNM’s appeal discussed above) at December 31, 2016, after considering the loss recorded in 2016. The impacts of not recovering costs for the lease extensions, new coal supply contract for Four Corners, and prepaid pension asset in rate base would be recognized in future periods reflecting that rates charged to customers would not recover those costs as they are incurred. The outcomes of the cross-appeals regarding the FPPAC and rate design should not have financial impact to PNM. PNM is unable to predict the outcome of this matter. New Mexico 2016 General Rate Case (“NM 2016 Rate Case”) On December 7, 2016, PNM filed an application with the NMPRC for a general increase in retail electric rates. PNM did not include any of the costs disallowed in the NM 2015 Rate Case that are at issue in its pending appeal to the NM Supreme Court. Key aspects of PNM’s request are: • An increase in base non-fuel revenues of $99.2 million • Based on a FTY beginning January 1, 2018 • ROE of 10.125% • Drivers of revenue deficiency ◦ Implementation of the modifications in PNM’s resource portfolio, which were previously approved by the NMPRC as part of the SJGS regional haze compliance plan (Note 16) ◦ Infrastructure investments ◦ Declines in forecasted energy sales due to successful energy efficiency programs and other economic factors ◦ Updates in the FERC/retail jurisdictional allocations • Proposed changes to rate design to establish fair and equitable pricing across rate classes and to better align cost recovery with cost causation ◦ Increased customer and demand charges ◦ A “lost contribution to fixed cost” mechanism applicable to residential and small commercial customers to address the regulatory disincentive associated with PNM’s energy efficiency programs Hearings are scheduled to begin on June 5, 2017. The NMPRC also ordered that a settlement conference should be held and that any resulting stipulation should be filed by March 27, 2017. The settlement conference has been scheduled for March 7, 2017. PNM cannot predict the outcome of this matter. Proceeding Regarding Definition of Future Test Year On May 27, 2015, the NMPRC approved an order that defines a FTY as a period that begins no later than 45 days following the filing of an application to increase rates. PNM disagreed with the interpretation adopted by the NMPRC and believes that the correct interpretation of the New Mexico FTY statute allows a FTY to begin up to 13 months after the filing of an application. On June 25, 2015, PNM filed a Notice of Appeal to the NM Supreme Court, challenging the NMPRC’s June 3, 2015 written order. On July 31, 2015, PNM and the NMPRC filed a joint motion for a temporary 30 -day stay and remand of PNM’s appeal so that the NMPRC could reconsider its FTY order in PNM’s 2014 rate case. The NM Supreme Court remanded this matter back to the NMPRC. On November 30, 2015, the NMPRC modified its previous order to provide for a FTY to begin up to 13 months after the filing of a rate case application. PNM and the NMPRC filed for dismissal of the appeal and the NM Supreme Court dismissed the appeal on February 15, 2016. Renewable Portfolio Standard The REA establishes a mandatory RPS requiring a utility to acquire a renewable energy portfolio equal to 10% of retail electric sales by 2011, 15% by 2015, and 20% by 2020. PNM files annual renewable energy procurement plans for approval by the NMPRC. The NMPRC requires renewable energy portfolios to be “fully diversified.” The current diversity requirements, which are subject to the limitation of the RCT, are minimums of 30% wind, 20% solar, 3% distributed generation, and 5% other. The REA provides for streamlined proceedings for approval of utilities’ renewable energy procurement plans, assures that utilities recover costs incurred consistent with approved procurement plans, and requires the NMPRC to establish a RCT for the procurement of renewable resources to prevent excessive costs being added to rates. Currently, the RCT is set at 3% of customers’ annual electric charges. PNM makes renewable procurements consistent with the NMPRC approved plans. PNM recovers certain renewable procurement costs from customers through a rate rider. See Renewable Energy Rider below. Included in PNM’s approved procurement plans are the following renewable energy resources: • 107 MW of PNM-owned solar PV facilities, including 23 MW constructed in 2014 and 40 MW constructed in 2015; the 2015 additions were identified as a cost-effective resource in PNM’s application to retire SJGS Units 2 and 3 (Note 16) and are being recovered in the base rates provided in the NM 2015 Rate Case discussed above rather than through PNM’s renewable energy rider; wind and solar REC purchases in 2013; and an additional procurement of 1.5 MW of PNM-owned solar PV facilities to supply the energy sold under PNM’s voluntary renewable energy tariff • A PPA through 2018 for the output of New Mexico Wind, having an aggregate capacity of 204 MW and a 20 -year PPA for the output of Red Mesa Wind, an existing wind generator having an aggregate capacity of 102 MW, beginning January 1, 2015 • A PPA for the output of the Lightning Dock Geothermal facility; the geothermal facility began providing power to PNM in January 2014; the current output of the facility is 4 MW • Solar distributed generation, aggregating 62.7 MW at December 31, 2016, owned by customers or third parties from whom PNM purchases any net excess output and RECs • Solar and wind RECs as needed to meet the RPS requirements PNM filed its 2016 renewable energy procurement plan on June 1, 2015. The plan met RPS and diversity requirements within the RCT in 2016 and 2017 using existing resources and did not propose any significant new procurements. The NMPRC approved the plan in November 2015, and, after granting a rehearing motion to consider issues regarding the rate treatment of certain customers eligible for a cap on, or an exemption from, RPS procurement, the NMPRC again approved the plan in an order issued on February 3, 2016. The NMPRC deferred issues related to capped and exempt customers to PNM’s NM 2015 Rate Case and to a new case, which the NMPRC subsequently initiated through issuance of an order to show cause. The NM 2015 Rate Case and show cause proceedings were to examine whether PNM miscalculated the FPPAC factor and base fuel costs in its treatment of renewable energy costs and application of the renewable procurement cost caps and exemptions. In the September 28, 2016 order in the NM 2015 Rate Case, the NMPRC ordered the cost of New Mexico Wind to be recovered through PNM’s renewable rider, rather than the FPPAC, and certain other modifications regarding the accounting for renewable energy in PNM’s FPPAC. These modifications do not affect the amount of fuel and purchased power or renewable costs that PNM will collect. PNM cannot predict the outcome of the show cause proceeding. PNM filed its 2017 renewable energy procurement plan on June 1, 2016. The plan meets RPS and diversity requirements for 2017 and 2018 using existing resources and does not propose any significant new procurements. PNM projects that its plan will slightly exceed the RCT in 2017 and will be within the RCT in 2018. PNM requested a variance from the RCT in 2017 to the extent the NMPRC determines a variance is necessary. A public hearing was held on September 26, 2016. On October 21, 2016, the Hearing Examiner issued a Recommended Decision recommending that the plan be approved as filed and also found that a variance from the RCT is not required. The NMPRC approved the Recommended Decision on November 23, 2016. Renewable Energy Rider The NMPRC has authorized PNM to recover certain renewable procurement costs through a rate rider billed on a per KWh basis. In PNM’s NM 2015 Rate Case, the NMPRC authorized continuation of the renewable rider. PNM recorded revenues from the rider of $42.0 million , $41.9 million , and $31.9 million in 2016, 2015, and 2014. In its 2016 renewable energy procurement plan case, PNM proposed to collect $42.4 million in 2016. The 2016 rider adjustment was approved as part of the order issued February 3, 2016 approving the 2016 renewable energy plan. In its 2017 renewable energy procurement plan discussed above, PNM proposed to collect $50.0 million through the rider in 2017. The increase, as compared with the amount the NMPRC approved for recovery through the rider in 2016, is due to including recovery of the costs of procuring energy from New Mexico Wind through the rider, rather than through the FPPAC, which complies with the NMPRC’s order in PNM’s NM 2015 Rate Case. The 2017 rider adjustment was approved as part of the order issued November 23, 2016 approving the 2017 renewable energy plan. As a separate component of the rider, if PNM’s earned return on jurisdictional equity in a calendar year, adjusted for weather and other items not representative of normal operations, exceeds the NMPRC-approved rate by 0.5% , PNM would be required to refund the excess to customers during May through December of the following year. The NMPRC-approved rate was 10.0% when the renewable rider was initially approved. PNM’s annual compliance filings with the NMPRC show that its jurisdictional equity return did not exceed the limitation through 2015. Preliminary calculations indicate PNM did not exceed such limitation in 2016. Energy Efficiency and Load Management Program Costs Public utilities are required by the Efficient Use of Energy Act to achieve specified levels of energy savings and to obtain NMPRC approval to implement energy efficiency and load management programs. In 2013, this act was amended to set an annual program budget equal to 3% of an electric utility’s annual revenue. PNM’s costs to implement approved programs are recovered through a rate rider. In October 2012, PNM filed an energy efficiency program application for programs proposed to be offered beginning in May 2013. The filing included proposed program costs of $22.5 million plus a proposed profit incentive. The NMPRC approved PNM’s program application, including the annual profit incentive discussed below, on November 6, 2013. On October 6, 2014, PNM filed an energy efficiency program application for programs proposed to be offered beginning in June 2015. The filing included proposed program costs of $25.8 million plus a proposed profit incentive. The proposed energy efficiency budget and plan are consistent with the 2013 amendments to the Efficient Use of Energy Act. PNM and the NMPRC staff filed a stipulated settlement on January 30, 2015. After a public hearing, the NMPRC approved the settlement on April 29, 2015. The approval established program budgets and the incentive amounts. On April 15, 2016, PNM filed an application for energy efficiency and load management programs to be offered in 2017. The proposed program portfolio consists of ten programs with a total budget of $28.0 million . The application also seeks approval of an incentive of $2.4 million based on target savings of 75 GWh. The actual incentive will be based upon actual savings achieved. An unopposed stipulation settling all issues was filed on September 29, 2016. The stipulation establishes a method to ensure that funding of PNM’s energy efficiency program is equal to 3% of its retail revenues, with an estimated 2017 energy efficiency funding level of $26.0 million , and a sliding scale profit incentive with a base level of 7.1% of program costs, equal to $1.8 million , if PNM achieves a minimum proscribed level of energy savings and increasing to a maximum of 9.0% depending on actual energy savings achieved above the minimum. The NMPRC approved the stipulation on January 11, 2017. Disincentives/Incentives The Efficient Use of Energy Act 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. In November 2013, the NMPRC issued an order authorizing PNM to recover an incentive equal to 7.6% of annual program costs beginning with program implementation in December 2013. Based on PNM’s approved program costs, this amounted to an annual incentive of $1.7 million . In PNM’s 2014 energy efficiency program application, PNM proposed an energy efficiency incentive of $2.1 million . PNM’s proposed incentive was based upon a shared benefits methodology and is similar in amount to previous PNM incentives authorized by the NMPRC. Under the terms of the January 30, 2015 stipulation discussed above, the incentive amount would be $1.7 million in 2015 and $1.8 million in 2016 assuming threshold level of savings are achieved. The base level incentive in 2017 is estimated to be $1.8 million . Energy Efficiency Rulemaking On May 17, 2012, the NMPRC issued a NOPR that would have amended the NMPRC’s energy efficiency rule to authorize use of a decoupling mechanism to recover certain fixed costs of providing retail electric service as the mechanism for removal of disincentives associated with the implementation of energy efficiency programs. The proposed rule also addressed incentives associated with energy efficiency. On July 26, 2012, the NMPRC closed the proposed rulemaking and opened a new energy efficiency rulemaking docket that may address decoupling and incentives. Workshops to develop a proposed rule have been held, but no order proposing a rule has been issued. PNM is unable to predict the outcome of this matter. On October 2, 2013, the NMPRC issued a NOPR and a proposed rule to implement amendments to the New Mexico Efficient Use of Energy Act. The NMPRC issued an order on October 8, 2014 adopting the proposed rule, which includes a provision that limits incentive awards to an amount equal to the utility’s WACC times its approved annual program costs. FPPAC Continuation Application Pursuant to the rules of the NMPRC, public utilities are required to file an application to continue using their FPPAC every four years. On April 23, 2014, the NMPRC approved a stipulated agreement resolving PNM’s 2013 application. The settlement modified the FPPAC to reset the fuel factor quarterly rather than annually, changed the carrying charge to apply the same rate to both over and under collections in the balancing account, allowed PNM to retain 10% of off-system sales margin through December 31, 2016, resolved the ratemaking treatment for coal pre-treatment at SJGS until the next subsequent PNM rate case, required PNM to write-off $10.5 million (which PNM recorded in 2013) of the under-collected balance in its FPPAC balancing account, and required PNM to recover the remaining under-collected balance ( $63.5 million as of April 30, 2014) over 18 months beginning July 1, 2014. Integrated Resource Plan NMPRC rules require that investor owned utilities file an IRP every three years. The IRP is required to cover a 20 -year planning period and contain an action plan covering the first four years of that period. 2014 IRP PNM filed its 2014 IRP on July 1, 2014. The four -year action plan was consistent with the replacement resources identified in PNM’s application to retire SJGS Units 2 and 3. PNM indicated that it planned to meet its anticipated long-term load growth with a combination of additional renewable energy resources, energy efficiency, and natural gas-fired facilities. Consistent with statute and NMPRC rule, PNM incorporated a public advisory process into the development of its 2014 IRP. On July 31, 2014, several parties requested the NMPRC not to accept the 2014 IRP as compliant with NMPRC rule because to do so could affect the then pending proceeding on PNM’s application to abandon SJGS Units 2 and 3 and for CCNs for certain replacement resources (Note 16) and because they asserted that the IRP does not conform to the NMPRC’s IRP rule. Certain parties also asked that further proceedings on the IRP be held in abeyance until the conclusion of the SJGS abandonment/CCN proceeding. The NMPRC issued an order in August 2014 that docketed a case to determine whether the IRP complies with applicable NMPRC rules. The order also held the case in abeyance pending the issuance of final, non-appealable orders in PNM’s 2015 renewable energy procurement plan case and its application to retire SJGS Units 2 and 3. The order regarding PNM’s application to abandon SJGS Units 2 and 3 described in Note 16 states that the NMPRC will issue a Notice of Proposed Dismissal in the 2014 IRP docket. On May 4, 2016, the NMPRC issued the Notice of Proposed Dismissal, stating that the docket will be closed with prejudice within thirty days unless good cause is shown why

Goodwill

Goodwill	12 Months Ended
	Dec. 31, 2016
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill	Goodwill The excess purchase price over the fair value of the assets acquired and the liabilities assumed by PNMR for its 2005 acquisition of TNP was recorded as goodwill and was pushed down to the businesses acquired. In 2007, the TNMP assets that were included in its New Mexico operations, including goodwill, were transferred to PNM. GAAP requires the Company to evaluate its goodwill for impairment annually at the reporting unit level or more frequently if circumstances indicate that the goodwill may be impaired. The Company evaluates goodwill impairment as of April 1st of each year. PNMR’s reporting units that have goodwill are PNM and TNMP. 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. GAAP provides that 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 determining whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount. If, after assessing the totality of events or 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, a quantitative analysis is not required. In other circumstances, an entity may perform a quantitative analysis to reach the conclusion regarding impairment with respect to a reporting unit. Currently, 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 requires 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. In January 2017, the FASB issued Accounting Standards Update 2017-04 - Intangibles - Goodwill and Other (Topic 350) that eliminates the second step of the impairment analysis. The Company must adopt this ASU in 2020, but early adoption is permitted. Accordingly, if the first step of a quantitative goodwill impairment analysis performed after adoption indicates that the fair value of a reporting unit is less than its carrying value, the goodwill of that reporting unit would be impaired to the extent of that difference. 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. For the annual evaluations performed as of April 1, 2016, PNMR utilized a quantitative analysis for both the PNM and TNMP reporting units. For the annual evaluations performed as of April 1, 2015 and 2014, PNMR utilized a quantitative analysis for the PNM reporting unit and a qualitative analysis for the TNMP reporting unit. A discounted cash flow methodology was primarily used in the quantitative analysis to estimate the fair value of each reporting unit. This analysis requires significant judgments, including estimation of future cash flows, which is dependent on internal forecasts, estimation of long-term growth rates for the business, and determination of appropriate weighted average cost of capital for each reporting unit. Changes in these estimates and assumptions could materially affect the determination of fair value and the conclusion of impairment. The annual evaluations performed as of April 1, 2016, 2015, and 2014 did not indicate impairments of the goodwill of any of PNMR’s reporting units. Since the April 1, 2016 annual evaluation, there have been no indications that the fair values of the reporting units with recorded goodwill have decreased below the carrying values. The April 1, 2016, 2015, and 2014 quantitative evaluations indicated the fair value of the PNM reporting unit, which has goodwill of $51.6 million , exceeded its carrying value by approximately 25% , 25% , and 30% . An increase of 0.5% in the expected return on equity capital utilized in discounting the forecasted cash flows, would have reduced the excess of PNM’s fair value over carrying value to approximately 18% , 18% , and 23% at April 1, 2016, 2015, and 2014. The 2016 quantitative evaluation indicated the fair value of the TNMP reporting unit, which has goodwill of $226.7 million , exceeded its carrying value by 32% . An increase of 0.5% in the expected return on equity capital utilized in calculating the WACC used to discount the forecasted cash flows, would have reduced the excess of TNMP’s fair value over carrying value to approximately 21% at April 1, 2016. The 2015 and 2014 qualitative analysis for TNMP included the consideration of various reporting unit specific factors as well as industry and macroeconomic factors to determine whether these factors were reasonably likely to have a material impact on the fair value of the reporting unit. Factors considered included the results of the April 1, 2012 quantitative analysis, which indicated that fair value exceeded carrying value of the reporting unit by approximately 26% , current and long-term forecasted financial results, regulatory environment, credit rating, interest rate environment, absolute and relative price of PNMR’s common stock, and operating strategy. TNMP believes it is operating within a generally favorable regulatory environment, its historical and forecasted financial results are positive, and its credit is perceived positively. Based on the analysis of the relevant factors, PNMR concluded that it was more likely than not that the fair value of the TNMP reporting unit exceeds its carrying value at April 1 2015 and 2014. Prior annual evaluations have not indicated impairments of any of PNMR’s reporting units, except in 2008. During 2008, the market capitalization of PNMR’s common stock was significantly below book value. In addition, a PNMR reporting unit, which was sold in 2011 was significantly impacted by depressed economic conditions and changes in the market in which it operated. As a result, goodwill impairments of $51.1 million for PNM, $34.5 million for TNMP, and an aggregate of $174.4 million for PNMR were recorded in 2008. Since 2008, the price of PNMR’s common stock has increased, improving the relationship between PNMR’s market capitalization and book value. In addition, improved regulatory treatment has been experienced by PNM in New Mexico and by TNMP in Texas. These factors resulted in more predictable earnings and increased fair values of the reporting units. Since 2008, the annual evaluations have not indicated that the fair values of the reporting units with recorded goodwill have decreased below their carrying values.

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income (Loss)	12 Months Ended
	Dec. 31, 2016
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Accumulated Other Comprehensive Income (Loss)	Accumulated Other Comprehensive Income (Loss) AOCI reports a measure for accumulated changes in equity that result from transactions and other economic events other than transactions with shareholders. Information regarding AOCI is as follows: Accumulated Other Comprehensive Income (Loss) PNM TNMP PNMR Unrealized Gains on Available-for-Sale Securities Pension Liability Adjustment Total Fair Value Adjustment for Cash Flow Hedges Fair Value Adjustment for Cash Flow Hedges Total (In thousands) Balance at December 31, 2013 $ 25,748 $ (83,625 ) $ (57,877 ) $ (263 ) $ — $ (58,140 ) Amounts reclassified from AOCI (pre-tax) (13,862 ) 5,152 (8,710 ) 558 — (8,152 ) Income tax impact of amounts reclassified 5,461 (2,032 ) 3,429 (195 ) — 3,234 Other OCI changes (pre-tax) 17,473 (15,282 ) 2,191 (153 ) — 2,038 Income tax impact of other OCI changes (6,812 ) 6,024 (788 ) 53 — (735 ) Net after-tax change 2,260 (6,138 ) (3,878 ) 263 — (3,615 ) Balance at December 31, 2014 28,008 (89,763 ) (61,755 ) — — (61,755 ) Amounts reclassified from AOCI (pre-tax) (28,531 ) 5,952 (22,579 ) — — (22,579 ) Income tax impact of amounts reclassified 11,181 (2,332 ) 8,849 — — 8,849 Other OCI changes (pre-tax) 10,998 (4,405 ) 6,593 — 72 6,665 Income tax impact of other OCI changes (4,310 ) 1,726 (2,584 ) — (28 ) (2,612 ) Net after-tax change (10,662 ) 941 (9,721 ) — 44 (9,677 ) Balance at December 31, 2015 17,346 (88,822 ) (71,476 ) — 44 (71,432 ) Amounts reclassified from AOCI (pre-tax) (22,139 ) 5,504 (16,635 ) — 764 (15,871 ) Income tax impact of amounts reclassified 8,639 (2,148 ) 6,491 — (298 ) 6,193 Other OCI changes (pre-tax) 778 (18,501 ) (17,723 ) — (874 ) (18,597 ) Income tax impact of other OCI changes (304 ) 7,219 6,915 — 341 7,256 Net after-tax change (13,026 ) (7,926 ) (20,952 ) — (67 ) (21,019 ) Balance at December 31, 2016 $ 4,320 $ (96,748 ) $ (92,428 ) $ — $ (23 ) $ (92,451 ) Pre-tax amounts reclassified from AOCI related to Unrealized Gains on Available-for-Sale Securities are included in Gains on available-for-sale securities in the Consolidated Statements of Earnings. Pre-tax amounts reclassified from AOCI related to Pension Liability Adjustment are reclassified to Operating Expenses – Administrative and general in the Consolidated Statements of Earnings. For the years ended December 31, 2016 , 2015 , and 2014 , approximately 23.4% , 22.2% , and 24.4% of the amount reclassified were capitalized into construction work in process and approximately 2.4% , 2.4% , and 2.0% were capitalized into other accounts. Pre-tax amounts reclassified from AOCI related to Fair Value Adjustment for Cash Flow Hedges are reclassified to Interest Charges in the Consolidated Statements of Earnings. An insignificant amount is then capitalized as AFUDC and capitalized interest. The income tax impacts of all amounts reclassified from AOCI are included in Income Taxes in the Consolidated Statements of Earnings.

Quarterly Operating Results (Un

Quarterly Operating Results (Unaudited)	12 Months Ended
	Dec. 31, 2016
Quarterly Financial Data [Abstract]
Quarterly Operating Results (Unaudited)	Quarterly Operating Results (Unaudited) Unaudited operating results by quarters for 2016 and 2015 are presented below. In the opinion of management of the Company, all adjustments (consisting of normal recurring accruals) necessary for a fair statement of the results of operations for such periods have been included. Quarter Ended March 31 June 30 September 30 December 31 (In thousands, except per share amounts) PNMR 2016 Operating revenues $ 310,961 $ 315,391 $ 400,374 $ 336,225 Operating income 41,508 64,822 108,071 63,584 Net earnings 13,965 30,952 58,556 28,423 Net earnings attributable to PNMR 10,546 27,076 54,418 24,809 Net Earnings Attributable to PNMR per Common Share: Basic 0.13 0.34 0.68 0.32 Diluted 0.13 0.34 0.68 0.31 2015 Operating revenues $ 332,868 $ 352,887 $ 417,433 $ 335,894 Operating income (loss) 49,569 72,414 121,505 (119,138 ) (1) Net earnings (loss) 17,852 35,655 64,855 (87,284 ) Net earnings attributable (loss) to PNMR 14,340 31,673 61,045 (91,418 ) Net Earnings (Loss) Attributable to PNMR per Common Share: Basic 0.18 0.40 0.77 (1.15 ) Diluted 0.18 0.40 0.76 (1.15 ) PNM 2016 Operating revenues $ 235,606 $ 233,346 $ 311,276 $ 255,685 Operating income 23,297 41,760 80,057 42,976 Net earnings 7,561 19,793 44,990 19,594 Net earnings attributable to PNM 4,274 16,049 40,984 16,112 2015 Operating revenues $ 261,940 $ 275,450 $ 333,437 $ 260,368 Operating income (loss) 31,655 47,179 93,710 (139,164 ) Net earnings (loss) 13,502 25,363 53,056 (92,245 ) Net earnings (loss) attributable to PNM 10,122 21,513 49,378 (96,247 ) TNMP 2016 Operating revenues $ 75,355 $ 82,045 $ 89,098 $ 80,540 Operating income 18,554 23,375 28,359 21,353 Net earnings 7,456 10,508 13,853 9,855 2015 Operating revenues $ 70,928 $ 77,437 $ 83,996 $ 75,526 Operating income 17,931 24,729 27,667 19,706 Net earnings 7,694 11,865 13,689 8,715 (1) Includes an expense of $165.7 million related to the BART determination for SJGS discussed in Note 16.

Schedule I - Condensed Financia

Schedule I - Condensed Financial Information of Parent Company	12 Months Ended
	Dec. 31, 2016
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
Schedule I - Condensed Financial Information of Parent Company	SCHEDULE I PNM RESOURCES, INC. CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY STATEMENTS OF EARNINGS Year ended December 31, 2016 2015 2014 (In thousands) Operating Revenues $ — $ — $ — Operating Expenses 2,871 1,221 650 Operating income (loss) (2,871 ) (1,221 ) (650 ) Other Income and Deductions: Equity in earnings of subsidiaries 122,252 27,352 124,543 Other income 1,711 747 622 Net other income and deductions 123,963 28,099 125,165 Interest Charges 8,102 8,275 13,650 Earnings Before Income Taxes 112,990 18,603 110,865 Income Tax Expense (Benefit) (3,859 ) 2,963 (5,389 ) Net Earnings $ 116,849 $ 15,640 $ 116,254 SCHEDULE I PNM RESOURCES, INC. CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY STATEMENTS OF CASH FLOWS Year Ended December 31, 2016 2015 2014 (In thousands) Net Cash Flows From Operating Activities $ 5,702 $ 1,375 $ 22,744 Cash Flows From Investing Activities: Utility plant additions 341 368 (474 ) Investments in subsidiaries (98,343 ) (175,000 ) — Cash dividends from subsidiaries 35,959 127,688 46,599 Net cash flows from investing activities (62,043 ) (46,944 ) 46,125 Cash Flows From Financing Activities: Short-term loan 100,000 50,000 — Repayment of short-term loan (150,000 ) — — Short-term borrowings (repayments), net 84,500 41,000 600 Long-term borrowings 100,000 150,000 — Repayment of long-term debt — (118,766 ) — Proceeds from stock option exercise 7,028 5,619 6,999 Purchases to satisfy awards of common stock (15,451 ) (17,720 ) (17,319 ) Dividends paid (70,095 ) (63,723 ) (58,940 ) Other, net (28 ) (782 ) 81 Net cash flows from financing activities 55,954 45,628 (68,579 ) Change in Cash and Cash Equivalents (387 ) 59 290 Cash and Cash Equivalents at Beginning of Period 441 382 92 Cash and Cash Equivalents at End of Period $ 54 $ 441 $ 382 Supplemental Cash Flow Disclosures: Interest paid, net of amounts capitalized $ 5,906 $ 7,559 $ 12,152 Income taxes paid (refunded), net $ — $ (730 ) $ (2,014 ) SCHEDULE I PNM RESOURCES, INC. CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY BALANCE SHEETS December 31, 2016 2015 (In thousands) Assets Cash and cash equivalents $ 54 $ 441 Intercompany receivables 92,234 102,676 Other, net 233 524 Total current assets 92,521 103,641 Property, plant and equipment, net of accumulated depreciation of $12,291 and $11,276 26,366 26,707 Investment in subsidiaries 1,986,276 1,822,593 Other long-term assets 79,314 81,168 Total long-term assets 2,091,956 1,930,468 $ 2,184,477 $ 2,034,109 Liabilities and Stockholders’ Equity Short-term debt $ 226,100 $ 191,600 Short-term debt-affiliate 8,819 8,819 Accrued interest and taxes 1,333 7,780 Other current liabilities 19,374 18,282 Total current liabilities 255,626 226,481 Long-term debt 249,895 149,860 Other long-term liabilities 3,004 2,955 Total liabilities 508,525 379,296 Common stock (no par value; 120,000,000 shares authorized; issued and outstanding 79,653,624 shares) 1,163,661 1,166,465 Accumulated other comprehensive income (loss), net of tax (92,451 ) (71,432 ) Retained earnings 604,742 559,780 Total common stockholders’ equity 1,675,952 1,654,813 $ 2,184,477 $ 2,034,109 See Notes 6, 7, 14, and 16 for information regarding commitments, contingencies, and maturities of long-term debt.

Schedule II - Valuation and Qua

Schedule II - Valuation and Qualifying Accounts	12 Months Ended
	Dec. 31, 2016
Valuation and Qualifying Accounts [Abstract]
Schedule II - Valuation and Qualifying Accounts	SCHEDULE II PNM RESOURCES, INC. AND SUBSIDIARIES VALUATION AND QUALIFYING ACCOUNTS Additions Deductions Description Balance at beginning of year Charged to costs and expenses Charged to other accounts Write-offs and other Balance at end of year (In thousands) Allowance for doubtful accounts, year ended December 31: 2014 $ 1,423 $ 3,267 $ — $ 3,224 $ 1,466 2015 $ 1,466 $ 3,358 $ — $ 3,427 $ 1,397 2016 $ 1,397 $ 2,885 $ — $ 3,073 $ 1,209 SCHEDULE II PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARY A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC. VALUATION AND QUALIFYING ACCOUNTS Additions Deductions Description Balance at beginning of year Charged to costs and expenses Charged to other accounts Write-offs Balance at end of year (In thousands) Allowance for doubtful accounts, year ended December 31: 2014 $ 1,423 $ 3,275 $ — $ 3,232 $ 1,466 2015 $ 1,466 $ 3,344 $ — $ 3,413 $ 1,397 2016 $ 1,397 $ 2,871 $ — $ 3,059 $ 1,209 SCHEDULE II TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC. VALUATION AND QUALIFYING ACCOUNTS Additions Deductions Description Balance at beginning of year Charged to costs and expenses Charged to other accounts Write-offs Balance at end of year (In thousands) Allowance for doubtful accounts, year ended December 31: 2014 $ — $ (8 ) $ — $ (8 ) $ — 2015 $ — $ 14 $ — $ 14 $ — 2016 $ — $ 14 $ — $ 14 $ —

Summary of the Business and S31

Summary of the Business and Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Basis of accounting	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.
Principles of Consolidation	Principles of Consolidation The 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 (Note 9) and, through January 15, 2016, the PVNGS Capital Trust. 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 shared services’ administrative and general expenses, which represent costs that are primarily driven by corporate level activities, are charged to the business segments. These services are billed at cost. Other significant intercompany transactions between PNMR, PNM, and TNMP include interest and income tax sharing payments, as well as equity transactions. All intercompany transactions and balances have been eliminated.
Accounting for the Effects of Certain Types of Regulation	Accounting for the Effects of Certain Types of Regulation The Company maintains its accounting records in accordance with the uniform system of accounts prescribed by FERC and adopted by the NMPRC and PUCT. Certain of the Company’s operations are regulated by the NMPRC, PUCT, and FERC and the provisions of GAAP for rate-regulated enterprises are applied to the regulated operations. Regulators may assign costs to accounting periods that differ from accounting methods applied by non-regulated utilities. When it is probable that regulators will permit recovery of costs through future rates, costs are deferred as regulatory assets that otherwise would be expensed. Likewise, regulatory liabilities are recognized when it is probable that regulators will require refunds through future rates or when revenue is collected for expenditures that have not yet been incurred. GAAP also provides for the recognition of revenue and regulatory assets and liabilities associated with “alternative revenue programs” authorized by regulators. Such programs allow the utility to adjust future rates in response to past activities or completed events, if certain criteria are met, even for programs that do not otherwise qualify for recognition of regulatory assets and liabilities. Regulatory assets and liabilities are amortized into earnings over the authorized recovery period. Accordingly, the Company has deferred certain costs and recorded certain liabilities pursuant to the rate actions of the NMPRC, PUCT, and FERC. Information on regulatory assets and regulatory liabilities is contained in Note 4. In some circumstances, regulators allow a requested increase in rates to be implemented, subject to refund, before the regulatory process has been completed and a decision rendered by the regulator. When this occurs, the Company assesses the possible outcomes of the rate proceeding. The Company records a provision for refund to the extent the amounts being collected, subject to refund, exceed the amount the Company determines is probable of ultimately being allowed by the regulator.
Cash and Cash Equivalents	Cash and Cash Equivalents Investments in highly liquid investments with original maturities of three months or less at the date of purchase are considered cash equivalents.
Utility Plant	Utility Plant Utility plant is stated at cost, which includes capitalized payroll-related costs such as taxes, pension, other fringe benefits, administrative costs, and AFUDC where authorized by rate regulation. Repairs, including major maintenance activities, and minor replacements of property are expensed when incurred, except as required by regulators for ratemaking purposes. Major replacements are charged to utility plant. Gains, losses, and costs to remove resulting from retirements or other dispositions of regulated property in the normal course of business are credited or charged to accumulated depreciation. PNM and TNMP may receive reimbursements, referred to as contributions in aid of construction (“CIAC”), from customers to pay for all or part of certain construction projects to extent that project does not benefit regulated customers in general. PNM and TNMP account for these reimbursements as offsets to utility plant additions based on the requirements of the NMPRC, FERC, and PUCT. Due to the PUCT’s regulatory treatment of CIAC reimbursements, TNMP also receives a financing component that is recognized as other income on the Consolidated Statements of Earnings. Under the NMPRC regulatory treatment, PNM does not receive a financing component.
Depreciation and Amortization	Depreciation and Amortization PNM’s provision for depreciation and amortization of utility plant, other than nuclear fuel, is based upon composite straight-line rates approved by the NMPRC and FERC. Amortization of nuclear fuel is based on units-of-production. TNMP’s provision for depreciation and amortization of utility plant is based upon straight-line rates approved by the PUCT. Depreciation of non-utility property is computed based on the straight-line method. The provision for depreciation of certain equipment is allocated between operating expenses and construction projects based on the use of the equipment. Average straight-line rates used were as follows: Year ended December 31 2016 2015 2014 PNM Electric plant 2.33 % 2.27 % 2.26 % Common, intangible, and general plant 5.40 % 4.66 % 4.64 % TNMP 3.66 % 3.65 % 3.59 %
Allowance for Funds Used During Construction	Allowance for Funds Used During Construction As provided by the FERC uniform systems of accounts, AFUDC is charged to regulated utility plant for construction projects. This allowance is a designed to enable a utility to capitalize financing costs during periods of construction of property subject to rate regulation. It represents the cost of borrowed funds (allowance for borrowed funds used during construction or “debt AFUDC”) and a return on other funds (allowance for equity funds used during construction or “equity AFUDC”). The allowance for borrowed funds used during construction is recorded in interest charges and the allowance for equity funds used during construction is recorded in other income on the Consolidated Statements of Earnings.
Capitalized Interest	Capitalized Interest The Company capitalizes interest on its construction projects and major computer software projects not subject to the computation of AFUDC.
Materials, Supplies, and Fuel Stock	Materials, Supplies, and Fuel Stock Materials and supplies relate to transmission, distribution, and generating assets. Materials and supplies are charged to inventory when purchased and are expensed or capitalized as appropriate when issued. Materials and supplies are valued using an average costing method. Coal is valued using a rolling weighted average costing method that is updated based on the current period cost per ton. Periodic aerial surveys are performed on the coal piles and adjustments are made. Average cost is equal to net realizable value under the ratemaking process.
Investments	PNM holds investment securities in the NDT for the purpose of funding its share of the decommissioning costs of PVNGS and trusts for PNM’s share of final reclamation costs related to the coal mines serving SJGS and Four Corners (Note 16). All of these investments are classified as available-for-sale. PNM evaluates the securities for impairment on an on-going basis. Since third party investment managers have sole discretion over the purchase and sales of the securities, PNM records a realized loss as an impairment for any security that has a market value that is less than cost at the end of each quarter. For the years ended December 31, 2016 , 2015 , and 2014 , PNM recorded impairment losses on the available-for-sale securities held in the NDT and coal mine reclamation trusts of $13.9 million , $10.4 million , and $4.8 million . No gains or losses are deferred as regulatory assets or liabilities. Unrealized gains on these investments, net of related tax effects, are included in OCI and AOCI. The available-for-sale securities are primarily comprised of international, United States, state, and municipal government obligations and corporate debt and equity securities. All investments are held in PNM’s name and are in the custody of major financial institutions. The specific identification method is used to determine the cost of securities disposed of, with realized gains and losses reflected in other income and deductions.
Goodwill	Goodwill Under GAAP, the Company does not amortize goodwill. Goodwill is evaluated for impairment annually, or more frequently if events and circumstances indicate that the goodwill might be impaired.
Asset Impairment	Asset Impairment Tangible long-lived assets are evaluated in relation to the estimated future undiscounted cash flows to assess recoverability when events and circumstances indicate that the assets might be impaired.
Revenue Recognition	Revenue Recognition Electric operating revenues are recorded in the period of energy delivery, which includes estimated amounts for service rendered but unbilled at the end of each accounting period. The determination of the energy sales to individual customers is based on the reading of their meters, which occurs on a systematic basis throughout the month. At the end of each month, amounts of energy delivered to customers since the date of the last meter reading and the corresponding unbilled revenue are estimated. Unbilled electric revenue is estimated based on the daily generation volumes, estimated customer usage by class, weather factors, line losses, and applicable customer rates reflecting historical trends and experience. PNM’s wholesale electricity sales are recorded as electric operating revenues and the wholesale electricity purchases are recorded as costs of energy sold. In accordance with GAAP, derivative contracts that are subject to unplanned netting are recorded net in earnings. A “book-out” is the planned or unplanned netting of off-setting purchase and sale transactions. A book-out is a transmission mechanism to reduce congestion on the transmission system or administrative burden. For accounting purposes, a book-out is the recording of net revenues upon the settlement of a derivative contract. Unrealized gains and losses on contracts that do not qualify for the normal purchases or normal sales exception or are not designated for hedge accounting are classified as economic hedges. Economic hedges are defined as derivative instruments, including long-term power and fuel supply agreements, used to hedge generation assets and purchased power costs. Changes in the fair value of economic hedges are reflected in results of operations, with changes related to economic hedges on sales included in operating revenues and changes related to economic hedges on purchases included in cost of energy sold.
Accounts Receivable and Allowance for Uncollectible Accounts	Accounts Receivable and Allowance for Uncollectible Accounts 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 calculates the allowance for uncollectible accounts based on historical experience and estimated default rates. The accounts receivable balances are reviewed monthly and adjustments to the allowance for uncollectible accounts and bad debt expense are made as necessary. Amounts that are deemed uncollectible are written off.
Amortization of Debt Acquisition Costs	Amortization of Debt Acquisition Costs Discount, premium, and expense related to the issuance of long-term debt are amortized over the lives of the respective issues. Gains and losses incurred upon the early retirement of long-term debt are recognized in other income or other deductions, except for amounts recoverable through NMPRC, FERC, or PUCT regulation, which are recorded as regulatory assets or liabilities and amortized over the lives of the respective issues. Unamortized debt premium, discount, and expense are reflected as part of the debt liabilities on the Consolidated Balance Sheets.
Derivatives and Accounting for Derivatives	Derivatives The Company records derivative instruments, including energy contracts, other than those designated as normal purchases or normal sales, in the balance sheet as either an asset or liability measured at their fair value. GAAP requires that changes in the derivatives’ fair value be recognized currently in earnings unless specific hedge accounting or normal purchase or normal sale criteria are met. Normal purchases and normal sales are not marked to market and are reflected in results of operations when the underlying transactions settle. For qualifying hedges, an entity must formally document, designate, and assess the effectiveness of transactions that receive hedge accounting. GAAP provides that the effective portion of the gain or loss on a derivative instrument designated and qualifying as a cash flow hedging instrument be reported as a component of AOCI and be reclassified into earnings in the period during which the hedged forecasted transaction affects earnings. The results of hedge ineffectiveness and the portion of the change in fair value of a derivative that an entity has chosen to exclude from hedge effectiveness are required to be presented in current earnings. See Note 6 and Note 8. The Company treats all forward commodity purchases and sales contracts subject to unplanned netting or book-out by the transmission provider as derivative instruments subject to mark-to-market accounting, unless the contract qualifies for the normal exception by meeting the definition of a capacity contract. Under this definition, the contract cannot permit net settlement, the seller must have the resources to serve the contract, and the buyer must be a load serving entity. GAAP provides guidance on whether realized gains and losses on derivative contracts not held for trading purposes should be reported on a net or gross basis and concludes such classification is a matter of judgment that depends on the relevant facts and circumstances. Accounting for Derivatives Under derivative accounting and related rules for energy contracts, the Company accounts for its various derivative instruments for the purchase and sale of energy based on the Company’s intent. During the years ended December 31, 2016 , 2015 , and 2014 , the Company was not hedging its exposure to the variability in future cash flows from commodity derivatives through designated cash flows hedges. The contracts recorded at fair value that do not qualify or are not designated for cash flow hedge accounting are classified as economic hedges. Economic hedges are defined as derivative instruments, including long-term power agreements, used to economically hedge generation assets, purchased power and fuel costs, and customer load requirements. Changes in the fair value of economic hedges are reflected in results of operations and are classified between operating revenues and cost of energy according to the intent of the hedge. The Company has no trading transactions.
Decommissioning and Reclamation Costs	Decommissioning and Reclamation Costs PNM owns and leases nuclear and fossil-fuel generating facilities. In accordance with GAAP, PNM is only required to recognize and measure decommissioning liabilities for tangible long-lived assets for which a legal obligation exists. Nuclear decommissioning costs and related accruals are based on periodic site-specific estimates of the costs for removing all radioactive and other structures at PVNGS and are dependent upon numerous assumptions, including estimates of future decommissioning costs at current price levels, inflation rates, and discount rates. PNM’s accruals for PVNGS Units 1, 2, and 3, including portions held under leases, have been made based on such estimates, the guidelines of the NRC, and the extended PVNGS license periods. PVNGS Units 1 and 2 are included in PNM’s retail rates while PVNGS Unit 3 is currently excluded. See Note 15 and Note 16. See Note 17 for information concerning the treatment of nuclear decommissioning in the NMPRC’s order in PNM’s NM 2015 Rate Case and PNM’s appeal of that order. In connection with both the SJGS and Four Corners coal supply agreements, the owners are required to reimburse the mining companies for the cost of contemporaneous reclamation, as well as the costs for final reclamation of the coal mines. The reclamation costs are based on periodic site-specific studies that estimate the costs to be incurred in the future and are dependent upon numerous assumptions, including estimates of future reclamation costs at current price levels, inflation rates, and discount rates. PNM considers the contemporaneous reclamation costs part of the cost of its delivered coal costs. See Note 16 for a discussion of the final reclamation costs.
Environmental Costs	Environmental Costs The normal operations of the Company involve activities and substances that expose the Company to potential liabilities under laws and regulations protecting the environment. Liabilities under these laws and regulations can be material and in some instances may be imposed without regard to fault, or may be imposed for past acts, even though the past acts may have been lawful at the time they occurred. The Company records its environmental liabilities when site assessments or remedial actions are probable and a range of reasonably likely cleanup costs can be estimated. The Company reviews its sites and measures the liability by assessing a range of reasonably likely costs for each identified site using currently available information and the probable level of involvement and financial condition of other potentially responsible parties. These estimates are based on assumptions regarding the costs for site investigations, remediation, operations and maintenance, monitoring, and site closure. The ultimate cost to clean up the Company’s identified sites may vary from its recorded liability due to numerous uncertainties inherent in the estimation process.
Income Taxes	Income Taxes Income taxes are recognized using the asset and liability method of accounting for income taxes. Deferred tax assets and liabilities are recognized for the estimated future tax consequences attributable to differences between the financial statement carrying value of existing assets and liabilities and their respective tax basis. In accordance with GAAP, all deferred taxes are reflected as non-current on the Consolidated Balance Sheets. Current NMPRC, FERC, and PUCT approved rates include the tax effects of the majority of these differences. GAAP requires that rate-regulated enterprises record deferred income taxes for temporary differences accorded flow-through treatment at the direction of a regulatory commission. The resulting deferred tax assets and liabilities are recorded based on the expected cash flow to be reflected in future rates. Because the NMPRC, FERC, and the PUCT have consistently permitted the recovery of tax effects previously flowed-through earnings, the Company has established regulatory liabilities and assets offsetting such deferred tax assets and liabilities. The Company recognizes only the impact of tax positions that, based on their merits, are more likely than not to be sustained upon an IRS audit. The Company defers investment tax credits related to rate regulated assets and amortizes them over the estimated useful lives of those assets. See Note 11. The Company makes an estimate of its anticipated effective tax rate for the year as of the end of each quarterly period within its fiscal year. In interim periods, income tax expense is calculated by applying the anticipated annual effective tax rate to year-to-date earnings before taxes, which includes the earnings attributable to the Valencia non-controlling interest. GAAP also provides that certain unusual or infrequently occurring items, as well as adjustments due to enactment of new tax laws, be excluded from the estimated annual effective tax rate calculation.
Excise Taxes	Excise Taxes The Company pays certain fees or taxes which are either considered to be an excise tax or similar to an excise tax. Substantially all of these taxes are recorded on a net basis in the Consolidated Statements of Earnings.
New Accounting Pronouncements	New Accounting Pronouncements Information concerning recently issued accounting pronouncements that have not been adopted by the Company is presented below. Accounting Standards Update 2014-09 – Revenue from Contracts with Customers (Topic 606) In May 2014, the FASB issued ASU No. 2014-09. The core principle of the guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. When it becomes effective, the new standard will replace most existing revenue recognition guidance in GAAP. In August 2015, the FASB issued a one-year deferral in the effective date. Since the issuance of ASU No. 2014-09, the FASB also has issued additional ASUs that clarify implementation guidance regarding principal versus agent considerations, licensing, and identifying performance obligations, as well as adding certain additional practical expedients. The new standard can be applied retrospectively to each prior period presented or on a modified retrospective basis with a cumulative effect adjustment to retained earnings on the date of adoption. The Company has not made a final decision on the transition method, but currently anticipates using the modified retrospective method. The Company will adopt the standard on January 1, 2018, its required effective date. The Company has completed its initial assessment of its revenues for potential changes to the amounts and timing of revenue recognition under the new guidance and does not anticipate significant changes in revenue recognition associated with retail electric service rates. The Company, along with others in the utility industry, is continuing to evaluate the impacts of the new guidance on its accounting for CIAC and the presentation of revenues associated with “alternative revenue programs,” which primarily result from its approved rate rider programs. The Company is continuing to analyze the impacts this new standard and has not yet completely determined the effect of the standard on its financial reporting. Accounting Standards Update 2016-01 – Financial Instruments (Subtopic 825-10) – Recognition and Measurement of Financial Assets and Financial Liabilities In January 2016, the FASB issued ASU No. 2016-01, which makes targeted improvements to GAAP regarding financial instruments. The new standard eliminates the requirement to classify investments in equity securities with readily determinable fair values into trading or available-for-sale categories and will require those equity securities to be measured at fair value with changes in fair value recognized in net income rather than in OCI. Also, the new standard will revise certain presentation and disclosure requirements. Under the new standard, accounting for investments in debt securities remains essentially unchanged. PNM currently classifies the investments held in the NDT and coal mine reclamation trusts as available for sale securities. Unrealized losses on these securities are recorded immediately through earnings and unrealized gains are recorded in AOCI until the securities are sold. The Company will adopt the new standard on January 1, 2018, its required effective date. At that time any unrealized gains, net of income taxes, recorded in AOCI related to equity securities will be reclassified to retained earnings as a cumulative effect adjustment and, thereafter, changes in the value of equity securities will be recorded in the Consolidated Statements of Earnings. The amount of the cumulative adjustment upon adoption will depend on the amounts recorded in AOCI at that time, but PNM had unrealized gains, net of income taxes, recorded in AOCI of $3.8 million at December 31, 2016. Accounting Standards Update 2016-02 – Leases (Topic 842) In February 2016, the FASB issued ASU No. 2016-02, which will change how lessees account for leases. The ASU will require that a liability be recorded on the balance sheet for all leases based on the present value of future lease obligations. A corresponding right-of-use asset will also be recorded. Amortization of the lease obligation and the right-of-use asset for certain leases, primarily those classified as operating leases, will be on a straight-line basis, which is not expected to have a significant impact on the statements of earnings or cash flows, whereas other leases will be required to be accounted for as financing arrangements similar to the accounting treatment for capital leases under current GAAP. Also, the new standard will revise certain disclosure requirements. Although early adoption of the standard is permitted, the Company does not currently plan to adopt this standard prior to January 1, 2019, its required effective date. At adoption of the ASU, leases will be recognized and measured as of the earliest period presented using a modified retrospective approach. The Company is in the process of analyzing the impacts of this new standard. Accounting Standards Update 2016-09 – Compensation – Stock Compensation (Topic 718) In March 2016, the FASB issued ASU No. 2016-09. The ASU simplifies several aspects of the accounting for share-based payment transactions, including income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. Currently, tax benefits resulting from deductions in excess of compensation cost on vested restricted stock and performance awards and on exercised stock options (“excess tax benefits”) are recorded to equity provided these benefits reduce taxes payable. Tax deficiencies resulting from deductions related to awards, which are below realized compensation cost upon vesting and on canceled stock options are recorded to equity. PNMR has not recorded excess tax benefits to equity since 2009 because it is in a net operating loss position for income tax purposes. PNMR will adopt this standard on January 1, 2017, its required effective date, and will record a cumulative effect adjustment to recognize excess tax benefits that have not been recorded due to the PNMR’s net operating loss. The impact of the cumulative effect adjustment will be to increase PNMR’s retained earnings and reduce accumulated deferred income tax liabilities by $8.4 million . PNMR has historically recognized cash flows from employee share withholdings as a financing activity. As a result, implementation of this standard will not result in any retrospective adjustments to the Consolidated Statements of Cash Flows. Subsequent to implementation, all excess tax benefits and deficiencies will be recorded to tax expense on the Consolidated Statements of Earnings and classified as cash flows from operating activities on the Consolidated Statements of Cash Flows. Accounting Standards Update 2016-13 – Financial Instruments – Credit Losses (Topic 326) Measurement of Credit Losses on Financial Instruments In June 2016, the FASB issued ASU No. 2016-13. The ASU changes the way entities recognize impairment of many financial assets, including accounts receivable and investments in debt securities, by requiring immediate recognition of estimated credit losses expected to occur over their remaining lives. The new standard is effective for the Company beginning on January 1, 2020. Early adoption is permitted beginning on January 1, 2019. The Company is in the process of analyzing the impacts of this new standard. Accounting Standards Update 2016-15 – Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments In August 2016, the FASB issued ASU No. 2016-15. The ASU eliminates diversity in practice in how certain cash receipts and cash payments are presented and classified in the statement of cash flows. Although early adoption is permitted, the Company does not currently plan to adopt this standard prior to January 1, 2018, its required effective date. The Company is in the process of analyzing the impacts of this new standard, but does not anticipate it will have a significant impact on the Company’s financial statements. Accounting Standards Update 2016-18 – Statement of Cash Flows (Topic 230): Restricted Cash In November 2016, the FASB issued ASU 2016-18. The ASU requires that the statements of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents during the period. Under the new standard, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the Statements of Cash Flows. Although early adoption is permitted, the Company does not currently plan to adopt this standard prior to January 1, 2018, its required effective date. The new standard requires the use of a retrospective transition method for each period presented after adoption. The Company is in the process of analyzing the impacts of this new standard.
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.
Fair Value of Derivatives	The Company determines the fair values of its derivative and other financial instruments based on the hierarchy established in GAAP, which requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. GAAP describes 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. Level 3 inputs used in determining fair values for the Company consist of internal valuation models. The Company records any transfers between fair value hierarchy levels as of the end of each calendar quarter. There were no transfers between levels during the years ended December 31, 2016 and 2015 . For available-for-sale securities, Level 2 fair values are provided by the trustee utilizing a pricing service. The pricing provider predominantly uses the market approach using bid side market value based upon a hierarchy of information for specific securities or securities with similar characteristics. 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. For investments categorized as Level 3, including the Westmoreland Loan, PVNGS lessor notes, and certain items in other investments, fair values were determined by discounted cash flow models that take into consideration discount rates that are observable for similar types of assets and liabilities. Management of the Company independently verifies the information provided by pricing services.
Variable Interest Entities	GAAP determines how an enterprise evaluates and accounts for its involvement with variable interest entities, focusing primarily on whether the enterprise has the power to direct the activities that most significantly impact the economic performance of a variable interest entity (“VIE”). GAAP also requires continual reassessment of the primary beneficiary of a VIE.
Pension and Other Postretirement Benefits	GAAP requires a plan sponsor to (a) recognize in its statement of financial position an asset for a plan’s overfunded status or a liability for a plan’s underfunded status; (b) measure a plan’s assets and its obligations that determine its funded status as of the end of the employer’s fiscal year; and (c) recognize changes in the funded status of a defined benefit postretirement plan in the year in which the changes occur. GAAP requires unrecognized prior service costs and unrecognized gains or losses to be recorded in AOCI and subsequently amortized. The amortization of these incurred costs is included as pension and postretirement benefit periodic cost or income in subsequent years. To the extent the amortization of these items will ultimately be recovered or returned through future rates, PNM and TNMP record the costs as a regulatory asset or regulatory liability. The expected long-term rate of return on pension and postretirement plan assets is calculated on the market-related value of assets. GAAP requires that actual gains and losses on pension and postretirement plan assets be recognized in the market-related value of assets equally over a period of not more than five years, which reduces year-to-year volatility.
Commitments and Contingencies	There are various claims and lawsuits pending against the Company. The Company also 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 (Note 17) proceedings in the normal course of its business. 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. Nevertheless, 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. In accordance with GAAP, the Company records liabilities for matters where it is probable a loss has been incurred and the amount of loss is reasonably estimable. The actual outcomes of the items listed below could ultimately differ from the judgments made and the differences could be material. The Company cannot make any assurances that the amount of reserves or potential insurance coverage will be sufficient to cover the cash obligations that might be incurred as a result of litigation or regulatory proceedings. Except as otherwise disclosed, the Company does not expect that any known lawsuits, environmental costs, and commitments will have a material effect on its financial condition, results of operations, or cash flows.

Summary of the Business and S32

Summary of the Business and Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Schedule of Average Rates Used Allocated Between Depreciation Expense and Construction Expense Projects Based on Use of Equipment	Average straight-line rates used were as follows: Year ended December 31 2016 2015 2014 PNM Electric plant 2.33 % 2.27 % 2.26 % Common, intangible, and general plant 5.40 % 4.66 % 4.64 % TNMP 3.66 % 3.65 % 3.59 %
Schedule of Inventory	Inventories consisted of the following at December 31 : PNMR PNM TNMP 2016 2015 2016 2015 2016 2015 (In thousands) Coal $ 19,940 $ 18,356 $ 19,940 $ 18,356 $ — $ — Materials and supplies 53,087 49,030 44,461 42,121 8,626 6,909 $ 73,027 $ 67,386 $ 64,401 $ 60,477 $ 8,626 $ 6,909

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2016
Segment Reporting [Abstract]
Summary of Segments	PNMR SEGMENT INFORMATION 2016 PNM TNMP Corporate and Other Consolidated (In thousands) Electric operating revenues $ 1,035,913 $ 327,038 $ — $ 1,362,951 Cost of energy 299,714 80,882 — 380,596 Utility margin 736,199 246,156 — 982,355 Other operating expenses 414,662 93,389 (12,791 ) 495,260 Depreciation and amortization 133,447 61,126 14,537 209,110 Operating income (loss) 188,090 91,641 (1,746 ) 277,985 Interest income 10,173 — 12,120 22,293 Other income (deductions) 22,066 3,202 (1,739 ) 23,529 Interest charges (87,469 ) (29,335 ) (11,829 ) (128,633 ) Segment earnings (loss) before income taxes 132,860 65,508 (3,194 ) 195,174 Income taxes (benefit) 40,922 23,836 (1,480 ) 63,278 Segment earnings (loss) 91,938 41,672 (1,714 ) 131,896 Valencia non-controlling interest (14,519 ) — — (14,519 ) Subsidiary preferred stock dividends (528 ) — — (528 ) Segment earnings (loss) attributable to PNMR $ 76,891 $ 41,672 $ (1,714 ) $ 116,849 At December 31, 2016: Total Assets $ 4,867,546 $ 1,383,223 $ 220,311 $ 6,471,080 Goodwill $ 51,632 $ 226,665 $ — $ 278,297 2015 PNM TNMP Corporate and Other Consolidated Electric operating revenues $ 1,131,195 $ 307,887 $ — $ 1,439,082 Cost of energy 391,131 73,518 — 464,649 Utility margin 740,064 234,369 — 974,433 Other operating expenses 590,967 88,051 (14,854 ) 664,164 Depreciation and amortization 115,717 56,285 13,917 185,919 Operating income 33,380 90,033 937 124,350 Interest income 6,574 — (76 ) 6,498 Other income (deductions) 26,914 3,736 (485 ) 30,165 Interest charges (79,950 ) (27,681 ) (7,229 ) (114,860 ) Segment earnings (loss) before income taxes (13,082 ) 66,088 (6,853 ) 46,153 Income taxes (benefit) (12,758 ) 24,125 3,708 15,075 Segment earnings (loss) (324 ) 41,963 (10,561 ) 31,078 Valencia non-controlling interest (14,910 ) — — (14,910 ) Subsidiary preferred stock dividends (528 ) — — (528 ) Segment earnings (loss) attributable to PNMR $ (15,762 ) $ 41,963 $ (10,561 ) $ 15,640 At December 31, 2015: Total Assets $ 4,599,344 $ 1,297,139 $ 112,845 $ 6,009,328 Goodwill $ 51,632 $ 226,665 $ — $ 278,297 2014 PNM TNMP Corporate and Other Consolidated Electric operating revenues $ 1,147,914 $ 287,939 $ — $ 1,435,853 Cost of energy 403,626 67,930 — 471,556 Utility margin 744,288 220,009 — 964,297 Other operating expenses 422,051 84,365 (14,450 ) 491,966 Depreciation and amortization 109,524 50,056 13,054 172,634 Operating income 212,713 85,588 1,396 299,697 Interest income 8,557 — (74 ) 8,483 Other income (deductions) 12,258 2,138 (2,302 ) 12,094 Interest charges (79,442 ) (27,396 ) (12,789 ) (119,627 ) Segment earnings (loss) before income taxes 154,086 60,330 (13,769 ) 200,647 Income taxes (benefit) 52,633 22,523 (5,418 ) 69,738 Segment earnings (loss) 101,453 37,807 (8,351 ) 130,909 Valencia non-controlling interest (14,127 ) — — (14,127 ) Subsidiary preferred stock dividends (528 ) — — (528 ) Segment earnings (loss) attributable to PNMR $ 86,798 $ 37,807 $ (8,351 ) $ 116,254 At December 31, 2014: Total Assets $ 4,453,114 $ 1,229,417 $ 107,706 $ 5,790,237 Goodwill $ 51,632 $ 226,665 $ — $ 278,297
Schedule of Major Customers	Three REPs accounted for more than 10% of the electric operating revenues of TNMP, as follows: Year Ended December 31, 2016 2015 2014 REP A 16 % 16 % 15 % REP B 11 % 13 % 15 % REP C 11 % 11 % 11 %

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2016
Related Party Transactions [Abstract]
Schedule of Related Party Transactions	The table below summarizes the nature and amount of related party transactions of PNMR, PNM and TNMP: Year Ended December 31, 2016 2015 2014 (In thousands) Services billings: PNMR to PNM $ 94,606 $ 90,827 $ 86,871 PNMR to TNMP 28,907 28,109 28,349 PNM to TNMP 427 554 524 TNMP to PNMR 66 41 31 Income tax sharing payments: PNMR to TNMP — — — PNMR to PNM — 1,450 — TNMP to PNMR — — — Interest payments: PNM to PNMR 11 54 65 PNMR to PNM 150 110 102 TNMP to PNMR 132 276 309

Regulatory Assets and Liabili35

Regulatory Assets and Liabilities (Tables)	12 Months Ended
	Dec. 31, 2016
Regulated Operations [Abstract]
Schedule of Regulatory Assets and Liabilities	Regulatory assets and liabilities reflected in the Consolidated Balance Sheets are presented below. PNM TNMP December 31, December 31, 2016 2015 2016 2015 Assets: (In thousands) Current: FPPAC $ 1,451 $ — $ — $ — Energy efficiency costs 1,991 — 413 629 Other — — — 441 3,442 — 413 1,070 Non-Current: CTC, including carrying charges — — 36,328 46,147 Coal mine reclamation costs 22,383 28,303 — — Deferred income taxes 62,918 66,990 9,932 10,244 Loss on reacquired debt 24,404 23,627 34,107 35,405 Pension and OPEB 249,286 218,743 27,661 23,356 AMS surcharge — — 14,669 1,673 AMS retirement costs — — 11,086 8,549 Other 6,422 5,247 2,027 2,380 365,413 342,910 135,810 127,754 Total regulatory assets $ 368,855 $ 342,910 $ 136,223 $ 128,824 PNM TNMP December 31, December 31, 2016 2015 2016 2015 Liabilities: (In thousands) Current: FPPAC $ — $ (11,410 ) $ — $ — Renewable energy rider (3,411 ) (2,584 ) — — Other (106 ) (1,597 ) (92 ) — (3,517 ) (15,591 ) (92 ) — Non-Current: Cost of removal (297,087 ) (284,015 ) (26,900 ) (26,859 ) Deferred income taxes (62,920 ) (77,502 ) (2,644 ) (3,283 ) PVNGS ARO (30,621 ) (33,747 ) — — Renewable energy tax benefits (22,540 ) (23,697 ) — — Nuclear spent fuel reimbursements (8,875 ) (9,214 ) — — Pension and OPEB — — (1,955 ) (1,913 ) Other (1,658 ) (6,688 ) (449 ) (495 ) (423,701 ) (434,863 ) (31,948 ) (32,550 ) Total regulatory liabilities $ (427,218 ) $ (450,454 ) $ (32,040 ) $ (32,550 )

Financing (Tables)

Financing (Tables)	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Schedule of Short-term Debt	Short-term debt outstanding consists of: December 31, Short-term Debt 2016 2015 (In thousands) PNM: PNM Revolving Credit Facility $ 35,000 $ — PNM New Mexico Credit Facility 26,000 — 61,000 — TNMP Revolving Credit Facility — 59,000 PNMR: PNMR Revolving Credit Facility 126,100 41,600 PNMR Term Loan Agreement — 150,000 PNMR 2016 One-Year Term Loan $ 100,000 $ 287,100 $ 250,600
Schedule of Long-term Debt Outstanding	Information concerning long-term debt outstanding and unamortized (premiums), discounts, and debt issuance costs is as follows: December 31, 2016 December 31, 2015 Principal Unamortized Discounts, (Premiums), and Issuance Costs, net Principal Unamortized Discounts, (Premiums), and Issuance Costs, net (In thousands) PNM Debt Senior Unsecured Notes, Pollution Control Revenue Bonds: 4.875% due 2033 $ — $ — $ 146,000 $ 721 1.875% due 2033, mandatory tender at October 1, 2021 146,000 1,807 — — 6.25% due 2038 36,000 239 36,000 251 4.75% due 2040, mandatory tender at June 1, 2017 37,000 25 37,000 82 5.20% due 2040, mandatory tender at June 1, 2020 40,045 147 40,045 190 5.90% due 2040 255,000 2,131 255,000 2,222 6.25% due 2040 11,500 96 11,500 100 2.54% due 2042, mandatory tender at June 1, 2017 20,000 67 20,000 199 2.40% due 2043, mandatory tender at June 1, 2020 39,300 340 39,300 456 5.20% due 2043, mandatory tender at June 1, 2020 21,000 75 21,000 96 Senior Unsecured Notes: 7.95% due 2018 350,000 995 350,000 1,718 7.50% due 2018 100,025 197 100,025 320 5.35% due 2021 160,000 780 160,000 943 3.85% due 2025 250,000 2,574 250,000 2,874 PNM Multi-draw Term Loan due 2016 — — 125,000 21 PNM 2016 Term Loan Agreement due 2017 175,000 28 — — 1,640,870 9,501 1,590,870 10,193 Less current maturities 232,000 120 125,000 21 1,408,870 9,381 1,465,870 10,172 TNMP Debt First Mortgage Bonds: 9.50% due 2019, Series 2009A 172,302 1,857 172,302 2,682 6.95% due 2043, Series 2013A 93,198 (18,773 ) 93,198 (19,490 ) 4.03% due 2024, Series 2014A 80,000 792 80,000 897 3.53% due 2026, Series 2016A 60,000 749 — — 405,500 (15,375 ) 345,500 (15,911 ) Less current maturities — — — — 405,500 (15,375 ) 345,500 (15,911 ) PNMR Debt PNMR 2015 Term Loan Agreement due 2018 150,000 84 150,000 140 BTMU Term Loan Agreement 92,207 1,634 — — PNMR 2016 Two-Year Term Loan due 2018 100,000 21 — — 342,207 1,739 150,000 140 Less current maturities 42,025 557 — — 300,182 1,182 150,000 140 Total Consolidated PNMR Debt 2,388,577 (4,135 ) 2,086,370 (5,578 ) Less current maturities 274,025 677 125,000 21 $ 2,114,552 $ (4,812 ) $ 1,961,370 $ (5,599 )
Schedule of Maturities of Long-term Debt	Reflecting mandatory tender dates, long-term debt matures as follows: PNMR PNM TNMP PNMR Consolidated (In thousands) 2017 $ 42,025 $ 232,000 $ — $ 274,025 2018 257,700 450,025 — 707,725 2019 12,310 — 172,302 184,612 2020 25,900 100,345 — 126,245 2021 4,272 306,000 — 310,272 Thereafter — 552,500 233,198 785,698 Total $ 342,207 $ 1,640,870 $ 405,500 $ 2,388,577

Lease Commitments (Tables)

Lease Commitments (Tables)	12 Months Ended
	Dec. 31, 2016
Leases [Abstract]
Schedule of Rent Expense	Operating lease expense, including the PVNGS and EIP leases, was: PNMR PNM TNMP (In thousands) 2016 $ 51,938 $ 47,349 $ 3,748 2015 $ 68,652 $ 63,558 $ 3,688 2014 $ 82,756 $ 76,745 $ 3,932
Schedule of Future Minimum Operating Lease Payments	Future minimum operating lease payments at December 31, 2016 are shown below: PNMR PNM TNMP (In thousands) 2017 $ 27,873 $ 26,497 $ 1,104 2018 25,809 25,262 267 2019 25,059 24,958 — 2020 25,044 24,958 — 2021 24,958 24,958 — Later years 84,462 84,462 — Total minimum lease payments $ 213,205 $ 211,095 $ 1,371

Fair Value of Derivative and 38

Fair Value of Derivative and Other Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2016
Fair Value of Derivative and Other Financial Instruments [Abstract]
Schedule of Commodity Derivatives	Commodity derivative instruments that are recorded at fair value, all of which are accounted for as economic hedges, are summarized as follows: Economic Hedges December 31, 2016 2015 (In thousands) PNMR and PNM Current assets $ 5,224 $ 3,813 Deferred charges — 2,622 5,224 6,435 Current liabilities (2,339 ) (1,859 ) Net $ 2,885 $ 4,576
Summary of the Effect of Mark-to-Market Commodity Derivative Instruments on Earnings	The following table presents the effect of mark-to-market commodity derivative instruments on earnings, excluding income tax effects. Commodity derivatives had no impact on OCI for the periods presented. Economic Hedges Year Ended 2016 2015 2014 (In thousands) PNMR and PNM Electric operating revenues $ (53 ) $ 7,156 $ 4,491 Cost of energy (1,208 ) (293 ) 593 Total gain $ (1,261 ) $ 6,863 $ 5,084
Schedule of Net Buy (Sell) Volume Positions	The table below presents PNMR’s and PNM’s net buy (sell) volume positions: Economic Hedges MMBTU MWh PNMR and PNM December 31, 2016 254,100 (2,471,600 ) December 31, 2015 577,481 (3,405,843 )
Schedule of Collateral Related to Derivative	The table below presents information about the Company’s contingent requirements to provide collateral under commodity contracts having an objectively determinable collateral provision that are in net liability positions and are not fully collateralized with cash. Contractual Liability represents 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. The table only reflects cash collateral that has been posted under the existing contracts and does not reflect letters of credit under the Company’s revolving credit facilities that have been issued as collateral. Net Exposure is the net contractual liability for all contracts, including those designated as normal purchases and normal sales, offset by existing cash collateral and by any offsets available under master netting agreements, including both asset and liability positions. Contingent Feature – Credit Rating Downgrade Contractual Liability Existing Cash Collateral Net Exposure (In thousands) PNMR and PNM December 31, 2016 $ — $ — $ — December 31, 2015 $ 839 $ — $ 839
Schedule of Fair Value and Unrealized Gains of Available-for-sale Securities	The fair value and gross unrealized gains of investments in available-for-sale securities are presented in the following table. December 31, 2016 December 31, 2015 Unrealized Gains Fair Value Unrealized Gains Fair Value PNMR and PNM (In thousands) Cash and cash equivalents $ — $ 23,683 $ — $ 10,700 Equity securities: Domestic value 1,135 34,796 11,610 44,505 Domestic growth 3,032 47,595 11,163 61,078 International and other 2,029 27,481 1,569 27,961 Fixed income securities: U.S. Government 115 40,962 178 27,880 Municipals 585 43,789 3,672 58,576 Corporate and other 553 54,671 628 28,342 $ 7,449 $ 272,977 $ 28,820 $ 259,042
Schedule of Realized Gain (Loss)	Gross realized losses shown below exclude the change in realized impairment losses of $(1.2) million , $(4.3) million , and $(0.7) million for the years ended December 31, 2016 , 2015 and 2014 . Year Ended December 31, 2016 2015 2014 (In thousands) Proceeds from sales $ 522,601 $ 252,174 $ 117,989 Gross realized gains $ 46,116 $ 29,663 $ 15,162 Gross realized (losses) $ (25,430 ) $ (9,259 ) $ (3,964 )
Investments Classified by Contractual Maturity Date	At December 31, 2016 , the available-for-sale and held-to-maturity debt securities had the following final maturities: Fair Value Available-for-Sale Held-to-Maturity PNMR and PNM PNMR (In thousands) Within 1 year $ 4,291 $ — After 1 year through 5 years 35,884 100,893 After 5 years through 10 years 52,651 — After 10 years through 15 years 5,617 — After 15 years through 20 years 6,924 — After 20 years 34,055 — $ 139,422 $ 100,893
Schedule of Instruments Presented by Level of Hierarchy	Items recorded at fair value on the Consolidated Balance Sheets are presented below by level of the fair value hierarchy. There were no Level 3 fair value measurements at December 31, 2016 and 2015 for items recorded at fair value. GAAP Fair Value Hierarchy Total Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs PNMR and PNM (In thousands) December 31, 2016 Available-for-sale securities Cash and cash equivalents $ 23,683 $ 23,683 $ — Equity securities: Domestic value 34,796 34,796 — Domestic growth 47,595 47,595 — International and other 27,481 27,481 — Fixed income securities: U.S. Government 40,962 39,723 1,239 Municipals 43,789 — 43,789 Corporate and other 54,671 23,158 31,513 $ 272,977 $ 196,436 $ 76,541 Commodity derivative assets $ 5,224 $ — $ 5,224 Commodity derivative liabilities (2,339 ) — (2,339 ) Net $ 2,885 $ — $ 2,885 December 31, 2015 Available-for-sale securities Cash and cash equivalents $ 10,700 $ 10,700 $ — Equity securities: Domestic value 44,505 44,505 — Domestic growth 61,078 61,078 — International and other 27,961 27,961 — Fixed income securities: U.S. Government 27,880 26,608 1,272 Municipals 58,576 — 58,576 Corporate and other 28,342 6,500 21,842 $ 259,042 $ 177,352 $ 81,690 Commodity derivative assets $ 6,435 $ — $ 6,435 Commodity derivative liabilities (1,859 ) — (1,859 ) Net $ 4,576 $ — $ 4,576
Summary of Carrying Amounts and Fair Value of Instruments	The carrying amounts and fair values of investments in the Westmoreland Loan, PVNGS lessor notes, other investments, and long-term debt, which are not recorded at fair value on the Consolidated Balance Sheets, are presented below: GAAP Fair Value Hierarchy Carrying Amount Fair Value Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) December 31, 2016 (In thousands) PNMR Long-term debt $ 2,392,712 $ 2,540,693 $ — $ 2,540,693 $ — Westmoreland Loan $ 95,000 $ 100,893 $ — $ — $ 100,893 Other investments $ 547 $ 1,164 $ 547 $ — $ 617 PNM Long-term debt $ 1,631,369 $ 1,730,157 $ — $ 1,730,157 $ — Other investments $ 316 $ 316 $ 316 $ — $ — TNMP Long-term debt $ 420,875 $ 468,329 $ — $ 468,329 $ — Other investments $ 231 $ 231 $ 231 $ — $ — December 31, 2015 PNMR Long-term debt $ 2,091,948 $ 2,264,869 $ — $ 2,264,869 $ — Investment in PVNGS lessor notes $ 8,587 $ 8,947 $ — $ — $ 8,947 Other investments $ 604 $ 1,269 $ 604 $ — $ 665 PNM Long-term debt $ 1,580,677 $ 1,703,209 $ — $ 1,703,209 $ — Investment in PVNGS lessor notes $ 8,587 $ 8,947 $ — $ — $ 8,947 Other investments $ 366 $ 366 $ 366 $ — $ — TNMP Long-term debt $ 361,411 $ 411,661 $ — $ 411,661 $ — Other investments $ 238 $ 238 $ 238 $ — $ —
Schedule of Investments Held by the Employee Benefit Plans	The fair values of investments held by the employee benefit plans are as follows: GAAP Fair Value Hierarchy Total Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) December 31, 2016 (In thousands) PNM Pension Plan Participation in PNMR Master Trust Investments: Investments categorized within fair value hierarchy $ 467,965 $ 129,624 $ 337,989 $ 352 Uncategorized investments 75,685 Total Master Trust Investments $ 543,650 TNMP Pension Plan Participation in PNMR Master Trust Investments: Investments categorized within fair value hierarchy $ 50,901 $ 14,447 $ 36,416 $ 38 Uncategorized investments 9,729 Total Master Trust Investments $ 60,630 PNM OPEB Plan Cash and cash equivalents $ 2,567 $ 2,567 $ — $ — Equity securities: International funds 9,300 — 9,300 — Domestic value 10,260 10,260 — — Domestic growth 6,338 6,338 — — Other funds 26,405 — 26,405 — Fixed income securities: Mutual funds 18,959 18,959 — — $ 73,829 $ 38,124 $ 35,705 $ — TNMP OPEB Plan Cash and cash equivalents $ 308 $ 308 $ — $ — Equity securities: International funds 1,279 — 1,279 — Domestic value 449 449 — — Domestic growth 1,089 1,089 — — Other funds 3,060 — 3,060 — Fixed income securities: Mutual funds 2,593 2,593 — — $ 8,778 $ 4,439 $ 4,339 $ — GAAP Fair Value Hierarchy Total Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) December 31, 2015 (In thousands) PNM Pension Plan Participation in PNMR Master Trust Investments: Investments categorized within fair value hierarchy $ 479,858 $ 111,441 $ 367,698 $ 719 Uncategorized investments 78,461 Total Master Trust Investments $ 558,319 TNMP Pension Plan Participation in PNMR Master Trust Investments: Investments categorized within fair value hierarchy $ 52,163 $ 12,199 $ 39,886 $ 78 Uncategorized investments 9,968 Total Master Trust Investments $ 62,131 PNM OPEB Plan Cash and cash equivalents $ 1,512 $ 1,512 $ — $ — Equity securities: International funds 10,604 — 10,604 — Domestic value 9,367 9,367 — — Domestic growth 5,894 5,894 — — Other funds 28,419 — 28,419 — Fixed income securities: Mutual funds 18,343 18,343 — — $ 74,139 $ 35,116 $ 39,023 $ — TNMP OPEB Plan Cash and cash equivalents $ 128 $ 128 $ — $ — Equity securities: International funds 1,310 — 1,310 — Domestic value 367 367 — — Domestic growth 1,013 1,013 — — Other funds 3,397 — 3,397 — Fixed income securities: Mutual funds 3,075 3,075 — — $ 9,290 $ 4,583 $ 4,707 $ — The fair values of investments in the PNMR Master Trust are as follows: GAAP Fair Value Hierarchy Total Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) December 31, 2016 (In thousands) PNMR Master Trust Cash and cash equivalents $ 20,503 $ 20,503 $ — $ — Equity securities: International 38,401 — 38,401 — Domestic value 36,036 36,036 — — Domestic growth 18,484 18,484 — — Other funds 27,532 — 27,532 — Fixed income securities: Corporate 205,419 — 205,029 390 U.S. Government 94,359 69,048 25,311 — Municipals 13,970 — 13,970 — Other funds 64,162 — 64,162 — Total investments categorized within fair value hierarchy 518,866 $ 144,071 $ 374,405 $ 390 Uncategorized investments: Private equity funds 27,060 Hedge funds 42,070 Real estate funds 16,284 $ 604,280 December 31, 2015 PNMR Master Trust Cash and cash equivalents $ 14,525 $ 14,525 $ — $ — Equity securities: International 36,675 — 36,675 — Domestic value 34,769 34,769 — — Domestic growth 25,407 25,407 — — Other funds 30,531 — 30,531 — Fixed income securities: Corporate 214,218 — 213,421 797 U.S. Government 98,138 48,936 49,202 — Municipals 16,647 — 16,647 — Other funds 61,111 3 61,108 — Total investments categorized within fair value hierarchy 532,021 $ 123,640 $ 407,584 $ 797 Uncategorized investments: Private equity funds 32,333 Hedge funds 40,731 Real estate funds 15,365 $ 620,450
Summary of Level 3 Measurements	A reconciliation of the changes in Level 3 fair value measurements is as follows: Fixed Income - Corporate PNMR Master Trust PNM Pension TNMP Pension Total Master Trust (In thousands) Balance at December 31, 2014 $ 655 $ 72 $ 727 Actual return on assets sold during the period — — — Actual return on assets still held at period end (1 ) — (1 ) Purchases 177 17 194 Sales (112 ) (11 ) (123 ) Balance at December 31, 2015 719 78 797 Actual return on assets sold during the period 1 — 1 Actual return on assets still held at period end 19 2 21 Purchases — — — Sales (387 ) (42 ) (429 ) Balance at December 31, 2016 $ 352 $ 38 $ 390 The following table presents information about the PBO, fair value of plan assets, and funded status of the plans: PNM Plan TNMP Plan Year Ended December 31, Year Ended December 31, 2016 2015 2016 2015 (In thousands) PBO at beginning of year $ 597,900 $ 657,557 $ 64,198 $ 72,305 Service cost — — — — Interest cost 30,307 28,255 3,304 3,043 Actuarial (gain) loss 39,463 (38,151 ) 4,318 (5,157 ) Benefits paid (45,919 ) (49,761 ) (4,759 ) (5,993 ) PBO at end of year 621,751 597,900 67,061 64,198 Fair value of plan assets at beginning of year 557,923 587,909 62,082 69,177 Actual return on plan assets 31,597 (10,225 ) 3,301 (1,102 ) Employer contributions — 30,000 — — Benefits paid (45,919 ) (49,761 ) (4,759 ) (5,993 ) Fair value of plan assets at end of year 543,601 557,923 60,624 62,082 Funded status – asset (liability) for pension benefits $ (78,150 ) $ (39,977 ) $ (6,437 ) $ (2,116 ) The following table presents information about the APBO, the fair value of plan assets, and the funded status of the plans: PNM Plan TNMP Plan Year Ended December 31, Year Ended December 31, 2016 2015 2016 2015 (In thousands) APBO at beginning of year $ 84,674 $ 95,175 $ 13,106 $ 14,070 Service cost 140 204 186 247 Interest cost 4,346 4,089 677 608 Participant contributions 2,690 2,439 520 320 Actuarial (gain) loss 17,877 (6,565 ) (96 ) (575 ) Benefits paid (11,734 ) (10,668 ) (1,563 ) (1,564 ) Plan design changes (3,724 ) — — — APBO at end of year 94,269 84,674 12,830 13,106 Fair value of plan assets at beginning of year 72,952 78,175 9,111 10,094 Actual return on plan assets 5,923 (617 ) 476 (82 ) Employer contributions 2,863 3,623 — 343 Participant contributions 2,690 2,439 520 320 Benefits paid (11,734 ) (10,668 ) (1,563 ) (1,564 ) Fair value of plan assets at end of year 72,694 72,952 8,544 9,111 Funded status – asset (liability) $ (21,575 ) $ (11,722 ) $ (4,286 ) $ (3,995 )

Variable Interest Entities (Tab

Variable Interest Entities (Tables)	12 Months Ended
	Dec. 31, 2016
Variable Interest Entities [Abstract]
Summarized Financial Information for Noncontrolling Interest	Summarized financial information for Valencia is as follows: Results of Operations Year Ended December 31, 2016 2015 2014 (In thousands) Operating revenues $ 20,371 $ 20,687 $ 20,247 Operating expenses (5,852 ) (5,777 ) (6,120 ) Earnings attributable to non-controlling interest $ 14,519 $ 14,910 $ 14,127 Financial Position December 31, 2016 2015 (In thousands) Current assets $ 2,551 $ 2,588 Net property, plant and equipment 66,947 69,784 Total assets 69,498 72,372 Current liabilities 578 965 Owners’ equity – non-controlling interest $ 68,920 $ 71,407

Earnings and Dividends Per Sh40

Earnings and Dividends Per Share (Tables)	12 Months Ended
	Dec. 31, 2016
Earnings Per Share [Abstract]
Computation of Earnings per Share and Dividends per Share	Information regarding the computation of earnings per share and dividends per share is as follows: Year Ended December 31, 2016 2015 2014 (In thousands, except per share amounts) Earnings Attributable to PNMR $ 116,849 $ 15,640 $ 116,254 Average Number of Common Shares: Outstanding during year 79,654 79,654 79,654 Vested awards of restricted stock 104 105 134 Average Shares – Basic 79,758 79,759 79,788 Dilutive Effect of Common Stock Equivalents: Stock options and restricted stock 374 380 491 Average Shares – Diluted 80,132 80,139 80,279 Net Earnings Per Share of Common Stock: Basic $ 1.47 $ 0.20 $ 1.46 Diluted $ 1.46 $ 0.20 $ 1.45 Dividends Declared per Common Share $ 0.9025 $ 0.8200 $ 0.7550

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax Expense (Benefit)	TNMP’s income taxes consist of the following components: Year Ended December 31, 2016 2015 2014 (In thousands) Current federal income tax $ 9,445 $ 1,603 $ 35 Current state income tax 1,729 1,639 1,939 Deferred federal income tax 12,690 20,904 20,577 Deferred state income tax (28 ) (21 ) (28 ) Total income taxes $ 23,836 $ 24,125 $ 22,523 PNMR’s income taxes consist of the following components: Year Ended December 31, 2016 2015 2014 (In thousands) Current federal income tax $ — $ — $ (2,015 ) Current state income tax (527 ) (1,376 ) (728 ) Deferred federal income tax 60,892 5,488 59,814 Deferred state income tax 3,886 12,305 14,831 Amortization of accumulated investment tax credits (973 ) (1,342 ) (2,164 ) Total income taxes $ 63,278 $ 15,075 $ 69,738 PNM’s income taxes (benefit) consist of the following components: Year Ended December 31, 2016 2015 2014 (In thousands) Current federal income tax $ (10,290 ) $ (7,934 ) $ (2,175 ) Current state income tax (1,907 ) (1,988 ) (979 ) Deferred federal income tax 49,123 (6,827 ) 45,890 Deferred state income tax 4,969 5,333 12,061 Amortization of accumulated investment tax credits (973 ) (1,342 ) (2,164 ) Total income taxes (benefit) $ 40,922 $ (12,758 ) $ 52,633
Schedule of Effective Income Tax Rate Reconciliation	PNMR’s provision for income taxes differed from the federal income tax computed at the statutory rate for each of the years shown. The differences are attributable to the following factors: Year Ended December 31, 2016 2015 2014 (In thousands) Federal income tax at statutory rates $ 68,311 $ 16,154 $ 70,226 Amortization of accumulated investment tax credits (973 ) (1,342 ) (2,164 ) Flow-through of depreciation items 1,227 1,485 1,344 Earnings attributable to non-controlling interest in Valencia (5,082 ) (5,218 ) (4,945 ) State income tax, net of federal benefit 4,537 (1,781 ) 5,723 Impairment of state net operating loss carryforwards (311 ) 5,278 3,129 Impairment of state production tax credits — 3,092 894 Allowance for equity funds used during construction (1,732 ) (3,650 ) (1,947 ) Reversal of deferred items related to BART at SJGS — 1,826 — Impairment of charitable contribution carryforward — 2,042 — Regulatory recovery of prior year impairment of state net operating loss carryforward, net of amortization (1,877 ) — — Other (822 ) (2,811 ) (2,522 ) Total income taxes $ 63,278 $ 15,075 $ 69,738 Effective tax rate 32.42 % 32.66 % 34.76 % The differences are attributable to the following factors: Year Ended December 31, 2016 2015 2014 (In thousands) Federal income tax (benefit) at statutory rates $ 46,501 $ (4,579 ) $ 53,930 Amortization of accumulated investment tax credits (973 ) (1,342 ) (2,164 ) Flow-through of depreciation items 1,185 1,465 1,325 Earnings attributable to non-controlling interest in Valencia (5,082 ) (5,218 ) (4,945 ) State income tax, net of federal benefit 3,921 (2,162 ) 5,522 Impairment of state net operating loss carryforwards (213 ) 3,619 2,145 Allowance for equity funds used during construction (1,457 ) (3,650 ) (1,947 ) Reversal of deferred items related to BART at SJGS — 1,826 — Reversal of deferred income taxes accrued at prior tax rates (301 ) (737 ) (737 ) Regulatory recovery of prior year impairment of state net operating loss carryforward, net of amortization (1,877 ) — — Other (782 ) (1,980 ) (496 ) Total income taxes (benefit) $ 40,922 $ (12,758 ) $ 52,633 Effective tax rate 30.80 % 97.52 % 34.16 % The differences are attributable to the following factors: Year Ended December 31, 2016 2015 2014 (In thousands) Federal income tax at statutory rates $ 22,928 $ 23,131 $ 21,115 State income tax, net of federal benefit 1,132 1,065 1,257 Other (224 ) (71 ) 151 Total income taxes $ 23,836 $ 24,125 $ 22,523 Effective tax rate 36.39 % 36.50 % 37.33 %
Components of Deferred Tax Assets and Liabilities	The components of PNM’s net accumulated deferred income tax liability were: December 31, 2016 2015 (In thousands) Deferred tax assets: Net operating loss $ 117,922 $ 116,693 Regulatory liabilities related to income taxes 60,940 75,889 Federal tax credit carryforwards 59,156 57,928 Shutdown of SJGS Units 2 and 3 53,434 53,823 Other 41,700 41,210 Total deferred tax assets 333,152 345,543 Deferred tax liabilities: Depreciation and plant related (891,578 ) (828,926 ) Investment tax credit (56,017 ) (56,589 ) Regulatory assets related to income taxes (56,577 ) (61,018 ) Pension (50,134 ) (58,070 ) Other (27,512 ) (37,324 ) Total deferred tax liabilities (1,081,818 ) (1,041,927 ) Net accumulated deferred income tax liabilities $ (748,666 ) $ (696,384 ) The components of PNMR’s net accumulated deferred income tax liability were: December 31, 2016 2015 (In thousands) Deferred tax assets: Net operating loss $ 160,901 $ 161,691 Regulatory liabilities related to income taxes 64,657 80,031 Federal tax credit carryforwards 78,675 77,417 Shutdown of SJGS Units 2 and 3 53,434 53,823 Other 75,805 70,749 Total deferred tax assets 433,472 443,711 Deferred tax liabilities: Depreciation and plant related (1,102,458 ) (1,027,047 ) Investment tax credit (56,017 ) (56,589 ) Regulatory assets related to income taxes (66,378 ) (71,054 ) CTC (12,715 ) (16,151 ) Pension (57,287 ) (65,226 ) Other (79,267 ) (85,037 ) Total deferred tax liabilities (1,374,122 ) (1,321,104 ) Net accumulated deferred income tax liabilities $ (940,650 ) $ (877,393 ) The components of TNMP’s net accumulated deferred income tax liability at December 31, were: December 31, 2016 2015 (In thousands) Deferred tax assets: Regulatory liabilities related to income taxes $ 3,718 $ 4,141 Other 6,016 6,702 Total deferred tax assets 9,734 10,843 Deferred tax liabilities: Depreciation and plant related (201,017 ) (189,322 ) CTC (12,715 ) (16,151 ) Regulatory assets related to income taxes (9,800 ) (10,036 ) Loss on reacquired debt (11,937 ) (12,392 ) Other (20,050 ) (15,733 ) Total deferred tax liabilities (255,519 ) (243,634 ) Net accumulated deferred income tax liabilities $ (245,785 ) $ (232,791 )
Reconciliation of Accumulated Deferred Income Tax Liability to Deferred Income Tax Benefit	The following table reconciles the change in PNMR’s net accumulated deferred income tax liability to the deferred income tax benefit included in the Consolidated Statement of Earnings: Year Ended December 31, 2016 (In thousands) Net change in deferred income tax liability per above table $ 63,257 Change in tax effects of income tax related regulatory assets and liabilities (10,621 ) Tax effect of mark-to-market adjustments 8,379 Tax effect of excess pension liability 5,071 Adjustment for uncertain income tax positions 297 Reclassification of unrecognized tax benefits (297 ) Regulatory recovery of prior year impairment of state net operating loss carryforward, net of amortization (1,877 ) Other (404 ) Deferred income taxes $ 63,805 The following table reconciles the change in PNM’s net accumulated deferred income tax liability to the deferred income tax benefit included in the Consolidated Statement of Earnings: Year Ended December 31, 2016 (In thousands) Net change in deferred income tax liability per above table $ 52,282 Change in tax effects of income tax related regulatory assets and liabilities (10,510 ) Tax effect of mark-to-market adjustments 8,336 Tax effect of excess pension liability 5,071 Adjustment for uncertain income tax positions 297 Reclassification of unrecognized tax benefits (297 ) Regulatory recovery of prior year impairment of state net operating loss carryforward, net of amortization (1,877 ) Other (183 ) Deferred income taxes $ 53,119 The following table reconciles the change in TNMP’s net accumulated deferred income tax liability to the deferred income tax benefit included in the Consolidated Statement of Earnings: Year Ended December 31, 2016 (In thousands) Net change in deferred income tax liability per above table $ 12,994 Change in tax effects of income tax related regulatory assets and liabilities (111 ) Other (221 ) Deferred income taxes $ 12,662
Reconciliation of Unrecognized Tax Benefits (Expenses)	A reconciliation of unrecognized tax benefits (expenses) is as follows: PNMR PNM TNMP (In thousands) Balance at December 31, 2013 $ 19,889 $ 11,073 $ 6,796 Additions based on tax positions related to 2014 623 623 — Additions (reductions) for tax positions of prior years (5,481 ) 532 (6,796 ) Settlement payments — — — Balance at December 31, 2014 15,031 12,228 — Additions based on tax positions related to 2015 1,214 1,214 — Additions (reductions) for tax positions of prior years (9,790 ) (9,790 ) — Settlement payments — — — Balance at December 31, 2015 6,455 3,652 — Additions based on tax positions related to 2016 242 242 — Additions (reductions) for tax positions of prior years 55 55 — Settlement payments — — — Balance at December 31, 2016 $ 6,752 $ 3,949 $ —
Interest Income (Expense) Related to Income Taxes	Interest income (expense) related to income taxes is as follows: PNMR PNM TNMP (In thousands) 2016 $ 4,398 $ 3,625 $ 345 2015 $ — $ — $ — 2014 $ 146 $ 148 $ (2 )
Accumulated Accrued Interest Receivable (Payable) Related to Income Taxes	Accumulated accrued interest receivable (payable) related to income taxes is as follows: PNMR PNM TNMP (In thousands) December 31, 2016: Accumulated accrued interest receivable $ — $ — $ — Accumulated accrued interest payable $ — $ — $ — December 31, 2015: Accumulated accrued interest receivable $ 3,236 $ 3,236 $ — Accumulated accrued interest payable $ (1,120 ) $ (24 ) $ (120 )
Deferred Income Taxes, Increase (Decrease) In Regulatory Liability and Income Tax Expense	Adjustments to deferred income taxes recorded as increases (decreases) in the regulatory liability and income tax expense are as follows: PNMR PNM TNMP (In thousands) December 31, 2016: Regulatory liability $ (7,132 ) $ (7,132 ) $ — Income tax expense $ 712 $ 804 $ — December 31, 2015: Regulatory liability $ (1,903 ) $ (1,903 ) $ — Income tax expense $ (674 ) $ (470 ) $ — December 31, 2014: Regulatory liability $ (5,106 ) $ (5,106 ) $ — Income tax expense $ (71 ) $ (312 ) $ —
Tax Carryforward, Impairments, net of Federal Tax Benefit	The impairments, net of federal tax benefit, for 2014 through 2016 are as follows: PNMR PNM TNMP (In thousands) December 31, 2016: State tax credit carryforwards $ — $ — $ — State net operating loss carryforwards $ (311 ) $ (213 ) $ — Charitable contribution carryforwards $ — $ — $ — December 31, 2015: State tax credit carryforwards $ 3,092 $ — $ — State net operating loss carryforwards $ 5,278 $ 3,619 $ — Charitable contribution carryforwards $ 2,042 $ — $ — December 31, 2014: State tax credit carryforwards $ 894 $ — $ — State net operating loss carryforwards $ 3,129 $ 2,145 $ —
Summary of Tax Credit Carryforwards	The reserve balances, after reflecting expiration of carryforwards under applicable tax laws, at December 31, 2016 and 2015 are as follows: PNMR PNM TNMP (In thousands) December 31, 2016: State tax credit carryforwards $ 3,986 $ — $ — State net operating loss carryforwards $ 361 $ 248 $ — Charitable contribution carryforwards $ 659 $ — $ — December 31, 2015: State tax credit carryforwards $ 6,378 $ — $ — State net operating loss carryforwards $ 361 $ 248 $ — Charitable contribution carryforwards $ 659 $ — $ —

Pension and Other Postretirem42

Pension and Other Postretirement Benefits (Tables)	12 Months Ended
	Dec. 31, 2016
Compensation and Retirement Disclosure [Abstract]
Schedule of Defined Benefit Plans Disclosures	A reconciliation of the changes in Level 3 fair value measurements is as follows: Fixed Income - Corporate PNMR Master Trust PNM Pension TNMP Pension Total Master Trust (In thousands) Balance at December 31, 2014 $ 655 $ 72 $ 727 Actual return on assets sold during the period — — — Actual return on assets still held at period end (1 ) — (1 ) Purchases 177 17 194 Sales (112 ) (11 ) (123 ) Balance at December 31, 2015 719 78 797 Actual return on assets sold during the period 1 — 1 Actual return on assets still held at period end 19 2 21 Purchases — — — Sales (387 ) (42 ) (429 ) Balance at December 31, 2016 $ 352 $ 38 $ 390 The following table presents information about the PBO, fair value of plan assets, and funded status of the plans: PNM Plan TNMP Plan Year Ended December 31, Year Ended December 31, 2016 2015 2016 2015 (In thousands) PBO at beginning of year $ 597,900 $ 657,557 $ 64,198 $ 72,305 Service cost — — — — Interest cost 30,307 28,255 3,304 3,043 Actuarial (gain) loss 39,463 (38,151 ) 4,318 (5,157 ) Benefits paid (45,919 ) (49,761 ) (4,759 ) (5,993 ) PBO at end of year 621,751 597,900 67,061 64,198 Fair value of plan assets at beginning of year 557,923 587,909 62,082 69,177 Actual return on plan assets 31,597 (10,225 ) 3,301 (1,102 ) Employer contributions — 30,000 — — Benefits paid (45,919 ) (49,761 ) (4,759 ) (5,993 ) Fair value of plan assets at end of year 543,601 557,923 60,624 62,082 Funded status – asset (liability) for pension benefits $ (78,150 ) $ (39,977 ) $ (6,437 ) $ (2,116 ) The following table presents information about the APBO, the fair value of plan assets, and the funded status of the plans: PNM Plan TNMP Plan Year Ended December 31, Year Ended December 31, 2016 2015 2016 2015 (In thousands) APBO at beginning of year $ 84,674 $ 95,175 $ 13,106 $ 14,070 Service cost 140 204 186 247 Interest cost 4,346 4,089 677 608 Participant contributions 2,690 2,439 520 320 Actuarial (gain) loss 17,877 (6,565 ) (96 ) (575 ) Benefits paid (11,734 ) (10,668 ) (1,563 ) (1,564 ) Plan design changes (3,724 ) — — — APBO at end of year 94,269 84,674 12,830 13,106 Fair value of plan assets at beginning of year 72,952 78,175 9,111 10,094 Actual return on plan assets 5,923 (617 ) 476 (82 ) Employer contributions 2,863 3,623 — 343 Participant contributions 2,690 2,439 520 320 Benefits paid (11,734 ) (10,668 ) (1,563 ) (1,564 ) Fair value of plan assets at end of year 72,694 72,952 8,544 9,111 Funded status – asset (liability) $ (21,575 ) $ (11,722 ) $ (4,286 ) $ (3,995 )
Schedule of Assumptions Used	Actuarial (gain) loss results from changes in: PNM Plan TNMP Plan Year Ended December 31, Year Ended December 31, 2016 2015 2016 2015 (in thousands) Discount rates $ 6,569 $ (7,345 ) $ 1,112 $ (1,322 ) Claims, contributions, and demographic experience 19,562 780 (102 ) 747 Assumed participation rate (6,335 ) — (1,013 ) — Mortality rate (691 ) — (93 ) — Medical benefits (1,228 ) — — — $ 17,877 $ (6,565 ) $ (96 ) $ (575 ) The following significant weighted-average assumptions were used to determine the APBO and net periodic benefit cost. Should actual experience differ from actuarial assumptions, the APBO and net periodic benefit cost would be affected. Year Ended December 31, PNM Plan 2016 2015 2014 Discount rate for determining December 31 APBO 4.47 % 5.34 % 4.45 % Discount rate for determining net periodic benefit cost 5.34 % 4.45 % 5.21 % Expected return on plan assets 7.70 % 7.70 % 8.50 % Rate of compensation increase N/A N/A N/A TNMP Plan Discount rate for determining December 31 APBO 4.47 % 5.34 % 4.45 % Discount rate for determining net periodic benefit cost 5.34 % 4.45 % 5.21 % Expected return on plan assets 5.70 % 5.70 % 6.50 % Rate of compensation increase N/A N/A N/A The following significant weighted-average assumptions were used to determine the PBO and net periodic benefit cost. Should actual experience differ from actuarial assumptions, the PBO and net periodic benefit cost would be affected. Year Ended December 31, PNM Plan 2016 2015 2014 Discount rate for determining December 31 PBO 4.51 % 5.29 % 4.48 % Discount rate for determining net periodic benefit cost 5.29 % 4.48 % 5.27 % Long-term rate of return on plan assets N/A N/A N/A Rate of compensation increase N/A N/A N/A TNMP Plan Discount rate for determining December 31 PBO 4.49 % 5.39 % 4.39 % Discount rate for determining net periodic benefit cost 5.39 % 4.39 % 5.06 % Long-term rate of return on plan assets N/A N/A N/A Rate of compensation increase N/A N/A N/A Actuarial (gain) loss results from changes in: PNM Plan TNMP Plan Year Ended December 31, Year Ended December 31, 2016 2015 2016 2015 (in thousands) Discount rates $ 41,849 $ (45,918 ) $ 5,055 $ (6,090 ) Demographic experience (334 ) 2,778 (556 ) 877 Other assumption and experience (2,052 ) 4,989 (181 ) 56 $ 39,463 $ (38,151 ) $ 4,318 $ (5,157 ) The following significant weighted-average assumptions were used to determine the PBO and net periodic benefit cost (income). Should actual experience differ from actuarial assumptions, the PBO and net periodic benefit cost (income) would be affected. Year Ended December 31, PNM Plan 2016 2015 2014 Discount rate for determining December 31 PBO 4.51 % 5.29 % 4.48 % Discount rate for determining net periodic benefit cost (income) 5.29 % 4.48 % 5.27 % Expected return on plan assets 6.50 % 6.80 % 7.20 % Rate of compensation increase N/A N/A N/A TNMP Plan Discount rate for determining December 31 PBO 4.49 % 5.39 % 4.39 % Discount rate for determining net periodic benefit cost (income) 5.39 % 4.39 % 5.06 % Expected return on plan assets 6.50 % 6.80 % 7.20 % Rate of compensation increase N/A N/A N/A
Schedule of Amounts in Accumulated Other Comprehensive Income (Loss) to be Recognized over Next Fiscal Year	The following table presents pre-tax information about prior service cost and net actuarial (gain) loss in AOCI as of December 31, 2016 . PNM Plan TNMP Plan December 31, 2016 December 31, 2016 Prior service cost Net actuarial (gain) loss Net actuarial (gain) loss (In thousands) Amounts in AOCI not yet recognized in net periodic benefit cost (income) at beginning of year $ (1,855 ) $ 146,775 $ — Experience (gain) loss — 43,283 4,960 Regulatory asset (liability) adjustment — (25,104 ) (4,960 ) Amortization recognized in net periodic benefit cost (income) 405 (5,805 ) — Amounts in AOCI not yet recognized in net periodic benefit cost (income) at end of year $ (1,450 ) $ 159,149 $ — Amortization expected to be recognized in 2017 $ (405 ) $ 6,320 $ — The following table presents pre-tax information about net actuarial loss in AOCI as of December 31, 2016 . December 31, 2016 PNM Plan TNMP Plan (In thousands) Amount in AOCI not yet recognized in net periodic benefit cost at beginning of year $ 2,084 $ — Experience (gain) loss 768 47 Regulatory asset (liability) adjustment (445 ) (47 ) Amortization recognized in net periodic benefit cost (income) (108 ) — Amount in AOCI not yet recognized in net periodic benefit cost at end of year $ 2,299 $ — Amortization expected to be recognized in 2017 $ 132 $ —
Schedule of Net Benefit Costs	The following table presents the components of net periodic benefit cost (income): Year Ended December 31, 2016 2015 2014 (In thousands) PNM Plan Service cost $ — $ — $ — Interest cost 30,307 28,255 30,163 Expected return on plan assets (35,416 ) (39,323 ) (38,044 ) Amortization of net (gain) loss 13,820 14,820 13,020 Amortization of prior service cost (965 ) (965 ) (965 ) Net periodic benefit cost $ 7,746 $ 2,787 $ 4,174 TNMP Plan Service cost $ — $ — $ — Interest cost 3,304 3,043 3,193 Expected return on plan assets (3,943 ) (4,420 ) (4,526 ) Amortization of net (gain) loss 700 782 665 Amortization of prior service cost — — — Net periodic benefit cost (income) $ 61 $ (595 ) $ (668 ) The following table presents the components of net periodic benefit cost: Year Ended December 31, 2016 2015 2014 (In thousands) PNM Plan Service cost $ — $ — $ — Interest cost 812 760 822 Amortization of net (gain) loss 256 325 210 Amortization of prior service cost — — — Net periodic benefit cost $ 1,068 $ 1,085 $ 1,032 TNMP Plan Service cost $ — $ — $ — Interest cost 40 36 39 Amortization of net (gain) loss 2 5 — Amortization of prior service cost — — — Net periodic benefit cost $ 42 $ 41 $ 39 The following table presents the components of net periodic benefit cost: Year Ended December 31, 2016 2015 2014 (In thousands) PNM Plan Service cost $ 140 $ 204 $ 181 Interest cost 4,346 4,089 4,630 Expected return on plan assets (5,483 ) (5,610 ) (5,638 ) Amortization of net (gain) loss 1,145 1,966 2,225 Amortization of prior service credit (30 ) (642 ) (1,343 ) Net periodic benefit cost $ 118 $ 7 $ 55 TNMP Plan Service cost $ 186 $ 247 $ 237 Interest cost 677 608 619 Expected return on plan assets (490 ) (520 ) (534 ) Amortization of net (gain) loss (40 ) — (122 ) Amortization of prior service cost — — 32 Net periodic benefit cost $ 333 $ 335 $ 232
Schedule of Expected Benefit Payments	The following executive retirement plan payments, which reflect expected future service, are expected: PNM Plan TNMP Plan (In thousands) 2017 $ 1,510 $ 93 2018 1,487 92 2019 1,459 89 2020 1,427 86 2021 1,391 83 2022 – 2026 6,228 341 The following other postretirement benefit payments, which reflect expected future service and are net of participant contributions, are expected to be paid: PNM Plan TNMP Plan (In thousands) 2017 $ 8,425 $ 803 2018 8,327 818 2019 8,092 827 2020 7,965 839 2021 7,792 859 2022 - 2026 33,891 4,466 The following pension benefit payments are expected to be paid: PNM Plan TNMP Plan (In thousands) 2017 $ 50,244 $ 5,526 2018 48,398 5,728 2019 47,696 5,086 2020 46,879 5,042 2021 45,348 5,294 2022 – 2026 209,331 22,509
Schedule of Health Care Cost Trend Rates	The following table shows the assumed health care cost trend rates for the PNM postretirement benefit plan: PNM Plan December 31, 2016 2015 Health care cost trend rate assumed for next year 6.8 % 7.0 % Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) 5.0 % 5.0 % Year that the rate reaches the ultimate trend rate 2024 2024
Schedule of Effect of One-Percentage-Point Change in Assumed Health Care Cost Trend Rates	The following table shows the impact of a one-percentage-point change in assumed health care cost trend rates: PNM Plan 1-Percentage- Point Increase 1-Percentage- Point Decrease (In thousands) Effect on total of service and interest cost $ 259 $ (226 ) Effect on APBO $ 1,575 $ (2,193 )
Schedule of Net Funded Status	For the executive retirement programs, the following table presents information about the PBO and funded status of the plans: PNM Plan TNMP Plan Year Ended Year Ended 2016 2015 2016 2015 (In thousands) PBO at beginning of year $ 16,105 $ 17,730 $ 794 $ 878 Service cost — — — — Interest cost 812 760 40 36 Actuarial (gain) loss 768 (908 ) 47 (26 ) Benefits paid (1,473 ) (1,477 ) (94 ) (94 ) PBO at end of year – funded status 16,212 16,105 787 794 Less current liability 1,510 1,519 93 93 Non-current liability $ 14,702 $ 14,586 $ 694 $ 701
Summary of Expenses for Other Retirement Plans	A summary of expenses for these other retirement plans is as follows: Year Ended December 31, 2016 2015 2014 (In thousands) PNMR 401(k) plan $ 17,762 $ 16,725 $ 16,703 Non-qualified plan $ 2,017 $ 1,436 $ 2,257 PNM 401(k) plan $ 13,397 $ 12,679 $ 12,745 Non-qualified plan $ 1,535 $ 1,090 $ 1,722 TNMP 401(k) plan $ 4,365 $ 4,046 $ 3,958 Non-qualified plan $ 482 $ 346 $ 535

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2016
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Summary of Awards	The following table provides additional information concerning stock options, and restricted stock activity including performance-based and market-based shares: Year Ended December 31, Restricted Stock 2016 2015 2014 Weighted-average grant date fair value $ 26.49 $ 20.34 $ 21.27 Total fair value of restricted shares that vested (in thousands) $ 5,079 $ 6,507 $ 4,933 Stock Options Weighted-average grant date fair value of options granted $ — $ — $ — Total fair value of options that vested (in thousands) $ — $ — $ — Total intrinsic value of options exercised (in thousands) $ 1,242 $ 2,350 $ 2,473 The following table summarizes the weighted-average assumptions used to determine the awards grant date fair value: Year Ended December 31, Restricted Shares and Performance-Based Shares 2016 2015 2014 Expected quarterly dividends per share $ 0.2200 $ 0.2000 $ 0.1850 Risk-free interest rate 0.94 % 0.92 % 0.62 % Market-Based Shares Dividend yield 2.74 % 2.87 % 2.82 % Expected volatility 20.44 % 18.73 % 25.11 % Risk-free interest rate 0.97 % 1.00 % 0.64 % The following table summarizes activity in restricted stock awards, including performance-based and market-based shares, and stock options: Restricted Stock Stock Options Shares Weighted-Average Grant Date Fair Value Shares Weighted Average Exercise Price Outstanding at December 31, 2015 245,094 $ 24.81 569,342 $ 19.35 Granted 190,276 $ 26.49 — $ — Exercised (216,340 ) $ 23.47 (253,268 ) $ 27.75 Forfeited (714 ) $ 29.54 (2,000 ) $ 12.22 Expired — — (8,200 ) $ 24.85 Outstanding at December 31, 2016 218,316 $ 27.59 305,874 $ 12.29

Construction Program and Join44

Construction Program and Jointly-Owned Electric Generating Plants (Tables)	12 Months Ended
	Dec. 31, 2016
Construction Program and Jointly-Owned Electric Generating Plants [Abstract]
Summary of Interests and Investments in Jointly-Owned Generating Facilities	At December 31, 2016 , PNM’s interests and investments in jointly-owned generating facilities are: Station (Fuel Type) Plant in Service Accumulated Depreciation (1) Construction Work in Progress Composite Interest (In thousands) SJGS (Coal) (2) $ 1,082,537 $ (445,597 ) $ 4,406 46.30 % PVNGS (Nuclear) (3) $ 797,793 $ (334,887 ) $ 38,946 10.20 % Four Corners Units 4 and 5 (Coal) $ 188,026 $ (103,584 ) $ 52,869 13.00 % Luna (Gas) $ 69,678 $ (25,386 ) $ 259 33.33 % (1) Includes cost of removal. (2) As discussed in Note 16, the NMPRC has approved the shutdown of SJGS Units 2 and 3 as of December 31, 2017. At December 31, 2016, PNM’s carrying value for its current ownership share of SJGS Units 2 and 3 included plant in service of $471.8 million and accumulated depreciation and amortization (including cost of removal) of $203.9 million for a net undepreciated net book value of $267.9 million , which amounts are included in the table above. At December 31, 2015, PNM recorded a regulatory disallowance of $127.6 million representing its estimate of the portion of the December 31, 2017 net book value of SJGS Units 2 and 3 that will not be recovered from ratepayers, which is reflected as a reduction of plant in service on the Consolidated Balance Sheets. (3) Includes interest in PVNGS Unit 3 , interest in common facilities for all PVNGS units, and owned interests in PVNGS Units 1 and 2 .
Summary of Budgeted Construction Expenditures	An unaudited summary of the budgeted construction expenditures, including expenditures for jointly-owned projects, and nuclear fuel, is as follows: 2017 2018 2019 2020 2021 Total (In millions) PNM $ 308.1 $ 231.0 $ 282.2 $ 252.5 $ 190.7 $ 1,264.5 TNMP 151.0 134.3 137.1 136.2 126.2 684.8 Corporate and Other 58.2 29.7 15.3 15.2 15.4 133.8 Total PNMR $ 517.3 $ 395.0 $ 434.6 $ 403.9 $ 332.3 $ 2,083.1

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2016
Asset Retirement Obligation Disclosure [Abstract]
Reconciliation of Asset Retirement Obligations	A reconciliation of the ARO liability is as follows: PNMR PNM TNMP (In thousands) Liability at December 31, 2013 $ 96,135 $ 95,225 $ 782 Liabilities incurred — — — Liabilities settled — — — Accretion expense 7,984 7,906 66 Revisions to estimated cash flows 51 51 — Liability at December 31, 2014 104,170 103,182 848 Liabilities incurred — — — Liabilities settled (730 ) (506 ) (224 ) Accretion expense 8,625 8,543 71 Revisions to estimated cash flows (1) (170 ) (170 ) — Liability at December 31, 2015 111,895 111,049 695 Liabilities incurred — — — Liabilities settled (14 ) (14 ) — Accretion expense 9,170 9,098 59 Revisions to estimated cash flows (2) 6,468 6,468 — Liability at December 31, 2016 $ 127,519 $ 126,601 $ 754 (1) PNM has an ARO for Four Corners that includes the obligations for decommissioning of that facility. In 2015, a new decommissioning study for Four Corners was implemented reflecting updated cash flow estimates. The new study resulted in an increase of $1.0 million to the ARO. In addition, a new decommissioning study for SJGS was implemented in 2015, resulting in a $1.2 million decrease to the ARO. (2) PNM has an ARO for PVNGS that includes obligations for nuclear decommissioning of that facility. In 2016, a new decommissioning study for PVNGS was implemented reflecting updated cash flow estimates. The new study resulted in an increase of $6.1 million to the ARO. In addition, an adjustment for SJGS related to the 2015 decommissioning study was implemented in 2016, resulting in a $0.3 million increase to the ARO.

Regulatory and Rate Matters Reg

Regulatory and Rate Matters Regulatory and Rate Matters (Tables)	12 Months Ended
	Dec. 31, 2016
Regulated Operations [Abstract]
Schedule of Rate Increases for Transmission Costs	TNMP recovers the costs of its energy efficiency programs through an energy efficiency cost recovery factor, which includes projected program costs, under or over collected costs from prior years, rate case expenses, and performance bonuses (if the programs exceed mandated savings goals). The following sets forth TNMP’s energy efficiency cost recovery factor increases: Effective Date Aggregate Collection Amount Performance Bonus (In millions) March 1, 2014 $ 5.6 $ 0.7 March 1, 2015 5.7 1.5 March 1, 2016 6.0 0.7 March 1, 2017 6.0 0.8 TNMP can update its transmission rates twice per year to reflect changes in its invested capital. 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) March 13, 2014 $ 18.2 $ 2.9 September 8, 2014 25.2 4.2 March 16, 2015 27.1 4.4 September 10, 2015 7.0 1.4 March 23, 2016 25.8 4.3 September 8, 2016 9.5 1.8

Accumulated Other Comprehensi47

Accumulated Other Comprehensive Income (Loss) (Tables)	12 Months Ended
	Dec. 31, 2016
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Schedule of Accumulated Other Comprehensive Income (Loss)	Information regarding AOCI is as follows: Accumulated Other Comprehensive Income (Loss) PNM TNMP PNMR Unrealized Gains on Available-for-Sale Securities Pension Liability Adjustment Total Fair Value Adjustment for Cash Flow Hedges Fair Value Adjustment for Cash Flow Hedges Total (In thousands) Balance at December 31, 2013 $ 25,748 $ (83,625 ) $ (57,877 ) $ (263 ) $ — $ (58,140 ) Amounts reclassified from AOCI (pre-tax) (13,862 ) 5,152 (8,710 ) 558 — (8,152 ) Income tax impact of amounts reclassified 5,461 (2,032 ) 3,429 (195 ) — 3,234 Other OCI changes (pre-tax) 17,473 (15,282 ) 2,191 (153 ) — 2,038 Income tax impact of other OCI changes (6,812 ) 6,024 (788 ) 53 — (735 ) Net after-tax change 2,260 (6,138 ) (3,878 ) 263 — (3,615 ) Balance at December 31, 2014 28,008 (89,763 ) (61,755 ) — — (61,755 ) Amounts reclassified from AOCI (pre-tax) (28,531 ) 5,952 (22,579 ) — — (22,579 ) Income tax impact of amounts reclassified 11,181 (2,332 ) 8,849 — — 8,849 Other OCI changes (pre-tax) 10,998 (4,405 ) 6,593 — 72 6,665 Income tax impact of other OCI changes (4,310 ) 1,726 (2,584 ) — (28 ) (2,612 ) Net after-tax change (10,662 ) 941 (9,721 ) — 44 (9,677 ) Balance at December 31, 2015 17,346 (88,822 ) (71,476 ) — 44 (71,432 ) Amounts reclassified from AOCI (pre-tax) (22,139 ) 5,504 (16,635 ) — 764 (15,871 ) Income tax impact of amounts reclassified 8,639 (2,148 ) 6,491 — (298 ) 6,193 Other OCI changes (pre-tax) 778 (18,501 ) (17,723 ) — (874 ) (18,597 ) Income tax impact of other OCI changes (304 ) 7,219 6,915 — 341 7,256 Net after-tax change (13,026 ) (7,926 ) (20,952 ) — (67 ) (21,019 ) Balance at December 31, 2016 $ 4,320 $ (96,748 ) $ (92,428 ) $ — $ (23 ) $ (92,451 )

Quarterly Operating Results (48

Quarterly Operating Results (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2016
Quarterly Financial Data [Abstract]
Schedule of Quarterly Financial Information	Unaudited operating results by quarters for 2016 and 2015 are presented below. In the opinion of management of the Company, all adjustments (consisting of normal recurring accruals) necessary for a fair statement of the results of operations for such periods have been included. Quarter Ended March 31 June 30 September 30 December 31 (In thousands, except per share amounts) PNMR 2016 Operating revenues $ 310,961 $ 315,391 $ 400,374 $ 336,225 Operating income 41,508 64,822 108,071 63,584 Net earnings 13,965 30,952 58,556 28,423 Net earnings attributable to PNMR 10,546 27,076 54,418 24,809 Net Earnings Attributable to PNMR per Common Share: Basic 0.13 0.34 0.68 0.32 Diluted 0.13 0.34 0.68 0.31 2015 Operating revenues $ 332,868 $ 352,887 $ 417,433 $ 335,894 Operating income (loss) 49,569 72,414 121,505 (119,138 ) (1) Net earnings (loss) 17,852 35,655 64,855 (87,284 ) Net earnings attributable (loss) to PNMR 14,340 31,673 61,045 (91,418 ) Net Earnings (Loss) Attributable to PNMR per Common Share: Basic 0.18 0.40 0.77 (1.15 ) Diluted 0.18 0.40 0.76 (1.15 ) PNM 2016 Operating revenues $ 235,606 $ 233,346 $ 311,276 $ 255,685 Operating income 23,297 41,760 80,057 42,976 Net earnings 7,561 19,793 44,990 19,594 Net earnings attributable to PNM 4,274 16,049 40,984 16,112 2015 Operating revenues $ 261,940 $ 275,450 $ 333,437 $ 260,368 Operating income (loss) 31,655 47,179 93,710 (139,164 ) Net earnings (loss) 13,502 25,363 53,056 (92,245 ) Net earnings (loss) attributable to PNM 10,122 21,513 49,378 (96,247 ) TNMP 2016 Operating revenues $ 75,355 $ 82,045 $ 89,098 $ 80,540 Operating income 18,554 23,375 28,359 21,353 Net earnings 7,456 10,508 13,853 9,855 2015 Operating revenues $ 70,928 $ 77,437 $ 83,996 $ 75,526 Operating income 17,931 24,729 27,667 19,706 Net earnings 7,694 11,865 13,689 8,715 (1) Includes an expense of $165.7 million related to the BART determination for SJGS discussed in Note 16.

Summary of the Business and S49

Summary of the Business and Significant Accounting Policies - Narrative (Details)	12 Months Ended
	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Jan. 01, 2017USD ($)	Dec. 31, 1986lease
Accounting Policies Disclosures [Line Items]
Payment defaults	$ 0
Unrealized gains, net of income taxes, recorded in AOCI	3,800,000
Allowance for equity funds used during construction	$ 4,949,000	$ 10,430,000	$ 5,563,000
Weighted average borrowing rate	6.10%	6.60%	6.60%
Interest costs incurred, capitalized	$ 1,800,000	$ 1,500,000	$ 1,600,000
Subsequent Event [Member] | Accounting Standards Update 2016-09 [Member]
Accounting Policies Disclosures [Line Items]
Reduction of accumulated deferred income tax liabilities				$ 8,400,000
Subsequent Event [Member] | Accounting Standards Update 2016-09 [Member] | Retained Earnings [Member]
Accounting Policies Disclosures [Line Items]
Increase in retained earnings				$ 8,400,000
Public Service Company of New Mexico [Member]
Accounting Policies Disclosures [Line Items]
Allowance for funds used during construction, capitalized interest	5,300,000	7,800,000	4,200,000
Allowance for equity funds used during construction	4,163,000	10,430,000	5,563,000
Interest costs incurred, capitalized	800,000	800,000	1,100,000
Impairment losses on securities held in the NDT	$ 13,900,000	10,400,000	4,800,000
Public Service Company of New Mexico [Member] | 10.3% Lessor Notes [Member]
Accounting Policies Disclosures [Line Items]
Notes receivable, stated percentage rate	10.30%
Public Service Company of New Mexico [Member] | 10.15% Lessor Notes [Member]
Accounting Policies Disclosures [Line Items]
Notes receivable, stated percentage rate	10.15%
Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station [Member]
Accounting Policies Disclosures [Line Items]
Number of operating leases | lease					11
Texas-New Mexico Power Company [Member]
Accounting Policies Disclosures [Line Items]
Allowance for funds used during construction, capitalized interest	$ 900,000	500,000	500,000
Allowance for equity funds used during construction	800,000	0	0
Interest costs incurred, capitalized	$ 100,000	$ 100,000	$ 100,000

Summary of the Business and S50

Summary of the Business and Significant Accounting Policies - Inventories/Depreciation and Amortization (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Public Utilities, Inventory [Line Items]
Inventory	$ 73,027	$ 67,386
Coal [Member]
Public Utilities, Inventory [Line Items]
Inventory	19,940	18,356
Materials and supplies [Member]
Public Utilities, Inventory [Line Items]
Inventory	53,087	49,030
Public Service Company of New Mexico [Member]
Public Utilities, Inventory [Line Items]
Inventory	64,401	60,477
Public Service Company of New Mexico [Member] | Coal [Member]
Public Utilities, Inventory [Line Items]
Inventory	19,940	18,356
Public Service Company of New Mexico [Member] | Materials and supplies [Member]
Public Utilities, Inventory [Line Items]
Inventory	$ 44,461	$ 42,121
Public Service Company of New Mexico [Member] | Electric plant [Member]
Public Utilities, Inventory [Line Items]
Depreciation average rates used	2.33%	2.27%	2.26%
Public Service Company of New Mexico [Member] | Common, intangible, and general plant [Member]
Public Utilities, Inventory [Line Items]
Depreciation average rates used	5.40%	4.66%	4.64%
Texas-New Mexico Power Company [Member]
Public Utilities, Inventory [Line Items]
Depreciation average rates used	3.66%	3.65%	3.59%
Inventory	$ 8,626	$ 6,909
Texas-New Mexico Power Company [Member] | Coal [Member]
Public Utilities, Inventory [Line Items]
Inventory	0	0
Texas-New Mexico Power Company [Member] | Materials and supplies [Member]
Public Utilities, Inventory [Line Items]
Inventory	$ 8,626	$ 6,909

Segment Information - Schedule

Segment Information - Schedule (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Segment Reporting Information [Line Items]
Electric Operating Revenues	$ 336,225	$ 400,374	$ 315,391	$ 310,961	$ 335,894	$ 417,433	$ 352,887	$ 332,868	$ 1,362,951	$ 1,439,082	$ 1,435,853
Cost of energy									380,596	464,649	471,556
Utility margin									982,355	974,433	964,297
Other operating expenses									495,260	664,164	491,966
Depreciation and amortization									209,110	185,919	172,634
Operating income	63,584	108,071	64,822	41,508	(119,138)	121,505	72,414	49,569	277,985	124,350	299,697
Interest income									22,293	6,498	8,483
Other income (deductions)									23,529	30,165	12,094
Interest charges									(128,633)	(114,860)	(119,627)
Earnings before Income Taxes									195,174	46,153	200,647
Income taxes (benefit)									63,278	15,075	69,738
Net Earnings	28,423	$ 58,556	$ 30,952	$ 13,965	(87,284)	$ 64,855	$ 35,655	$ 17,852	131,896	31,078	130,909
Valencia non-controlling interest									(14,519)	(14,910)	(14,127)
Subsidiary preferred stock dividends									(528)	(528)	(528)
Segment earnings (loss) attributable to PNMR									116,849	15,640	116,254
Total Assets	6,471,080				6,009,328				6,471,080	6,009,328	5,790,237
Goodwill	278,297				278,297				278,297	278,297	278,297
PNM [Member]
Segment Reporting Information [Line Items]
Electric Operating Revenues									1,035,913	1,131,195	1,147,914
Cost of energy									299,714	391,131	403,626
Utility margin									736,199	740,064	744,288
Other operating expenses									414,662	590,967	422,051
Depreciation and amortization									133,447	115,717	109,524
Operating income									188,090	33,380	212,713
Interest income									10,173	6,574	8,557
Other income (deductions)									22,066	26,914	12,258
Interest charges									(87,469)	(79,950)	(79,442)
Earnings before Income Taxes									132,860	(13,082)	154,086
Income taxes (benefit)									40,922	(12,758)	52,633
Net Earnings									91,938	(324)	101,453
Valencia non-controlling interest									(14,519)	(14,910)	(14,127)
Subsidiary preferred stock dividends									(528)	(528)	(528)
Segment earnings (loss) attributable to PNMR									76,891	(15,762)	86,798
Total Assets	4,867,546				4,599,344				4,867,546	4,599,344	4,453,114
Goodwill	51,632				51,632				51,632	51,632	51,632
TNMP [Member]
Segment Reporting Information [Line Items]
Electric Operating Revenues									327,038	307,887	287,939
Cost of energy									80,882	73,518	67,930
Utility margin									246,156	234,369	220,009
Other operating expenses									93,389	88,051	84,365
Depreciation and amortization									61,126	56,285	50,056
Operating income									91,641	90,033	85,588
Interest income									0	0	0
Other income (deductions)									3,202	3,736	2,138
Interest charges									(29,335)	(27,681)	(27,396)
Earnings before Income Taxes									65,508	66,088	60,330
Income taxes (benefit)									23,836	24,125	22,523
Net Earnings									41,672	41,963	37,807
Valencia non-controlling interest									0	0	0
Subsidiary preferred stock dividends									0	0	0
Segment earnings (loss) attributable to PNMR									41,672	41,963	37,807
Total Assets	1,383,223				1,297,139				1,383,223	1,297,139	1,229,417
Goodwill	226,665				226,665				226,665	226,665	226,665
Corporate and Other [Member]
Segment Reporting Information [Line Items]
Electric Operating Revenues									0	0	0
Cost of energy									0	0	0
Utility margin									0	0	0
Other operating expenses									(12,791)	(14,854)	(14,450)
Depreciation and amortization									14,537	13,917	13,054
Operating income									(1,746)	937	1,396
Interest income									12,120	(76)	(74)
Other income (deductions)									(1,739)	(485)	(2,302)
Interest charges									(11,829)	(7,229)	(12,789)
Earnings before Income Taxes									(3,194)	(6,853)	(13,769)
Income taxes (benefit)									(1,480)	3,708	(5,418)
Net Earnings									(1,714)	(10,561)	(8,351)
Valencia non-controlling interest									0	0	0
Subsidiary preferred stock dividends									0	0	0
Segment earnings (loss) attributable to PNMR									(1,714)	(10,561)	(8,351)
Total Assets	220,311				112,845				220,311	112,845	107,706
Goodwill	$ 0				$ 0				$ 0	$ 0	$ 0

Segment Information - Major Cus

Segment Information - Major Customers (Details) - Electric operating revenues [Member] - customer	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
PNMR and PNM [Member]
Concentration Risk [Line Items]
Number of customers that make up more than 10% of total revenue	0
PNMR and PNM [Member] | Maximum [Member]
Concentration Risk [Line Items]
Operating revenues from continuing operations	10.00%
Texas-New Mexico Power Company [Member]
Concentration Risk [Line Items]
Number of customers that make up more than 10% of total revenue	3
Texas-New Mexico Power Company [Member] | REP A [Member]
Concentration Risk [Line Items]
Operating revenues from continuing operations	16.00%	16.00%	15.00%
Texas-New Mexico Power Company [Member] | REP B [Member]
Concentration Risk [Line Items]
Operating revenues from continuing operations	11.00%	13.00%	15.00%
Texas-New Mexico Power Company [Member] | REP C [Member]
Concentration Risk [Line Items]
Operating revenues from continuing operations	11.00%	11.00%	11.00%

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Service billings [Member] | PNMR to PNM [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	$ 94,606	$ 90,827	$ 86,871
Service billings [Member] | PNMR to TNMP [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	28,907	28,109	28,349
Service billings [Member] | PNM to TNMP [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	427	554	524
Service billings [Member] | TNMP to PNMR [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	66	41	31
Income tax sharing payments [Member] | PNMR to PNM [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	0	1,450	0
Income tax sharing payments [Member] | PNMR to TNMP [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	0	0	0
Income tax sharing payments [Member] | TNMP to PNMR [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	0	0	0
Interest payments [Member] | PNMR to PNM [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	150	110	102
Interest payments [Member] | TNMP to PNMR [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	132	276	309
Interest payments [Member] | PNM to PNMR [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	$ 11	$ 54	$ 65

Regulatory Assets and Liabili54

Regulatory Assets and Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Regulatory Assets
Current	$ 3,855	$ 1,070
Non-Current	501,223	470,664
Regulatory Liabilities
Current	(3,609)	(15,591)
Non-Current	(455,649)	(467,413)
Public Service Company of New Mexico [Member]
Regulatory Assets
Current	3,442	0
Non-Current	365,413	342,910
Total regulatory assets	368,855	342,910
Regulatory Liabilities
Current	(3,517)	(15,591)
Non-Current	(423,701)	(434,863)
Total regulatory liabilities	(427,218)	(450,454)
Public Service Company of New Mexico [Member] | FPPAC [Member]
Regulatory Liabilities
Current	0	(11,410)
Public Service Company of New Mexico [Member] | Renewable Energy Rider [Member]
Regulatory Liabilities
Current	(3,411)	(2,584)
Public Service Company of New Mexico [Member] | Other Current [Member]
Regulatory Liabilities
Current	(106)	(1,597)
Public Service Company of New Mexico [Member] | Cost of removal [Member]
Regulatory Liabilities
Non-Current	(297,087)	(284,015)
Public Service Company of New Mexico [Member] | Deferred income taxes [Member]
Regulatory Liabilities
Non-Current	(62,920)	(77,502)
Public Service Company of New Mexico [Member] | AROs [Member]
Regulatory Liabilities
Non-Current	(30,621)	(33,747)
Public Service Company of New Mexico [Member] | Renewable energy [Member]
Regulatory Liabilities
Non-Current	(22,540)	(23,697)
Public Service Company of New Mexico [Member] | Nuclear spent fuel reimbursements [Member]
Regulatory Liabilities
Non-Current	(8,875)	(9,214)
Public Service Company of New Mexico [Member] | Pension and OPEB [Member]
Regulatory Liabilities
Non-Current	0	0
Public Service Company of New Mexico [Member] | Other [Member]
Regulatory Liabilities
Non-Current	(1,658)	(6,688)
Public Service Company of New Mexico [Member] | FPPAC [Member]
Regulatory Assets
Current	1,451	0
Public Service Company of New Mexico [Member] | Energy Efficiency [Member]
Regulatory Assets
Current	1,991	0
Public Service Company of New Mexico [Member] | Energy efficiency costs [Member]
Regulatory Assets
Current	0	0
Public Service Company of New Mexico [Member] | CTC, including carrying charges[Member]
Regulatory Assets
Non-Current	0	0
Public Service Company of New Mexico [Member] | Coal mine reclamation costs [Member]
Regulatory Assets
Non-Current	22,383	28,303
Public Service Company of New Mexico [Member] | Deferred income taxes [Member]
Regulatory Assets
Non-Current	62,918	66,990
Public Service Company of New Mexico [Member] | Loss on reacquired debt [Member]
Regulatory Assets
Non-Current	24,404	23,627
Public Service Company of New Mexico [Member] | Pension and OPEB [Member]
Regulatory Assets
Non-Current	249,286	218,743
Public Service Company of New Mexico [Member] | AMS surcharge [Member]
Regulatory Assets
Non-Current	0	0
Public Service Company of New Mexico [Member] | AMS retirement costs [Member]
Regulatory Assets
Non-Current	0	0
Public Service Company of New Mexico [Member] | Other [Member]
Regulatory Assets
Non-Current	6,422	5,247
Texas-New Mexico Power Company [Member]
Regulatory Assets
Current	413	1,070
Non-Current	135,810	127,754
Total regulatory assets	136,223	128,824
Regulatory Liabilities
Current	(92)	0
Non-Current	(31,948)	(32,550)
Total regulatory liabilities	(32,040)	(32,550)
Texas-New Mexico Power Company [Member] | FPPAC [Member]
Regulatory Liabilities
Current	0	0
Texas-New Mexico Power Company [Member] | Renewable Energy Rider [Member]
Regulatory Liabilities
Current	0	0
Texas-New Mexico Power Company [Member] | Other Current [Member]
Regulatory Liabilities
Current	(92)	0
Texas-New Mexico Power Company [Member] | Cost of removal [Member]
Regulatory Liabilities
Non-Current	(26,900)	(26,859)
Texas-New Mexico Power Company [Member] | Deferred income taxes [Member]
Regulatory Liabilities
Non-Current	(2,644)	(3,283)
Texas-New Mexico Power Company [Member] | AROs [Member]
Regulatory Liabilities
Non-Current	0	0
Texas-New Mexico Power Company [Member] | Renewable energy [Member]
Regulatory Liabilities
Non-Current	0	0
Texas-New Mexico Power Company [Member] | Nuclear spent fuel reimbursements [Member]
Regulatory Liabilities
Non-Current	0	0
Texas-New Mexico Power Company [Member] | Pension and OPEB [Member]
Regulatory Liabilities
Non-Current	(1,955)	(1,913)
Texas-New Mexico Power Company [Member] | Other [Member]
Regulatory Liabilities
Non-Current	(449)	(495)
Texas-New Mexico Power Company [Member] | FPPAC [Member]
Regulatory Assets
Current	0	0
Texas-New Mexico Power Company [Member] | Energy Efficiency [Member]
Regulatory Assets
Current	413	629
Texas-New Mexico Power Company [Member] | Energy efficiency costs [Member]
Regulatory Assets
Current	0	441
Texas-New Mexico Power Company [Member] | CTC, including carrying charges[Member]
Regulatory Assets
Non-Current	36,328	46,147
Texas-New Mexico Power Company [Member] | Coal mine reclamation costs [Member]
Regulatory Assets
Non-Current	0	0
Texas-New Mexico Power Company [Member] | Deferred income taxes [Member]
Regulatory Assets
Non-Current	9,932	10,244
Texas-New Mexico Power Company [Member] | Loss on reacquired debt [Member]
Regulatory Assets
Non-Current	34,107	35,405
Texas-New Mexico Power Company [Member] | Pension and OPEB [Member]
Regulatory Assets
Non-Current	27,661	23,356
Texas-New Mexico Power Company [Member] | AMS surcharge [Member]
Regulatory Assets
Non-Current	14,669	1,673
Texas-New Mexico Power Company [Member] | AMS retirement costs [Member]
Regulatory Assets
Non-Current	11,086	8,549
Texas-New Mexico Power Company [Member] | Other [Member]
Regulatory Assets
Non-Current	$ 2,027	$ 2,380

Stockholders' Equity (Details)

Stockholders' Equity (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Line of Credit [Member]
Class of Stock [Line Items]
Debt-to-capital ratio (not more than)	65.00%
Public Service Company of New Mexico [Member]
Class of Stock [Line Items]
Equity contribution from parent	$ 28,142	$ 175,000	$ 0
Preferred stock, dividend rate	4.58%
Preferred stock, redemption percent	102.00%
Preferred stock outstanding (in shares)	115,293	115,293
Preferred stock, cumulative shares authorized (in shares)	10,000,000	10,000,000
Public Service Company of New Mexico [Member] | Maximum [Member]
Class of Stock [Line Items]
Requirement to obtain approval to transfer more than a percentage of PNM's assets	5.00%
Public Service Company of New Mexico [Member] | Affiliated Entity [Member]
Class of Stock [Line Items]
Cash dividends paid to parent company by consolidated subsidiaries	$ 4,100	$ 94,400	30,300
Texas-New Mexico Power Company [Member]
Class of Stock [Line Items]
Equity contribution from parent	$ 50,000	0	0
Preferred stock, cumulative shares authorized (in shares)	1,000,000
Texas-New Mexico Power Company [Member] | Line of Credit [Member]
Class of Stock [Line Items]
Debt-to-capital ratio (not more than)	65.00%
Texas-New Mexico Power Company [Member] | Affiliated Entity [Member]
Class of Stock [Line Items]
Cash dividends paid to parent company by consolidated subsidiaries	$ 31,800	$ 33,200	$ 16,300
PNMR and TNMP [Member]
Class of Stock [Line Items]
Preferred stock outstanding (in shares)	0

Financing - Activities, PNM and

Financing - Activities, PNM and TNMP (Details)

Feb. 01, 2017USD ($)

Nov. 01, 2016USD ($)

Feb. 01, 2016USD ($)

Dec. 21, 2015USD ($)

Aug. 11, 2015USD ($)

May 08, 2015USD ($)

Dec. 31, 2014USD ($)

Jun. 27, 2014USD ($)

Mar. 05, 2014USD ($)

Jun. 21, 2016USD ($)

Dec. 31, 2016USD ($)

Dec. 31, 2015USD ($)

Dec. 31, 2014USD ($)

Feb. 21, 2017USD ($)

Dec. 21, 2016USD ($)loan

Oct. 21, 2016USD ($)

Sep. 27, 2016USD ($)

May 20, 2016USD ($)

Dec. 17, 2015USD ($)

Sep. 30, 2015

Jun. 01, 2015USD ($)

Mar. 09, 2015USD ($)

Dec. 22, 2014USD ($)

Jan. 01, 2014USD ($)

Dec. 09, 2013USD ($)

Debt Instrument [Line Items]

Outstanding amount

$ 287,100,000

$ 250,600,000

Amount outstanding

100,000,000

50,000,000

$ 0

Fixed interest rate

1.927%

Payment of debt

303,793,000

333,066,000

125,000,000

PNMR Term Loan Agreement [Member]

Debt Instrument [Line Items]

Outstanding amount

0

150,000,000

PNMR 2016 One-Year Term Loan and PNMR 2016 Two-Year Term Loan [Member]

Debt Instrument [Line Items]

Number of loan agreements (in loans) | loan

2

PNMR 2016 One Year Term Loan [Member]

Debt Instrument [Line Items]

Outstanding amount

$ 100,000,000

$ 100,000,000

Variable interest rate

1.60%

PNMR 2016 Two Year Term Loan [Member]

Debt Instrument [Line Items]

Loan entered into

100,000,000

Variable interest rate

1.69%

Level 2 [Member] | Cash Flow Hedging [Member]

Debt Instrument [Line Items]

Fair value gain (loss, less than)

$ (100,000)

100,000

Notes Payable to Banks [Member] | PNMR Term Loan Agreement [Member]

Debt Instrument [Line Items]

Outstanding amount

$ 100,000,000

Amount outstanding

$ 150,000,000

Term Loan and Other Outstanding Debt [Member]

Debt Instrument [Line Items]

Repayments of debt

$ 75,000,000

NM Capital [Member] | San Juan Generating Station [Member] | Coal Supply [Member]

Debt Instrument [Line Items]

Payments to fund long-term loans to unaffiliated third party

$ 125,000,000

PNMR [Member] | PNMR 2016 Two Year Term Loan [Member]

Debt Instrument [Line Items]

Loan entered into

100,000,000

0

Public Service Company of New Mexico [Member]

Debt Instrument [Line Items]

Outstanding amount

61,000,000

0

Payment of debt

$ 271,000,000

214,300,000

75,000,000

Public Service Company of New Mexico [Member] | NMPRC [Member]

Debt Instrument [Line Items]

Requirement to obtain approval for any financing transaction, period of time (more than)

18 months

Texas-New Mexico Power Company [Member]

Debt Instrument [Line Items]

Outstanding amount

$ 0

59,000,000

Payment of debt

$ 0

0

$ 50,000,000

Repayments of debt

$ 30,000,000

Line of Credit [Member]

Debt Instrument [Line Items]

Debt-to-capital ratios (less than or equal to)

65.00%

Line of Credit [Member] | Texas-New Mexico Power Company [Member]

Debt Instrument [Line Items]

Debt-to-capital ratios (less than or equal to)

65.00%

PNMR 2015 Term Loan Agreement [Member]

Debt Instrument [Line Items]

Loan entered into

$ 150,000,000

$ 150,000,000

Variable interest rate

1.55%

Unsecured Debt [Member] | Senior unsecured notes, 9.25% due 2015 [Member]

Debt Instrument [Line Items]

Aggregate outstanding principal amount

$ 118,800,000

Stated percentage

9.25%

Unsecured Debt [Member] | Public Service Company of New Mexico [Member]

Debt Instrument [Line Items]

Shelf registration statement, capacity of issuance (up to)

$ 250,000,000

Unsecured Debt [Member] | Public Service Company of New Mexico [Member] | 3.85% due 2025 [Member]

Debt Instrument [Line Items]

Aggregate outstanding principal amount

$ 250,000,000

$ 250,000,000

250,000,000

Stated percentage

3.85%

3.85%

BTMU Term Loan Agreement [Member] | NM Capital [Member]

Debt Instrument [Line Items]

Loan entered into

$ 125,000,000

$ 92,200,000

Stated percentage

3.64%

Estimated principal payments

$ 42,000,000

BTMU Term Loan Agreement [Member] | NM Capital [Member] | Subsequent Event [Member]

Debt Instrument [Line Items]

Loan entered into

$ 82,800,000

Payment of debt

$ 9,400,000

BTMU Term Loan Agreement [Member] | NM Capital [Member] | Maximum [Member]

Debt Instrument [Line Items]

Debt-to-capital ratio

65.00%

BTMU Term Loan Agreement [Member] | NM Capital [Member] | Minimum [Member]

Debt Instrument [Line Items]

Long-term debt, required quarterly payment

$ 5,000,000

Letter of Credit [Member] | PNMR [Member] | Letter or credit, 30 mil JP Morgan [Member]

Debt Instrument [Line Items]

Aggregate principal amount

$ 30,300,000

PNM 2014 Term Loan Agreement [Member] | Public Service Company of New Mexico [Member]

Debt Instrument [Line Items]

Loan entered into

$ 175,000,000

Repayments of debt

$ 175,000,000

PNM 2014 Multi-Draw Term Loan Agreement [Member] | Public Service Company of New Mexico [Member]

Debt Instrument [Line Items]

Loan entered into

$ 125,000,000

Repayments of debt

$ 125,000,000

Outstanding borrowings

$ 25,000,000

$ 100,000,000

Unsecured notes, Pollution control revenue bonds [Member] | Public Service Company of New Mexico [Member] | Senior unsecured note, PCRB Due 2043, at 4 percent [Member]

Debt Instrument [Line Items]

Aggregate outstanding principal amount

$ 39,300,000

Unsecured notes, Pollution control revenue bonds [Member] | Public Service Company of New Mexico [Member] | Senior unsecured note, PCRB Due 2043, at 2 point 4 percent [Member]

Debt Instrument [Line Items]

Aggregate outstanding principal amount

$ 39,300,000

Stated percentage

2.40%

PNM 2016 Term Loan Agreement [Member] | Public Service Company of New Mexico [Member]

Debt Instrument [Line Items]

Stated percentage

1.36%

Aggregate principal amount

$ 175,000,000

Pollution Control Bonds [Member] | Public Service Company of New Mexico [Member] | Pollution Control Revenue Bonds 1 Point 875 Percent, due 2021 [Member]

Debt Instrument [Line Items]

Stated percentage

1.875%

Aggregate principal amount

$ 146,000,000

Pollution Control Bonds [Member] | Public Service Company of New Mexico [Member] | Pollution Control Revenue Bonds 1 Point 875 Percent, due 2021, 2016 Series A [Member]

Debt Instrument [Line Items]

Aggregate principal amount

46,000,000

Pollution Control Bonds [Member] | Public Service Company of New Mexico [Member] | Pollution Control Revenue Bonds 1 Point 875 Percent, due 2021, 2016 Series B [Member]

Debt Instrument [Line Items]

Aggregate principal amount

$ 100,000,000

Pollution Control Revenue Bonds [Member] | Texas-New Mexico Power Company [Member] | First Mortgage Bonds Due 2024, Series 2014A, at 4.03% [Member]

Debt Instrument [Line Items]

Stated percentage

4.03%

Aggregate principal amount

$ 80,000,000

2011 Term Loan Agreement [Member] | Texas-New Mexico Power Company [Member]

Debt Instrument [Line Items]

Repayments of debt

$ 50,000,000

First Mortgage Bonds [Member] | Texas-New Mexico Power Company [Member] | First Mortgage Bonds Due 2024, Series 2014A, at 4.03% [Member]

Debt Instrument [Line Items]

Aggregate outstanding principal amount

$ 80,000,000

80,000,000

Stated percentage

4.03%

First Mortgage Bonds [Member] | Texas-New Mexico Power Company [Member] | First Mortgage Bonds 3 Point 53 Percent, due 2026, Series 2016A [Member]

Debt Instrument [Line Items]

Aggregate outstanding principal amount

$ 60,000,000

$ 0

Stated percentage

3.53%

3.53%

Aggregate principal amount

$ 60,000,000

Financing - Borrowing Arrangeme

Financing - Borrowing Arrangements Between PNMR and Its Subsidiaries and Short-term Debt (Details)	Nov. 01, 2020USD ($)	Feb. 21, 2017USD ($)	Dec. 31, 2016USD ($)	Dec. 21, 2016USD ($)	Nov. 30, 2016USD ($)	Dec. 31, 2015USD ($)	Jan. 08, 2014USD ($)bank
Short-term Debt [Line Items]
Short-term debt			$ 287,100,000			$ 250,600,000
Letters of credit outstanding			6,200,000
JPMorgan Chase Bank, N.A. [Member]
Short-term Debt [Line Items]
Letters of credit outstanding			30,300,000
PNMR Term Loan Agreement [Member]
Short-term Debt [Line Items]
Short-term debt			0			150,000,000
PNMR 2016 One Year Term Loan [Member]
Short-term Debt [Line Items]
Short-term debt			100,000,000	$ 100,000,000
PNMR Revolving Credit Facility [Member]
Short-term Debt [Line Items]
Financing capacity			300,000,000		$ 10,000,000
Short-term debt			126,100,000			41,600,000
PNMR Revolving Credit Facility [Member] | Scenario, Forecast [Member]
Short-term Debt [Line Items]
Financing capacity	$ 290,000,000
Subsequent Event [Member]
Short-term Debt [Line Items]
Invested cash		$ 1,500,000
Subsequent Event [Member] | PNMR Revolving Credit Facility [Member]
Short-term Debt [Line Items]
Available borrowing capacity		149,500,000
Subsequent Event [Member] | Revolving Credit Facility [Member]
Short-term Debt [Line Items]
Available borrowing capacity		607,600,000
Texas-New Mexico Power Company [Member]
Short-term Debt [Line Items]
Subsidiary loan agreements			4,600,000			11,800,000
Short-term debt			0			59,000,000
Letters of credit outstanding			100,000
Texas-New Mexico Power Company [Member] | TNMP Revolving Credit Facility [Member]
Short-term Debt [Line Items]
Financing capacity			75,000,000
Short-term debt			0			59,000,000
Texas-New Mexico Power Company [Member] | TNMP Revolving Credit Facility [Member] | First Mortgage Bonds Due 2019, Series 2009A, at 9.50% [Member]
Short-term Debt [Line Items]
Aggregate principal amount of bonds			75,000,000
Texas-New Mexico Power Company [Member] | Subsequent Event [Member]
Short-term Debt [Line Items]
Subsidiary loan agreements		7,400,000
Invested cash		0
Texas-New Mexico Power Company [Member] | Subsequent Event [Member] | TNMP Revolving Credit Facility [Member]
Short-term Debt [Line Items]
Available borrowing capacity		66,900,000
Public Service Company of New Mexico [Member]
Short-term Debt [Line Items]
Subsidiary loan agreements			0
Short-term debt			61,000,000			0
Letters of credit outstanding			$ 2,500,000
Public Service Company of New Mexico [Member] | New Mexico Revolving Credit Facility [Member]
Short-term Debt [Line Items]
Financing capacity							$ 50,000,000
Number of participating lenders (in banks) | bank							9
Public Service Company of New Mexico [Member] | Local Lines of Credit [Member]
Short-term Debt [Line Items]
Interest rates on outstanding borrowings			1.81%
Public Service Company of New Mexico [Member] | PNM Revolving Credit Facility [Member]
Short-term Debt [Line Items]
Financing capacity			$ 400,000,000		$ 40,000,000
Interest rates on outstanding borrowings			1.82%
Short-term debt			$ 35,000,000			0
Public Service Company of New Mexico [Member] | PNM Revolving Credit Facility [Member] | Scenario, Forecast [Member]
Short-term Debt [Line Items]
Financing capacity	$ 360,000,000
Public Service Company of New Mexico [Member] | New Mexico Revolving Credit Facility [Member]
Short-term Debt [Line Items]
Short-term debt			26,000,000			0
Public Service Company of New Mexico [Member] | Subsequent Event [Member]
Short-term Debt [Line Items]
Subsidiary loan agreements		0
Invested cash		0
Public Service Company of New Mexico [Member] | Subsequent Event [Member] | PNM Revolving Credit Facility [Member]
Short-term Debt [Line Items]
Available borrowing capacity		366,200,000
Public Service Company of New Mexico [Member] | Subsequent Event [Member] | New Mexico Revolving Credit Facility [Member]
Short-term Debt [Line Items]
Available borrowing capacity		$ 25,000,000
PNM Resources [Member]
Short-term Debt [Line Items]
Short-term debt			$ 226,100,000			$ 191,600,000
PNM Resources [Member] | PNMR Revolving Credit Facility [Member]
Short-term Debt [Line Items]
Interest rates on outstanding borrowings			1.98%
Maximum [Member]
Short-term Debt [Line Items]
Subsidiary loan agreements			$ 100,000,000

Financing - Long-term Debt (Det

Financing - Long-term Debt (Details) - USD ($)	Dec. 31, 2016	Dec. 21, 2016	Dec. 31, 2015	Dec. 17, 2015	Aug. 11, 2015
Debt Instrument [Line Items]
Total	$ 2,388,577,000		$ 2,086,370,000
Principal, Less current maturities	274,025,000		125,000,000
Long-term debt, excluding current maturities, gross	2,114,552,000		1,961,370,000
Unamortized Discounts, (Premiums), and Issuance Costs, net	(4,135,000)		(5,578,000)
Unamortized Discounts, (Premiums), and Issuance Costs, net, Less current maturities	677,000		21,000
Unamortized Discounts, (Premiums), and Issuance Costs, net, excluding current maturities	(4,812,000)		(5,599,000)
PNMR 2016 Two Year Term Loan [Member]
Debt Instrument [Line Items]
Long-term debt		$ 100,000,000
Public Service Company of New Mexico [Member]
Debt Instrument [Line Items]
Total	1,640,870,000		1,590,870,000
Principal, Less current maturities	232,000,000		125,000,000
Long-term debt, excluding current maturities, gross	1,408,870,000		1,465,870,000
Unamortized Discounts, (Premiums), and Issuance Costs, net	9,501,000		10,193,000
Unamortized Discounts, (Premiums), and Issuance Costs, net, Less current maturities	120,000		21,000
Unamortized Discounts, (Premiums), and Issuance Costs, net, excluding current maturities	$ 9,381,000		10,172,000
Public Service Company of New Mexico [Member] | Senior Unsecured Notes, Pollution Control Revenue Bonds [Member] | 4.875% due 2033 [Member]
Debt Instrument [Line Items]
Stated percentage	4.875%
Unsecured long-term debt, noncurrent	$ 0		146,000,000
Unamortized Discounts, (Premiums), and Issuance Costs, net	$ 0		721,000
Public Service Company of New Mexico [Member] | Senior Unsecured Notes, Pollution Control Revenue Bonds [Member] | 1.875% due 2033, mandatory tender at October 1, 2021 [Member]
Debt Instrument [Line Items]
Stated percentage	1.875%
Unsecured long-term debt, noncurrent	$ 146,000,000		0
Unamortized Discounts, (Premiums), and Issuance Costs, net	$ 1,807,000		0
Public Service Company of New Mexico [Member] | Senior Unsecured Notes, Pollution Control Revenue Bonds [Member] | 6.25% due 2038 [Member]
Debt Instrument [Line Items]
Stated percentage	6.25%
Unsecured long-term debt, noncurrent	$ 36,000,000		36,000,000
Unamortized Discounts, (Premiums), and Issuance Costs, net	$ 239,000		251,000
Public Service Company of New Mexico [Member] | Senior Unsecured Notes, Pollution Control Revenue Bonds [Member] | 4.75% due 2040, mandatory tender at June 1, 2017 [Member]
Debt Instrument [Line Items]
Stated percentage	4.75%
Unsecured long-term debt, noncurrent	$ 37,000,000		37,000,000
Unamortized Discounts, (Premiums), and Issuance Costs, net	$ 25,000		82,000
Public Service Company of New Mexico [Member] | Senior Unsecured Notes, Pollution Control Revenue Bonds [Member] | 5.20% due 2040, mandatory tender at June 1, 2020 [Member]
Debt Instrument [Line Items]
Stated percentage	5.20%
Unsecured long-term debt, noncurrent	$ 40,045,000		40,045,000
Unamortized Discounts, (Premiums), and Issuance Costs, net	$ 147,000		190,000
Public Service Company of New Mexico [Member] | Senior Unsecured Notes, Pollution Control Revenue Bonds [Member] | 5.90% due 2040 [Member]
Debt Instrument [Line Items]
Stated percentage	5.90%
Unsecured long-term debt, noncurrent	$ 255,000,000		255,000,000
Unamortized Discounts, (Premiums), and Issuance Costs, net	$ 2,131,000		2,222,000
Public Service Company of New Mexico [Member] | Senior Unsecured Notes, Pollution Control Revenue Bonds [Member] | 6.25% due 2040 [Member]
Debt Instrument [Line Items]
Stated percentage	6.25%
Unsecured long-term debt, noncurrent	$ 11,500,000		11,500,000
Unamortized Discounts, (Premiums), and Issuance Costs, net	$ 96,000		100,000
Public Service Company of New Mexico [Member] | Senior Unsecured Notes, Pollution Control Revenue Bonds [Member] | 2.54% due 2042, mandatory tender at June 1, 2017 [Member]
Debt Instrument [Line Items]
Stated percentage	2.54%
Unsecured long-term debt, noncurrent	$ 20,000,000		20,000,000
Unamortized Discounts, (Premiums), and Issuance Costs, net	$ 67,000		199,000
Public Service Company of New Mexico [Member] | Senior Unsecured Notes, Pollution Control Revenue Bonds [Member] | 2.40% due 2043, mandatory tender at June 1, 2020 [Member]
Debt Instrument [Line Items]
Stated percentage	2.40%
Unsecured long-term debt, noncurrent	$ 39,300,000		39,300,000
Unamortized Discounts, (Premiums), and Issuance Costs, net	$ 340,000		456,000
Public Service Company of New Mexico [Member] | Senior Unsecured Notes, Pollution Control Revenue Bonds [Member] | 5.20% due 2043, mandatory tender at June 1, 2020 [Member]
Debt Instrument [Line Items]
Stated percentage	5.20%
Unsecured long-term debt, noncurrent	$ 21,000,000		21,000,000
Unamortized Discounts, (Premiums), and Issuance Costs, net	$ 75,000		96,000
Public Service Company of New Mexico [Member] | Unsecured Debt [Member] | 7.95% due 2018 [Member]
Debt Instrument [Line Items]
Stated percentage	7.95%
Unsecured long-term debt, noncurrent	$ 350,000,000		350,000,000
Unamortized Discounts, (Premiums), and Issuance Costs, net	$ 995,000		1,718,000
Public Service Company of New Mexico [Member] | Unsecured Debt [Member] | 7.50% due 2018 [Member]
Debt Instrument [Line Items]
Stated percentage	7.50%
Unsecured long-term debt, noncurrent	$ 100,025,000		100,025,000
Unamortized Discounts, (Premiums), and Issuance Costs, net	$ 197,000		320,000
Public Service Company of New Mexico [Member] | Unsecured Debt [Member] | 5.35% due 2021 [Member]
Debt Instrument [Line Items]
Stated percentage	5.35%
Unsecured long-term debt, noncurrent	$ 160,000,000		160,000,000
Unamortized Discounts, (Premiums), and Issuance Costs, net	$ 780,000		943,000
Public Service Company of New Mexico [Member] | Unsecured Debt [Member] | 3.85% due 2025 [Member]
Debt Instrument [Line Items]
Stated percentage	3.85%				3.85%
Unsecured long-term debt, noncurrent	$ 250,000,000		250,000,000		$ 250,000,000
Unamortized Discounts, (Premiums), and Issuance Costs, net	2,574,000		2,874,000
Public Service Company of New Mexico [Member] | Unsecured Debt [Member] | PNM Multi-Draw Term Loan Agreement due 2016 [Member]
Debt Instrument [Line Items]
Long-term debt	0		125,000,000
Unamortized Discounts, (Premiums), and Issuance Costs, net	0		21,000
Public Service Company of New Mexico [Member] | Unsecured Debt [Member] | PNM 2016 Term Loan Agreement [Member]
Debt Instrument [Line Items]
Long-term debt	175,000,000		0
Unamortized Discounts, (Premiums), and Issuance Costs, net	28,000		0
Texas-New Mexico Power Company [Member]
Debt Instrument [Line Items]
Total	405,500,000		345,500,000
Principal, Less current maturities	0		0
Long-term debt, excluding current maturities, gross	405,500,000		345,500,000
Unamortized Discounts, (Premiums), and Issuance Costs, net	(15,375,000)		(15,911,000)
Unamortized Discounts, (Premiums), and Issuance Costs, net, Less current maturities	0		0
Unamortized Discounts, (Premiums), and Issuance Costs, net, excluding current maturities	$ (15,375,000)		(15,911,000)
Texas-New Mexico Power Company [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds, 9.50% due 2019, Series 2009A [Member]
Debt Instrument [Line Items]
Stated percentage	9.50%
Unsecured long-term debt, noncurrent	$ 172,302,000		172,302,000
Unamortized Discounts, (Premiums), and Issuance Costs, net	$ 1,857,000		2,682,000
Texas-New Mexico Power Company [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds, 6.95% due 2043, Series 2013A [Member]
Debt Instrument [Line Items]
Stated percentage	6.95%
Unsecured long-term debt, noncurrent	$ 93,198,000		93,198,000
Unamortized Discounts, (Premiums), and Issuance Costs, net	$ (18,773,000)		(19,490,000)
Texas-New Mexico Power Company [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds, 4.03% due 2024, Series 2014A [Member]
Debt Instrument [Line Items]
Stated percentage	4.03%
Unsecured long-term debt, noncurrent	$ 80,000,000		80,000,000
Unamortized Discounts, (Premiums), and Issuance Costs, net	$ 792,000		897,000
Texas-New Mexico Power Company [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds, 3.53% due 2026, Series 2016A [Member]
Debt Instrument [Line Items]
Stated percentage	3.53%			3.53%
Unsecured long-term debt, noncurrent	$ 60,000,000		0
Unamortized Discounts, (Premiums), and Issuance Costs, net	749,000		0
PNMR [Member]
Debt Instrument [Line Items]
Total	342,207,000		150,000,000
Principal, Less current maturities	42,025,000		0
Long-term debt, excluding current maturities, gross	300,182,000		150,000,000
Unamortized Discounts, (Premiums), and Issuance Costs, net	1,739,000		140,000
Unamortized Discounts, (Premiums), and Issuance Costs, net, Less current maturities	557,000		0
Unamortized Discounts, (Premiums), and Issuance Costs, net, excluding current maturities	1,182,000		140,000
PNMR [Member] | PNMR Term Loan Agreement due 2018 [Member]
Debt Instrument [Line Items]
Long-term debt	150,000,000		150,000,000
Unamortized Discounts, (Premiums), and Issuance Costs, net	84,000		140,000
PNMR [Member] | BTMU Term Loan Agreement [Member]
Debt Instrument [Line Items]
Long-term debt	92,207,000		0
Unamortized Discounts, (Premiums), and Issuance Costs, net	1,634,000		0
PNMR [Member] | PNMR 2016 Two Year Term Loan [Member]
Debt Instrument [Line Items]
Long-term debt	100,000,000		0
Unamortized Discounts, (Premiums), and Issuance Costs, net	$ 21,000		$ 0

Financing - Long-term Debt Matu

Financing - Long-term Debt Maturities (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Long-term Debt, by Maturity [Abstract]
2,017	$ 274,025
2,018	707,725
2,019	184,612
2,020	126,245
2,021	310,272
Thereafter	785,698
Total	2,388,577	$ 2,086,370
PNMR [Member]
Long-term Debt, by Maturity [Abstract]
2,017	42,025
2,018	257,700
2,019	12,310
2,020	25,900
2,021	4,272
Thereafter	0
Total	342,207	150,000
Public Service Company of New Mexico [Member]
Long-term Debt, by Maturity [Abstract]
2,017	232,000
2,018	450,025
2,019	0
2,020	100,345
2,021	306,000
Thereafter	552,500
Total	1,640,870	1,590,870
Texas-New Mexico Power Company [Member]
Long-term Debt, by Maturity [Abstract]
2,017	0
2,018	0
2,019	172,302
2,020	0
2,021	0
Thereafter	233,198
Total	$ 405,500	$ 345,500

Lease Commitments - Narrative (

Lease Commitments - Narrative (Details) $ in Thousands	Jan. 15, 2016USD ($)leaseMW	Nov. 30, 2015USD ($)	Dec. 31, 2016USD ($)leaselessor	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Apr. 01, 2015USD ($)	Jan. 15, 2015lease	Dec. 31, 1986lease	Dec. 31, 1985lease
Lease commitments
Operating lease, option term extensions			2 years
Operating leases, renewal options after original lease term			6 years
Corporate Headquarters [Member]
Lease commitments
Operating lease expense		$ 1,900
Public Service Company of New Mexico [Member]
Lease commitments
Operating lease expense			$ 47,349	$ 63,558	$ 76,745
Public Service Company of New Mexico [Member] | TGP Granada, LLC and its affiliate Complaint [Member]
Lease commitments
Lease ownership in EIP			60.00%
Additional area leased of the EIP						40.00%
Option to purchase leased capacity at fair value						$ 7,700
Public Service Company of New Mexico [Member] | Navajo Nation [Member]
Lease commitments
Number of operating leases set to expire | lease			0
Operating leases, period to expiration of the lease			5 years
Annual lease payments			$ 6,000
Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station [Member]
Lease commitments
Number of leases | lease								4	4
Rental payments, fixed renewal option period during original terms of leases			50.00%
Lease covenants, restrictions on conveying, transferring, leasing, and dividends (more than)			5.00%
Loss contingency, range of possible loss, portion not accrued (up to)			$ 176,100
Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station, Unit 1 Leases [Member]
Lease commitments
Annual lease payments			33,000
Number of leases | lease							4		4
Annual lease payments during renewal period			16,500
Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station, Unit 2 Leases [Member]
Lease commitments
Annual lease payments			$ 23,700
Number of leases | lease	1		3					4
Annual lease payments during renewal period			$ 1,600
Estimated purchase price of leased asset	$ 78,100
Leased capacity to be purchased (in megawatts) | MW	31.25
Additional capacity to be leased (in megawatts) | MW	32.76
Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station, Unit 1, Lease with Maximum Option Period Provision [Member]
Lease commitments
Number of lessors | lessor			4
Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station, Unit 2, Lease with Maximum Option Period Provision [Member]
Lease commitments
Number of leases | lease			1
Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station, Unit 1, Lease Expires in 2023 [Member]
Lease commitments
Number of leases | lease			4
Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station, Unit 2, Lease Expires in 2024 [Member]
Lease commitments
Number of leases | lease			1
Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station, Unit 2 Leases 32.76 MW [Member]
Lease commitments
Number of leases | lease	2
Estimated purchase price of leased asset	$ 85,200

Lease Commitments - Schedule of

Lease Commitments - Schedule of Rent Expense (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
PNMR [Member]
Operating lease expense [Line Items]
Operating lease expense	$ 51,938	$ 68,652	$ 82,756
Public Service Company of New Mexico [Member]
Operating lease expense [Line Items]
Operating lease expense	47,349	63,558	76,745
Texas-New Mexico Power Company [Member]
Operating lease expense [Line Items]
Operating lease expense	$ 3,748	$ 3,688	$ 3,932

Lease Commitments - Future Mini

Lease Commitments - Future Minimum Rental Payments for Operating Leases (Details) $ in Thousands	Dec. 31, 2016USD ($)
PNMR [Member]
Lease commitments
2,017	$ 27,873
2,018	25,809
2,019	25,059
2,020	25,044
2,021	24,958
Later years	84,462
Total minimum lease payments	213,205
Public Service Company of New Mexico [Member]
Lease commitments
2,017	26,497
2,018	25,262
2,019	24,958
2,020	24,958
2,021	24,958
Later years	84,462
Total minimum lease payments	211,095
Texas-New Mexico Power Company [Member]
Lease commitments
2,017	1,104
2,018	267
2,019	0
2,020	0
2,021	0
Later years	0
Total minimum lease payments	$ 1,371

Fair Value of Derivative and 63

Fair Value of Derivative and Other Financial Instruments - Commodity Derivatives (Details) - USD ($)	Dec. 31, 2016	Dec. 31, 2015
Derivatives, Fair Value [Line Items]
Current assets	$ 5,224,000	$ 3,813,000
Deferred charges	0	2,622,000
Current liabilities	(2,339,000)	(1,859,000)
PNMR and PNM [Member]
Derivatives, Fair Value [Line Items]
Amounts recognized for the legal right to reclaim cash collateral	0	0
Amounts posted as cash collateral under margin arrangements	2,600,000	2,700,000
Obligations to return cash collateral	100,000	100,000
PNMR and PNM [Member] | Designated as hedging instrument [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Current assets	5,224,000	3,813,000
Deferred charges	0	2,622,000
Total assets	5,224,000	6,435,000
Current liabilities	(2,339,000)	(1,859,000)
Net	2,885,000	4,576,000
PNMR and PNM [Member] | Designated as hedging instrument [Member] | Commodity Contract [Member] | Palo Verde Nuclear Generating Station [Member]
Derivatives, Fair Value [Line Items]
Current assets	2,700,000	3,000,000
Deferred charges		2,600,000
Public Service Company of New Mexico [Member]
Derivatives, Fair Value [Line Items]
Current assets	5,224,000	3,813,000
Deferred charges	0	2,622,000
Current liabilities	(2,339,000)	(1,859,000)
Public Service Company of New Mexico [Member] | Designated as hedging instrument [Member] | Commodity Contract [Member] | Fuel and Purchased Power Adjustment Clause [Member]
Derivatives, Fair Value [Line Items]
Current assets	200,000	400,000
Current liabilities	$ (100,000)	$ (200,000)

Fair Value of Derivative and 64

Fair Value of Derivative and Other Financial Instruments - Effect of Mark-to-Market Instruments on Earnings (Details) - Designated as hedging instrument [Member] - Commodity Contract [Member] - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss)	$ (1,261)	$ 6,863	$ 5,084
Electric operating revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss)	(53)	7,156	4,491
Cost of energy [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss)	$ (1,208)	$ (293)	$ 593

Fair Value of Derivative and 65

Fair Value of Derivative and Other Financial Instruments - Volume Positions and Requirements to Provide Collateral (Details) - PNMR and PNM [Member] $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)MMBTUMWh	Dec. 31, 2015USD ($)MMBTUMWh
Derivative [Line Items]
Contractual Liability	$ 0	$ 839
Existing Cash Collateral	0	0
Net Exposure	$ 0	$ 839
Long [Member] | Commodity Contract [Member] | Economic hedges [Member]
Derivative [Line Items]
Power-related contracts | MMBTU	254,100	577,481
Short [Member] | Commodity Contract [Member] | Economic hedges [Member]
Derivative [Line Items]
Power-related contracts | MWh	2,471,600	3,405,843

Fair Value of Derivative and 66

Fair Value of Derivative and Other Financial Instruments - Sale of Power (Details) - PNMR and PNM [Member] - Palo Verde Nuclear Generating Station Unit 3 [Member]	Dec. 31, 2017$ / MWh	Dec. 31, 2016MW
Sale of Power [Line Items]
Number of megawatts not included in retail rates (in megawatts) | MW		134
Percentage of electric power plant output sold or contracted to sell		100.00%
Commodity Contract [Member] | Subsequent Event [Member]
Sale of Power [Line Items]
Derivative, average forward price (in dollars per megawatt hour) | $ / MWh	29

Fair Value of Derivative and 67

Fair Value of Derivative and Other Financial Instruments - Non-Derivative Financial Instruments (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Schedule of Available-for-sale Securities [Line Items]
Realized impairment loss	$ (1,200,000)	$ (4,300,000)	$ (700,000)
PNMR and PNM [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	272,977,000	259,042,000
Unrealized Gains	7,449,000	28,820,000
Proceeds from sales	522,601,000	252,174,000	117,989,000
Gross realized gains	46,116,000	29,663,000	15,162,000
Gross realized (losses)	(25,430,000)	(9,259,000)	$ (3,964,000)
Value of other than temporary impairments	0
PNMR and PNM [Member] | Cash and equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	23,683,000	10,700,000
Unrealized Gains	0	0
PNMR and PNM [Member] | Domestic value [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	34,796,000	44,505,000
Unrealized Gains	1,135,000	11,610,000
PNMR and PNM [Member] | Domestic growth [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	47,595,000	61,078,000
Unrealized Gains	3,032,000	11,163,000
PNMR and PNM [Member] | International and other [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	27,481,000	27,961,000
Unrealized Gains	2,029,000	1,569,000
PNMR and PNM [Member] | U.S. Government [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	40,962,000	27,880,000
Unrealized Gains	115,000	178,000
PNMR and PNM [Member] | Municipals [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	43,789,000	58,576,000
Unrealized Gains	585,000	3,672,000
PNMR and PNM [Member] | Corporate and other [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	54,671,000	28,342,000
Unrealized Gains	553,000	628,000
PNMR and PNM [Member] | Measured on a recurring basis [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	272,977,000	259,042,000
PNMR and PNM [Member] | Measured on a recurring basis [Member] | Nuclear Decommissioning Trust [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	253,900,000	249,100,000
PNMR and PNM [Member] | Measured on a recurring basis [Member] | Mine Reclamation Trust [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	19,100,000	9,900,000
PNMR and PNM [Member] | Measured on a recurring basis [Member] | Cash and equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	23,683,000	10,700,000
PNMR and PNM [Member] | Measured on a recurring basis [Member] | Domestic value [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	34,796,000	44,505,000
PNMR and PNM [Member] | Measured on a recurring basis [Member] | Domestic growth [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	47,595,000	61,078,000
PNMR and PNM [Member] | Measured on a recurring basis [Member] | International and other [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	27,481,000	27,961,000
PNMR and PNM [Member] | Measured on a recurring basis [Member] | U.S. Government [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	40,962,000	27,880,000
PNMR and PNM [Member] | Measured on a recurring basis [Member] | Municipals [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	43,789,000	58,576,000
PNMR and PNM [Member] | Measured on a recurring basis [Member] | Corporate and other [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	$ 54,671,000	$ 28,342,000

Fair Value of Derivative and 68

Fair Value of Derivative and Other Financial Instruments - Maturities of Securities (Details) $ in Thousands	Dec. 31, 2016USD ($)
PNMR and PNM [Member]
Available-for-Sale
Within 1 year	$ 4,291
After 1 year through 5 years	35,884
After 5 years through 10 years	52,651
After 10 years through 15 years	5,617
After 15 years through 20 years	6,924
After 20 years	34,055
Available-for-sale debt securities	139,422
PNM Resources [Member]
Held-to-Maturity
Within 1 year	0
After 1 year through 5 years	100,893
After 5 years through 10 years	0
After 10 years through 15 years	0
After 15 years through 20 years	0
After 20 years	0
Held-to-maturity debt securities	$ 100,893

Fair Value of Derivative and 69

Fair Value of Derivative and Other Financial Instruments - Items Recorded at Fair Value (Details) - PNMR and PNM [Member] - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	$ 272,977	$ 259,042
Cash and equivalents [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	23,683	10,700
Domestic value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	34,796	44,505
Domestic growth [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	47,595	61,078
International and other [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	27,481	27,961
U.S. Government [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	40,962	27,880
Municipals [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	43,789	58,576
Corporate and other [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	54,671	28,342
Measured on a recurring basis [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	272,977	259,042
Measured on a recurring basis [Member] | Commodity Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity derivative assets	5,224	6,435
Commodity derivative liabilities	(2,339)	(1,859)
Net	2,885	4,576
Measured on a recurring basis [Member] | Cash and equivalents [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	23,683	10,700
Measured on a recurring basis [Member] | Domestic value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	34,796	44,505
Measured on a recurring basis [Member] | Domestic growth [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	47,595	61,078
Measured on a recurring basis [Member] | International and other [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	27,481	27,961
Measured on a recurring basis [Member] | U.S. Government [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	40,962	27,880
Measured on a recurring basis [Member] | Municipals [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	43,789	58,576
Measured on a recurring basis [Member] | Corporate and other [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	54,671	28,342
Measured on a recurring basis [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member}
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	196,436	177,352
Measured on a recurring basis [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Commodity Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity derivative assets	0	0
Commodity derivative liabilities	0	0
Net	0	0
Measured on a recurring basis [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Cash and equivalents [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	23,683	10,700
Measured on a recurring basis [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Domestic value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	34,796	44,505
Measured on a recurring basis [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Domestic growth [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	47,595	61,078
Measured on a recurring basis [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | International and other [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	27,481	27,961
Measured on a recurring basis [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | U.S. Government [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	39,723	26,608
Measured on a recurring basis [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Municipals [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	0	0
Measured on a recurring basis [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Corporate and other [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	23,158	6,500
Measured on a recurring basis [Member] | Significant Other Observable Inputs (Level 2) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	76,541	81,690
Measured on a recurring basis [Member] | Significant Other Observable Inputs (Level 2) [Member] | Commodity Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity derivative assets	5,224	6,435
Commodity derivative liabilities	(2,339)	(1,859)
Net	2,885	4,576
Measured on a recurring basis [Member] | Significant Other Observable Inputs (Level 2) [Member] | Cash and equivalents [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	0	0
Measured on a recurring basis [Member] | Significant Other Observable Inputs (Level 2) [Member] | Domestic value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	0	0
Measured on a recurring basis [Member] | Significant Other Observable Inputs (Level 2) [Member] | Domestic growth [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	0	0
Measured on a recurring basis [Member] | Significant Other Observable Inputs (Level 2) [Member] | International and other [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	0	0
Measured on a recurring basis [Member] | Significant Other Observable Inputs (Level 2) [Member] | U.S. Government [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	1,239	1,272
Measured on a recurring basis [Member] | Significant Other Observable Inputs (Level 2) [Member] | Municipals [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	43,789	58,576
Measured on a recurring basis [Member] | Significant Other Observable Inputs (Level 2) [Member] | Corporate and other [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value	$ 31,513	$ 21,842

Fair Value of Derivative and 70

Fair Value of Derivative and Other Financial Instruments - Items not Recorded at Fair Value (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
PNMR [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 2,540,693	$ 2,264,869
Westmoreland Loan	100,893
Investment in PVNGS lessor notes		8,947
Other investments	1,164	1,269
PNMR [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	2,392,712	2,091,948
Westmoreland Loan	95,000
Investment in PVNGS lessor notes		8,587
Other investments	547	604
PNMR [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member}
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	0	0
Westmoreland Loan	0
Investment in PVNGS lessor notes		0
Other investments	547	604
PNMR [Member] | Significant Other Observable Inputs (Level 2) [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	2,540,693	2,264,869
Westmoreland Loan	0
Investment in PVNGS lessor notes		0
Other investments	0	0
PNMR [Member] | Significant Unobservable Inputs (Level 3) [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	0	0
Westmoreland Loan	100,893
Investment in PVNGS lessor notes		8,947
Other investments	617	665
Public Service Company of New Mexico [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	1,730,157	1,703,209
Investment in PVNGS lessor notes		8,947
Other investments	316	366
Public Service Company of New Mexico [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	1,631,369	1,580,677
Investment in PVNGS lessor notes		8,587
Other investments	316	366
Public Service Company of New Mexico [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member}
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	0	0
Investment in PVNGS lessor notes		0
Other investments	316	366
Public Service Company of New Mexico [Member] | Significant Other Observable Inputs (Level 2) [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	1,730,157	1,703,209
Investment in PVNGS lessor notes		0
Other investments	0	0
Public Service Company of New Mexico [Member] | Significant Unobservable Inputs (Level 3) [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	0	0
Investment in PVNGS lessor notes		8,947
Other investments	0	0
Texas-New Mexico Power Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	468,329	411,661
Other investments	231	238
Texas-New Mexico Power Company [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	420,875	361,411
Other investments	231	238
Texas-New Mexico Power Company [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member}
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	0	0
Other investments	231	238
Texas-New Mexico Power Company [Member] | Significant Other Observable Inputs (Level 2) [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	468,329	411,661
Other investments	0	0
Texas-New Mexico Power Company [Member] | Significant Unobservable Inputs (Level 3) [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	0	0
Other investments	$ 0	$ 0

Fair Value of Derivative and 71

Fair Value of Derivative and Other Financial Instruments - Defined Benefit Plans Disclosure (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Public Service Company of New Mexico [Member] | Pension Plan [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	$ 557,923	$ 587,909
Fair value of plan assets at end of year	543,601	557,923
Public Service Company of New Mexico [Member] | Pension Plan [Member] | PNMR Master Trust [Member] | Fair Value Measurement [Domain]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	479,858
Fair value of plan assets at end of year	467,965	479,858
Public Service Company of New Mexico [Member] | Pension Plan [Member] | PNMR Master Trust [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	558,319
Fair value of plan assets at end of year	543,650	558,319
Public Service Company of New Mexico [Member] | Pension Plan [Member] | PNMR Master Trust [Member] | Estimate of Fair Value Measurement [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	78,461
Fair value of plan assets at end of year	75,685	78,461
Public Service Company of New Mexico [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan assets owned	73,829	74,139
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	72,952	78,175
Fair value of plan assets at end of year	72,694	72,952
Public Service Company of New Mexico [Member] | Other Postretirement Benefits [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	1,512
Fair value of plan assets at end of year	2,567	1,512
Public Service Company of New Mexico [Member] | Other Postretirement Benefits [Member] | Equity Securities, International Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	10,604
Fair value of plan assets at end of year	9,300	10,604
Public Service Company of New Mexico [Member] | Other Postretirement Benefits [Member] | Equity Securities, Domestic Value [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	9,367
Fair value of plan assets at end of year	10,260	9,367
Public Service Company of New Mexico [Member] | Other Postretirement Benefits [Member] | Equity Securities, Domestic Growth [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	5,894
Fair value of plan assets at end of year	6,338	5,894
Public Service Company of New Mexico [Member] | Other Postretirement Benefits [Member] | Equity Securities, Other Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	28,419
Fair value of plan assets at end of year	26,405	28,419
Public Service Company of New Mexico [Member] | Other Postretirement Benefits [Member] | Fixed income securities, Mutual funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	18,343
Fair value of plan assets at end of year	18,959	18,343
Public Service Company of New Mexico [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Pension Plan [Member] | PNMR Master Trust [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	111,441
Fair value of plan assets at end of year	129,624	111,441
Public Service Company of New Mexico [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan assets owned	38,124	35,116
Public Service Company of New Mexico [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Other Postretirement Benefits [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	1,512
Fair value of plan assets at end of year	2,567	1,512
Public Service Company of New Mexico [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Other Postretirement Benefits [Member] | Equity Securities, International Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
Public Service Company of New Mexico [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Other Postretirement Benefits [Member] | Equity Securities, Domestic Value [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	9,367
Fair value of plan assets at end of year	10,260	9,367
Public Service Company of New Mexico [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Other Postretirement Benefits [Member] | Equity Securities, Domestic Growth [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	5,894
Fair value of plan assets at end of year	6,338	5,894
Public Service Company of New Mexico [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Other Postretirement Benefits [Member] | Equity Securities, Other Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
Public Service Company of New Mexico [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Other Postretirement Benefits [Member] | Fixed income securities, Mutual funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	18,343
Fair value of plan assets at end of year	18,959	18,343
Public Service Company of New Mexico [Member] | Significant Other Observable Inputs (Level 2) [Member] | Pension Plan [Member] | PNMR Master Trust [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	367,698
Fair value of plan assets at end of year	337,989	367,698
Public Service Company of New Mexico [Member] | Significant Other Observable Inputs (Level 2) [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan assets owned	35,705	39,023
Public Service Company of New Mexico [Member] | Significant Other Observable Inputs (Level 2) [Member] | Other Postretirement Benefits [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
Public Service Company of New Mexico [Member] | Significant Other Observable Inputs (Level 2) [Member] | Other Postretirement Benefits [Member] | Equity Securities, International Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	10,604
Fair value of plan assets at end of year	9,300	10,604
Public Service Company of New Mexico [Member] | Significant Other Observable Inputs (Level 2) [Member] | Other Postretirement Benefits [Member] | Equity Securities, Domestic Value [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
Public Service Company of New Mexico [Member] | Significant Other Observable Inputs (Level 2) [Member] | Other Postretirement Benefits [Member] | Equity Securities, Domestic Growth [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
Public Service Company of New Mexico [Member] | Significant Other Observable Inputs (Level 2) [Member] | Other Postretirement Benefits [Member] | Equity Securities, Other Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	28,419
Fair value of plan assets at end of year	26,405	28,419
Public Service Company of New Mexico [Member] | Significant Other Observable Inputs (Level 2) [Member] | Other Postretirement Benefits [Member] | Fixed income securities, Mutual funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
Public Service Company of New Mexico [Member] | Significant Unobservable Inputs (Level 3) [Member] | Fixed Income Securities, Corporate [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year		655
Actual return on assets sold during the period	1	0
Actual return on assets still held at period end	19	(1)
Purchases	0	177
Sales	(387)	(112)
Public Service Company of New Mexico [Member] | Significant Unobservable Inputs (Level 3) [Member] | Pension Plan [Member] | PNMR Master Trust [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	719
Fair value of plan assets at end of year	352	719
Public Service Company of New Mexico [Member] | Significant Unobservable Inputs (Level 3) [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan assets owned	0	0
Public Service Company of New Mexico [Member] | Significant Unobservable Inputs (Level 3) [Member] | Other Postretirement Benefits [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
Public Service Company of New Mexico [Member] | Significant Unobservable Inputs (Level 3) [Member] | Other Postretirement Benefits [Member] | Equity Securities, International Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
Public Service Company of New Mexico [Member] | Significant Unobservable Inputs (Level 3) [Member] | Other Postretirement Benefits [Member] | Equity Securities, Domestic Value [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
Public Service Company of New Mexico [Member] | Significant Unobservable Inputs (Level 3) [Member] | Other Postretirement Benefits [Member] | Equity Securities, Domestic Growth [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
Public Service Company of New Mexico [Member] | Significant Unobservable Inputs (Level 3) [Member] | Other Postretirement Benefits [Member] | Equity Securities, Other Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
Public Service Company of New Mexico [Member] | Significant Unobservable Inputs (Level 3) [Member] | Other Postretirement Benefits [Member] | Fixed income securities, Mutual funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
Texas-New Mexico Power Company [Member] | Pension Plan [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	62,082	69,177
Fair value of plan assets at end of year	60,624	62,082
Texas-New Mexico Power Company [Member] | Pension Plan [Member] | PNMR Master Trust [Member] | Fair Value Measurement [Domain]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	52,163
Fair value of plan assets at end of year	50,901	52,163
Texas-New Mexico Power Company [Member] | Pension Plan [Member] | PNMR Master Trust [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	62,131
Fair value of plan assets at end of year	60,630	62,131
Texas-New Mexico Power Company [Member] | Pension Plan [Member] | PNMR Master Trust [Member] | Estimate of Fair Value Measurement [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	9,968
Fair value of plan assets at end of year	9,729	9,968
Texas-New Mexico Power Company [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan assets owned	8,778	9,290
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	9,111	10,094
Fair value of plan assets at end of year	8,544	9,111
Texas-New Mexico Power Company [Member] | Other Postretirement Benefits [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	128
Fair value of plan assets at end of year	308	128
Texas-New Mexico Power Company [Member] | Other Postretirement Benefits [Member] | Equity Securities, International Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	1,310
Fair value of plan assets at end of year	1,279	1,310
Texas-New Mexico Power Company [Member] | Other Postretirement Benefits [Member] | Equity Securities, Domestic Value [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	367
Fair value of plan assets at end of year	449	367
Texas-New Mexico Power Company [Member] | Other Postretirement Benefits [Member] | Equity Securities, Domestic Growth [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	1,013
Fair value of plan assets at end of year	1,089	1,013
Texas-New Mexico Power Company [Member] | Other Postretirement Benefits [Member] | Equity Securities, Other Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	3,397
Fair value of plan assets at end of year	3,060	3,397
Texas-New Mexico Power Company [Member] | Other Postretirement Benefits [Member] | Fixed income securities, Mutual funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	3,075
Fair value of plan assets at end of year	2,593	3,075
Texas-New Mexico Power Company [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Pension Plan [Member] | PNMR Master Trust [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	12,199
Fair value of plan assets at end of year	14,447	12,199
Texas-New Mexico Power Company [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan assets owned	4,439	4,583
Texas-New Mexico Power Company [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Other Postretirement Benefits [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	128
Fair value of plan assets at end of year	308	128
Texas-New Mexico Power Company [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Other Postretirement Benefits [Member] | Equity Securities, International Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
Texas-New Mexico Power Company [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Other Postretirement Benefits [Member] | Equity Securities, Domestic Value [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	367
Fair value of plan assets at end of year	449	367
Texas-New Mexico Power Company [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Other Postretirement Benefits [Member] | Equity Securities, Domestic Growth [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	1,013
Fair value of plan assets at end of year	1,089	1,013
Texas-New Mexico Power Company [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Other Postretirement Benefits [Member] | Equity Securities, Other Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
Texas-New Mexico Power Company [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Other Postretirement Benefits [Member] | Fixed income securities, Mutual funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	3,075
Fair value of plan assets at end of year	2,593	3,075
Texas-New Mexico Power Company [Member] | Significant Other Observable Inputs (Level 2) [Member] | Pension Plan [Member] | PNMR Master Trust [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	39,886
Fair value of plan assets at end of year	36,416	39,886
Texas-New Mexico Power Company [Member] | Significant Other Observable Inputs (Level 2) [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan assets owned	4,339	4,707
Texas-New Mexico Power Company [Member] | Significant Other Observable Inputs (Level 2) [Member] | Other Postretirement Benefits [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
Texas-New Mexico Power Company [Member] | Significant Other Observable Inputs (Level 2) [Member] | Other Postretirement Benefits [Member] | Equity Securities, International Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	1,310
Fair value of plan assets at end of year	1,279	1,310
Texas-New Mexico Power Company [Member] | Significant Other Observable Inputs (Level 2) [Member] | Other Postretirement Benefits [Member] | Equity Securities, Domestic Value [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
Texas-New Mexico Power Company [Member] | Significant Other Observable Inputs (Level 2) [Member] | Other Postretirement Benefits [Member] | Equity Securities, Domestic Growth [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
Texas-New Mexico Power Company [Member] | Significant Other Observable Inputs (Level 2) [Member] | Other Postretirement Benefits [Member] | Equity Securities, Other Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	3,397
Fair value of plan assets at end of year	3,060	3,397
Texas-New Mexico Power Company [Member] | Significant Other Observable Inputs (Level 2) [Member] | Other Postretirement Benefits [Member] | Fixed income securities, Mutual funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
Texas-New Mexico Power Company [Member] | Significant Unobservable Inputs (Level 3) [Member] | Fixed Income Securities, Corporate [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year		72
Actual return on assets sold during the period	0	0
Actual return on assets still held at period end	2	0
Purchases	0	17
Sales	(42)	(11)
Texas-New Mexico Power Company [Member] | Significant Unobservable Inputs (Level 3) [Member] | Pension Plan [Member] | PNMR Master Trust [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	78
Fair value of plan assets at end of year	38	78
Texas-New Mexico Power Company [Member] | Significant Unobservable Inputs (Level 3) [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan assets owned	0	0
Texas-New Mexico Power Company [Member] | Significant Unobservable Inputs (Level 3) [Member] | Other Postretirement Benefits [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
Texas-New Mexico Power Company [Member] | Significant Unobservable Inputs (Level 3) [Member] | Other Postretirement Benefits [Member] | Equity Securities, International Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
Texas-New Mexico Power Company [Member] | Significant Unobservable Inputs (Level 3) [Member] | Other Postretirement Benefits [Member] | Equity Securities, Domestic Value [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
Texas-New Mexico Power Company [Member] | Significant Unobservable Inputs (Level 3) [Member] | Other Postretirement Benefits [Member] | Equity Securities, Domestic Growth [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
Texas-New Mexico Power Company [Member] | Significant Unobservable Inputs (Level 3) [Member] | Other Postretirement Benefits [Member] | Equity Securities, Other Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
Texas-New Mexico Power Company [Member] | Significant Unobservable Inputs (Level 3) [Member] | Other Postretirement Benefits [Member] | Fixed income securities, Mutual funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
PNMR [Member] | Fair Value Measurement [Domain]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	532,021
Fair value of plan assets at end of year	518,866	532,021
PNMR [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	620,450
Fair value of plan assets at end of year	604,280	620,450
PNMR [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	14,525
Fair value of plan assets at end of year	20,503	14,525
PNMR [Member] | Equity Securities, International Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	36,675
Fair value of plan assets at end of year	38,401	36,675
PNMR [Member] | Equity Securities, Domestic Value [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	34,769
Fair value of plan assets at end of year	36,036	34,769
PNMR [Member] | Equity Securities, Domestic Growth [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	25,407
Fair value of plan assets at end of year	18,484	25,407
PNMR [Member] | Equity Securities, Other Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	30,531
Fair value of plan assets at end of year	27,532	30,531
PNMR [Member] | Fixed Income Securities, Corporate [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	214,218
Fair value of plan assets at end of year	205,419	214,218
PNMR [Member] | Fixed Income Securities, U.S. Government [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	98,138
Fair value of plan assets at end of year	94,359	98,138
PNMR [Member] | Fixed Income Securities, Municipals [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	16,647
Fair value of plan assets at end of year	13,970	16,647
PNMR [Member] | Fixed Income Securities, Other Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	61,111
Fair value of plan assets at end of year	64,162	61,111
PNMR [Member] | Private equity funds [Member] | Estimate of Fair Value Measurement [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	32,333
Fair value of plan assets at end of year	27,060	32,333
PNMR [Member] | Hedge funds [Member] | Estimate of Fair Value Measurement [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	40,731
Fair value of plan assets at end of year	42,070	40,731
PNMR [Member] | Real estate funds [Member] | Estimate of Fair Value Measurement [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	15,365
Fair value of plan assets at end of year	16,284	15,365
PNMR [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member}
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	123,640
Fair value of plan assets at end of year	144,071	123,640
PNMR [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Cash and Cash Equivalents [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	14,525
Fair value of plan assets at end of year	20,503	14,525
PNMR [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Equity Securities, International Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
PNMR [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Equity Securities, Domestic Value [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	34,769
Fair value of plan assets at end of year	36,036	34,769
PNMR [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Equity Securities, Domestic Growth [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	25,407
Fair value of plan assets at end of year	18,484	25,407
PNMR [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Equity Securities, Other Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
PNMR [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Fixed Income Securities, Corporate [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
PNMR [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Fixed Income Securities, U.S. Government [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	48,936
Fair value of plan assets at end of year	69,048	48,936
PNMR [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Fixed Income Securities, Municipals [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
PNMR [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member} | Fixed Income Securities, Other Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	3
Fair value of plan assets at end of year	0	3
PNMR [Member] | Significant Other Observable Inputs (Level 2) [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	407,584
Fair value of plan assets at end of year	374,405	407,584
PNMR [Member] | Significant Other Observable Inputs (Level 2) [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
PNMR [Member] | Significant Other Observable Inputs (Level 2) [Member] | Equity Securities, International Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	36,675
Fair value of plan assets at end of year	38,401	36,675
PNMR [Member] | Significant Other Observable Inputs (Level 2) [Member] | Equity Securities, Domestic Value [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
PNMR [Member] | Significant Other Observable Inputs (Level 2) [Member] | Equity Securities, Domestic Growth [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
PNMR [Member] | Significant Other Observable Inputs (Level 2) [Member] | Equity Securities, Other Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	30,531
Fair value of plan assets at end of year	27,532	30,531
PNMR [Member] | Significant Other Observable Inputs (Level 2) [Member] | Fixed Income Securities, Corporate [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	213,421
Fair value of plan assets at end of year	205,029	213,421
PNMR [Member] | Significant Other Observable Inputs (Level 2) [Member] | Fixed Income Securities, U.S. Government [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	49,202
Fair value of plan assets at end of year	25,311	49,202
PNMR [Member] | Significant Other Observable Inputs (Level 2) [Member] | Fixed Income Securities, Municipals [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	16,647
Fair value of plan assets at end of year	13,970	16,647
PNMR [Member] | Significant Other Observable Inputs (Level 2) [Member] | Fixed Income Securities, Other Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	61,108
Fair value of plan assets at end of year	64,162	61,108
PNMR [Member] | Significant Unobservable Inputs (Level 3) [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	797
Fair value of plan assets at end of year	390	797
PNMR [Member] | Significant Unobservable Inputs (Level 3) [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
PNMR [Member] | Significant Unobservable Inputs (Level 3) [Member] | Equity Securities, International Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
PNMR [Member] | Significant Unobservable Inputs (Level 3) [Member] | Equity Securities, Domestic Value [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
PNMR [Member] | Significant Unobservable Inputs (Level 3) [Member] | Equity Securities, Domestic Growth [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
PNMR [Member] | Significant Unobservable Inputs (Level 3) [Member] | Equity Securities, Other Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
PNMR [Member] | Significant Unobservable Inputs (Level 3) [Member] | Fixed Income Securities, Corporate [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	797	727
Actual return on assets sold during the period	1	0
Actual return on assets still held at period end	21	(1)
Purchases	0	194
Sales	(429)	(123)
Fair value of plan assets at end of year	390	797
PNMR [Member] | Significant Unobservable Inputs (Level 3) [Member] | Fixed Income Securities, U.S. Government [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
PNMR [Member] | Significant Unobservable Inputs (Level 3) [Member] | Fixed Income Securities, Municipals [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
PNMR [Member] | Significant Unobservable Inputs (Level 3) [Member] | Fixed Income Securities, Other Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	0
Fair value of plan assets at end of year	0	0
PNMR [Member] | Significant Unobservable Inputs (Level 3) [Member] | Private equity funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	719
Fair value of plan assets at end of year	352	719
PNMR [Member] | Significant Unobservable Inputs (Level 3) [Member] | Hedge funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	78
Fair value of plan assets at end of year	$ 38	$ 78

Variable Interest Entities (Det

Variable Interest Entities (Details)	Feb. 01, 2017USD ($)	Feb. 01, 2016USD ($)	Jan. 31, 2016USD ($)	Jul. 17, 2014USD ($)	May 30, 2014	Oct. 08, 2013USD ($)	Jul. 17, 2014USD ($)	Dec. 31, 2016USD ($)leaseinvestorMW	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Feb. 21, 2017USD ($)	Jul. 19, 2016USD ($)	May 31, 2016MW	Apr. 30, 2016USD ($)	Jan. 15, 2016leaseMW	Jan. 15, 2015lease	Dec. 31, 1986lease	Dec. 31, 1985lease
Variable Interest Entity, Statement Of Operation [Abstract]
Earnings attributable to non-controlling interest								$ 14,519,000	$ 14,910,000	$ 14,127,000
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Current assets								378,039,000	385,570,000
Total assets								6,471,080,000	6,009,328,000	5,790,237,000
Current liabilities								805,108,000	641,120,000
Owners’ equity – non-controlling interest								$ 68,920,000	71,407,000
Public Service Company of New Mexico [Member]
Variable Interest Entity [Line Items]
Number of different institutional investors of trust lessors | investor								5
Accrued lease payments								$ 26,497,000
Variable Interest Entity, Statement Of Operation [Abstract]
Earnings attributable to non-controlling interest								14,519,000	14,910,000	14,127,000
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Current assets								314,245,000	357,757,000
Total assets								4,867,546,000	4,599,344,000
Current liabilities								457,361,000	316,921,000
Owners’ equity – non-controlling interest								68,920,000	71,407,000
Public Service Company of New Mexico [Member] | Delta [Member]
Variable Interest Entity [Line Items]
Payment for fixed charges							$ 3,500,000
Payment for variable charges							600,000
Payments to acquire businesses, net				$ 22,800,000
Project financing debt, amount at closing				14,600,000			14,600,000
Recorded plant in service				58,100,000			58,100,000
Accumulated depreciation				23,500,000			23,500,000
Current assets				3,600,000			3,600,000
Deferred charges				3,400,000			3,400,000
Current liabilities				300,000			300,000
Non-current regulatory liabilities				$ 3,400,000			$ 3,400,000
Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Variable Interest Entities, Other financial obligations due to beneficial owner								0
Variable interest entities, Exposure beyond contractual lease payments								0
Variable interest entities, Additional rights to assets beyond use of leased assets								0
Variable Interest Entity, Nonconsolidated, Carrying Amount, Assets								$ 0
Public Service Company of New Mexico [Member] | Valencia [Member]
Variable Interest Entity [Line Items]
Number of megawatts purchased (in megawatts) | MW								158
Power plant total construction costs								$ 90,000,000
Payment for fixed charges								19,300,000	19,200,000	19,100,000
Payment for variable charges								$ 1,100,000	1,600,000	1,200,000
Purchase price, percentage of the book value reduced by related indebtedness								50.00%
Purchase price, percentage of fair market value								50.00%
Number of days to agreement on fair market value						60 days
Purchase price as determined by appraisal process						$ 85,000,000
Long term contract option to purchase, approximate approval period								15 months
Long term contract option to purchase, ownership percentage					50.00%
Number of years the operating licenses for plants were extended								20 years
Variable Interest Entity, Statement Of Operation [Abstract]
Operating revenues								$ 20,371,000	20,687,000	20,247,000
Operating expenses								(5,852,000)	(5,777,000)	(6,120,000)
Earnings attributable to non-controlling interest								14,519,000	14,910,000	$ 14,127,000
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Current assets								2,551,000	2,588,000
Net property, plant and equipment								66,947,000	69,784,000
Total assets								69,498,000	72,372,000
Current liabilities								578,000	965,000
Owners’ equity – non-controlling interest								$ 68,920,000	71,407,000
Public Service Company of New Mexico [Member] | Valencia [Member] | Maximum [Member]
Variable Interest Entity [Line Items]
Option to purchase a percentage of the plant or VIE (up to )						50.00%		50.00%
Public Service Company of New Mexico [Member] | PVNGS [Member] | Palo Verde Nuclear Generating Station [Member]
Variable Interest Entity [Line Items]
Accrued lease payments								$ 8,300,000	$ 18,400,000
Public Service Company of New Mexico [Member] | Delta [Member]
Variable Interest Entity [Line Items]
Period of long term contract for purchase of electric power, fixed costs								20 years
NM Capital [Member] | Coal Supply [Member] | San Juan Generating Station [Member]
Variable Interest Entity [Line Items]
Loan agreement		$ 125,000,000	$ 125,000,000
Issuance in letters of credit			30,300,000									$ 30,300,000		$ 40,000,000
NM Capital [Member] | Coal Supply [Member] | San Juan Coal Company, Westmoreland [Member]
Variable Interest Entity [Line Items]
Amount outstanding			$ 125,000,000					$ 95,000,000
Interest receivable								$ 1,300,000
NM Capital [Member] | Coal Supply [Member] | San Juan Coal Company, Westmoreland [Member] | Subsequent Event [Member]
Variable Interest Entity [Line Items]
Amount outstanding											$ 85,400,000
Scheduled principal payment	$ 9,600,000
Palo Verde Nuclear Generating Station, Unit 1 Leases [Member] | Public Service Company of New Mexico [Member]
Variable Interest Entity [Line Items]
Number of leases | lease																4		4
Palo Verde Nuclear Generating Station, Unit 2 Leases [Member] | Public Service Company of New Mexico [Member]
Variable Interest Entity [Line Items]
Number of megawatts purchased (in megawatts) | MW													64.1		64.1
Number of leases | lease								3							1		4
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Number of leases under which assets were purchased | lease															3

Earnings and Dividends Per Sh73

Earnings and Dividends Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Earnings Per Share [Abstract]
Earnings Attributable to PNMR	$ 24,809	$ 54,418	$ 27,076	$ 10,546	$ (91,418)	$ 61,045	$ 31,673	$ 14,340	$ 116,849	$ 15,640	$ 116,254
Average Number of Common Shares:
Outstanding during year (in shares)									79,654	79,654	79,654
Vested awards of restricted stock (in shares)									104	105	134
Average Shares – Basic (in shares)									79,758	79,759	79,788
Dilutive Effect of Common Stock Equivalents:
Stock options and restricted stock (in shares)									374	380	491
Average Shares – Diluted (in shares)									80,132	80,139	80,279
Net Earnings Per Share of Common Stock:
Basic (dollars per share)	$ 0.32	$ 0.68	$ 0.34	$ 0.13	$ (1.15)	$ 0.77	$ 0.40	$ 0.18	$ 1.47	$ 0.20	$ 1.46
Diluted (dollars per share)	$ 0.31	$ 0.68	$ 0.34	$ 0.13	$ (1.15)	$ 0.76	$ 0.40	$ 0.18	1.46	0.20	1.45
Dividends Declared per Common Share (in dollars per share)									$ 0.9025	$ 0.82	$ 0.755

Income Taxes - Schedule of Comp

Income Taxes - Schedule of Components of Income Tax Expense (Benefit) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Taxes [Line Items]
Current federal income tax	$ 0	$ 0	$ (2,015)
Current state income tax	(527)	(1,376)	(728)
Deferred federal income tax	60,892	5,488	59,814
Deferred state income tax	3,886	12,305	14,831
Amortization of accumulated investment tax credits	(973)	(1,342)	(2,164)
Total income taxes (benefit)	63,278	15,075	69,738
Public Service Company of New Mexico [Member]
Income Taxes [Line Items]
Current federal income tax	(10,290)	(7,934)	(2,175)
Current state income tax	(1,907)	(1,988)	(979)
Deferred federal income tax	49,123	(6,827)	45,890
Deferred state income tax	4,969	5,333	12,061
Amortization of accumulated investment tax credits	(973)	(1,342)	(2,164)
Total income taxes (benefit)	40,922	(12,758)	52,633
Texas-New Mexico Power Company [Member]
Income Taxes [Line Items]
Current federal income tax	9,445	1,603	35
Current state income tax	1,729	1,639	1,939
Deferred federal income tax	12,690	20,904	20,577
Deferred state income tax	(28)	(21)	(28)
Total income taxes (benefit)	$ 23,836	$ 24,125	$ 22,523

Income Taxes - Schedule of Effe

Income Taxes - Schedule of Effective Income Tax Rate Reconciliation (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Taxes [Line Items]
Federal income tax at statutory rates	$ 68,311	$ 16,154	$ 70,226
Amortization of accumulated investment tax credits	(973)	(1,342)	(2,164)
Flow-through of depreciation items	1,227	1,485	1,344
Earnings attributable to non-controlling interest in Valencia	(5,082)	(5,218)	(4,945)
State income tax, net of federal benefit	4,537	(1,781)	5,723
Impairment of state net operating loss carryforwards	(311)	5,278	3,129
Impairment of state production tax credits	0	3,092	894
Allowance for equity funds used during construction	(1,732)	(3,650)	(1,947)
Reversal of deferred items related to BART at SJGS	0	1,826	0
Impairment of charitable contribution carryforward	0	2,042	0
Regulatory recovery of prior year impairment of state net operating loss carryforward, net of amortization	(1,877)	0	0
Other	(822)	(2,811)	(2,522)
Total income taxes (benefit)	$ 63,278	$ 15,075	$ 69,738
Effective tax rate	32.42%	32.66%	34.76%
Public Service Company of New Mexico [Member]
Income Taxes [Line Items]
Federal income tax at statutory rates	$ 46,501	$ (4,579)	$ 53,930
Amortization of accumulated investment tax credits	(973)	(1,342)	(2,164)
Flow-through of depreciation items	1,185	1,465	1,325
Earnings attributable to non-controlling interest in Valencia	(5,082)	(5,218)	(4,945)
State income tax, net of federal benefit	3,921	(2,162)	5,522
Impairment of state net operating loss carryforwards	(213)	3,619	2,145
Allowance for equity funds used during construction	(1,457)	(3,650)	(1,947)
Reversal of deferred items related to BART at SJGS	0	1,826	0
Impairment of charitable contribution carryforward	(301)	(737)	(737)
Regulatory recovery of prior year impairment of state net operating loss carryforward, net of amortization	(1,877)	0	0
Other	(782)	(1,980)	(496)
Total income taxes (benefit)	$ 40,922	$ (12,758)	$ 52,633
Effective tax rate	30.80%	97.52%	34.16%
Texas-New Mexico Power Company [Member]
Income Taxes [Line Items]
Federal income tax at statutory rates	$ 22,928	$ 23,131	$ 21,115
State income tax, net of federal benefit	1,132	1,065	1,257
Other	(224)	(71)	151
Total income taxes (benefit)	$ 23,836	$ 24,125	$ 22,523
Effective tax rate	36.39%	36.50%	37.33%

Income Taxes - Schedule of Defe

Income Taxes - Schedule of Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Deferred tax assets:
Net operating loss	$ 160,901	$ 161,691
Regulatory liabilities related to income taxes	64,657	80,031
Federal tax credit carryforwards	78,675	77,417
Shutdown of SJGS Units 2 and 3	53,434	53,823
Other	75,805	70,749
Total deferred tax assets	433,472	443,711
Deferred tax liabilities:
Depreciation and plant related	(1,102,458)	(1,027,047)
Investment tax credit	(56,017)	(56,589)
Regulatory assets related to income taxes	(66,378)	(71,054)
CTC	(12,715)	(16,151)
Pension	(57,287)	(65,226)
Other	(79,267)	(85,037)
Total deferred tax liabilities	(1,374,122)	(1,321,104)
Current accumulated deferred income tax (asset) liability	(940,650)	(877,393)
Public Service Company of New Mexico [Member]
Deferred tax assets:
Net operating loss	117,922	116,693
Regulatory liabilities related to income taxes	60,940	75,889
Federal tax credit carryforwards	59,156	57,928
Shutdown of SJGS Units 2 and 3	53,434	53,823
Other	41,700	41,210
Total deferred tax assets	333,152	345,543
Deferred tax liabilities:
Depreciation and plant related	(891,578)	(828,926)
Investment tax credit	(56,017)	(56,589)
Regulatory assets related to income taxes	(56,577)	(61,018)
Pension	(50,134)	(58,070)
Other	(27,512)	(37,324)
Total deferred tax liabilities	(1,081,818)	(1,041,927)
Current accumulated deferred income tax (asset) liability	(748,666)	(696,384)
Texas-New Mexico Power Company [Member]
Deferred tax assets:
Regulatory liabilities related to income taxes	3,718	4,141
Other	6,016	6,702
Total deferred tax assets	9,734	10,843
Deferred tax liabilities:
Depreciation and plant related	(201,017)	(189,322)
Regulatory assets related to income taxes	(9,800)	(10,036)
Loss on reacquired debt	(11,937)	(12,392)
CTC	(12,715)	(16,151)
Other	(20,050)	(15,733)
Total deferred tax liabilities	(255,519)	(243,634)
Current accumulated deferred income tax (asset) liability	$ (245,785)	$ (232,791)

Income Taxes - Schedule of De77

Income Taxes - Schedule of Deferred Income Tax Components (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Taxes [Line Items]
Net change in deferred income tax liability per above table	$ 63,257
Change in tax effects of income tax related regulatory assets and liabilities	(10,621)
Tax effect of mark-to-market adjustments	8,379
Tax effect of excess pension liability	5,071
Adjustment for uncertain income tax positions	297
Reclassification of unrecognized tax benefits	(297)
Regulatory recovery of prior year impairment of state net operating loss carryforward, net of amortization	(1,877)
Other	(404)
Deferred income taxes	63,805	$ 16,451	$ 72,481
Public Service Company of New Mexico [Member]
Income Taxes [Line Items]
Net change in deferred income tax liability per above table	52,282
Change in tax effects of income tax related regulatory assets and liabilities	(10,510)
Tax effect of mark-to-market adjustments	8,336
Tax effect of excess pension liability	5,071
Adjustment for uncertain income tax positions	297
Reclassification of unrecognized tax benefits	(297)
Regulatory recovery of prior year impairment of state net operating loss carryforward, net of amortization	(1,877)
Other	(183)
Deferred income taxes	53,119	(2,836)	55,787
Texas-New Mexico Power Company [Member]
Income Taxes [Line Items]
Net change in deferred income tax liability per above table	12,994
Change in tax effects of income tax related regulatory assets and liabilities	(111)
Other	(221)
Deferred income taxes	$ 12,662	$ 20,883	$ 20,549

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of Unrecognized Tax Benefits (Expense) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Beginning balance	$ 6,455	$ 15,031	$ 19,889
Additions based on tax positions	242	1,214	623
Additions (reductions) for tax positions of prior years		(9,790)	(5,481)
Additions (reductions) for tax positions of prior years	55
Settlement payments	0	0	0
Ending balance	6,752	6,455	15,031
Public Service Company of New Mexico [Member]
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Beginning balance	3,652	12,228	11,073
Additions based on tax positions	242	1,214	623
Additions (reductions) for tax positions of prior years		(9,790)
Additions (reductions) for tax positions of prior years	55		532
Settlement payments	0	0	0
Ending balance	3,949	3,652	12,228
Unrecognized tax benefits that would impact effective tax rate	3,400
Texas-New Mexico Power Company [Member]
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Beginning balance	0	0	6,796
Additions based on tax positions	0	0	0
Additions (reductions) for tax positions of prior years		0	(6,796)
Additions (reductions) for tax positions of prior years	0
Settlement payments	0	0	0
Ending balance	0	$ 0	$ 0
PNMR [Member]
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Unrecognized tax benefits that would impact effective tax rate	$ 6,200

Income Taxes - Interest Income

Income Taxes - Interest Income (Expense) Related to Income Taxes (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Taxes [Line Items]
Interest income related to income taxes	$ 4,398	$ 0	$ 146
Public Service Company of New Mexico [Member]
Income Taxes [Line Items]
Interest income related to income taxes	3,625	0	148
Texas-New Mexico Power Company [Member]
Income Taxes [Line Items]
Interest income related to income taxes	345	$ 0	$ (2)
Interest Income and Interest Expense applicable to federal income tax matters [Member]
Income Taxes [Line Items]
Net refunds received	6,500
Increase (decrease) of net interest receivable	(2,100)
Interest income	5,100
Interest expense	700
Professional fees	900
Net pre-tax impacts	3,500
Interest Income and Interest Expense applicable to federal income tax matters [Member] | Public Service Company of New Mexico [Member]
Income Taxes [Line Items]
Net pre-tax impacts	2,600
Interest Income and Interest Expense applicable to federal income tax matters [Member] | Texas-New Mexico Power Company [Member]
Income Taxes [Line Items]
Net pre-tax impacts	300
Interest Income and Interest Expense applicable to federal income tax matters [Member] | Corporate and Other [Member]
Income Taxes [Line Items]
Net pre-tax impacts	$ 600

Income Taxes - Accumulated Accr

Income Taxes - Accumulated Accrued Interest Receivable (Payable) Related to Income Taxes (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
PNMR [Member]
Income Taxes [Line Items]
Accumulated accrued interest receivable	$ 0	$ 3,236
Accumulated accrued interest payable	0	(1,120)
Public Service Company of New Mexico [Member]
Income Taxes [Line Items]
Accumulated accrued interest receivable	0	3,236
Accumulated accrued interest payable	0	(24)
Texas-New Mexico Power Company [Member]
Income Taxes [Line Items]
Accumulated accrued interest receivable	0	0
Accumulated accrued interest payable	$ 0	$ (120)

Income Taxes - Carryforwards (D

Income Taxes - Carryforwards (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Operating Loss Carryforwards [Line Items]
New Mexico corporate tax rate being phased in					7.60%
New Mexico Corporate tax rate, effective by 2018				5.90%
Regulatory liability	$ (7,132,000)	$ (1,903,000)	$ (5,106,000)
Increase/Decrease in Income Tax expense due to tax rate change	(712,000)	674,000	71,000
Income Taxes, Impairment of Carryforwards [Abstract]
State tax credit carryforwards	0	3,092,000	894,000
State net operating loss carryforwards	(311,000)	5,278,000	3,129,000
Charitable contribution carryforwards	0	2,042,000
Income Taxes, Reserve Balances [Abstract]
State tax credit carryforwards	3,986,000	6,378,000
State net operating loss carryforwards	361,000	361,000
Charitable contribution carryforwards	659,000	659,000
Liability (refund) adjustment from settlement with taxing authority			(2,000,000)
Income tax expense (benefit)	63,278,000	15,075,000	69,738,000
Corporate and Other [Member]
Income Taxes, Reserve Balances [Abstract]
Income tax expense (benefit)	(1,480,000)	3,708,000	(5,418,000)
Internal Revenue Service (IRS) [Member]
Operating Loss Carryforwards [Line Items]
Federal net operating loss carryforwards	420,100,000
Federal tax credit carryforwards that expire beginning in 2023	78,700,000
Income Taxes, Reserve Balances [Abstract]
Income tax expense (benefit)			(200,000)
Internal Revenue Service (IRS) [Member] | Corporate and Other [Member]
Income Taxes, Reserve Balances [Abstract]
Income tax expense (benefit)			(1,300,000)
Public Service Company of New Mexico [Member]
Operating Loss Carryforwards [Line Items]
Regulatory liability	(7,132,000)	(1,903,000)	(5,106,000)
Increase/Decrease in Income Tax expense due to tax rate change	(804,000)	470,000	312,000
Income Taxes, Impairment of Carryforwards [Abstract]
State tax credit carryforwards	0	0	0
State net operating loss carryforwards	(213,000)	3,619,000	2,145,000
Charitable contribution carryforwards	0	0
Income Taxes, Reserve Balances [Abstract]
State tax credit carryforwards	0	0
State net operating loss carryforwards	248,000	248,000
Charitable contribution carryforwards	0	0
Income tax expense (benefit)	40,922,000	(12,758,000)	52,633,000
Public Service Company of New Mexico [Member] | Internal Revenue Service (IRS) [Member]
Income Taxes, Reserve Balances [Abstract]
Income tax expense (benefit)			1,100,000
Texas-New Mexico Power Company [Member]
Operating Loss Carryforwards [Line Items]
Regulatory liability	0	0	0
Increase/Decrease in Income Tax expense due to tax rate change	0	0	0
Income Taxes, Impairment of Carryforwards [Abstract]
State tax credit carryforwards	0	0	0
State net operating loss carryforwards	0	0	0
Charitable contribution carryforwards	0	0
Income Taxes, Reserve Balances [Abstract]
State tax credit carryforwards	0	0
State net operating loss carryforwards	0	0
Charitable contribution carryforwards	0	0
Income tax expense (benefit)	23,836,000	$ 24,125,000	22,523,000
Texas-New Mexico Power Company [Member] | Internal Revenue Service (IRS) [Member]
Income Taxes, Reserve Balances [Abstract]
Income tax expense (benefit)			$ 0
2015 Electric Rate Case [Member] | Public Service Company of New Mexico [Member]
Income Taxes, Reserve Balances [Abstract]
Approval to recover impairment of net operating loss carryforward	$ (2,100,000)
Recovery period of regulatory asset		2 years

Pension and Other Postretirem82

Pension and Other Postretirement Benefits - Narrative (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Expected return on plan assets	4.00%
Amortization of gains and losses that are outside the corridor	5 years
Maximum annual contributions per employee	75.00%
Employer matching contribution, percent of employees' gross pay	6.00%
Minimum [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Non-matching contribution of eligible compensation based on eligible employee's age	3.00%
Maximum [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Non-matching contribution of eligible compensation based on eligible employee's age	10.00%
Pension Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Expected long-term return resulting from effect of 1% change	1.00%
Expected long-term return resulting from effect of one-percentage point increase (as a percent)	1.00%
Expected employer contributions to pension plans	$ 0
Pension Plan [Member] | Minimum [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Weighted average discount rate related to anticipated contributions	4.10%
Pension Plan [Member] | Maximum [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Weighted average discount rate related to anticipated contributions	4.90%
Pension Plan [Member] | Equity Securities [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations	21.00%
Pension Plan [Member] | Equity Securities [Member] | Developed Countries Outside of United States [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations	6.00%
Pension Plan [Member] | Fixed income [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations	65.00%
Pension Plan [Member] | Alternative Investments [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations	14.00%
Pension Plan [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Expected return on plan assets	6.50%	6.80%	7.20%
Expected long-term return on assets decrease resulting in increase net periodic costs In next fiscal year	$ 5,300,000
Actual rate of return for pension plans	5.90%
Actuarial gains (losses) recorded as regulatory assets	$ (43,283,000)
Pension Plan [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Expected return on plan assets	6.50%	6.80%	7.20%
Expected long-term return on assets decrease resulting in increase net periodic costs In next fiscal year	$ 600,000
Actual rate of return for pension plans	5.50%
Actuarial gains (losses) recorded as regulatory assets	$ (4,960,000)
Other Postretirement Benefits [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Expected long-term return resulting from effect of 1% change	1.00%
Other Postretirement Benefits [Member] | Equity Securities [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations	70.00%
Other Postretirement Benefits [Member] | Fixed income [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations	30.00%
Other Postretirement Benefits [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Expected return on plan assets	7.70%	7.70%	8.50%
Expected long-term return on assets decrease resulting in increase net periodic costs In next fiscal year	$ 700,000
Actual rate of return for pension plans	8.50%
Actuarial gains (losses) recorded as regulatory assets	$ (17,400,000)
Other Postretirement Benefits [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Expected return on plan assets	5.70%	5.70%	6.50%
Expected long-term return on assets decrease resulting in increase net periodic costs In next fiscal year	$ 100,000
Actual rate of return for pension plans	5.50%
Actuarial gains (losses) recorded as regulatory assets	$ 100,000
Effect of 1%-point change in assumed health care cost trend rates on net periodic expense and APBO	0
Estimated future employer contributions in next fiscal year	400,000
Estimated future employer contributions in years two through five	$ 1,400,000

Pension and Other Postretirem83

Pension and Other Postretirement Benefits - APBO, PBO, Fair Value of Plan Assets, and Funded Status of the Plans (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Non-current liability	$ 125,844	$ 73,097
Public Service Company of New Mexico [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Non-current liability	114,427	66,285
Public Service Company of New Mexico [Member] | Pension Plan [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Balance at beginning of year	597,900	657,557
Service cost	0	0	$ 0
Interest cost	30,307	28,255	30,163
Actuarial (gain) loss	39,463	(38,151)
Benefits paid	(45,919)	(49,761)
Balance at end of year	621,751	597,900	657,557
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	557,923	587,909
Actual return on plan assets	31,597	(10,225)
Employer contributions	0	30,000
Benefits paid	(45,919)	(49,761)
Fair value of plan assets at end of year	543,601	557,923	587,909
Funded status – asset (liability) for pension benefits	(78,150)	(39,977)
Public Service Company of New Mexico [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Balance at beginning of year	84,674	95,175
Service cost	140	204	181
Interest cost	4,346	4,089	4,630
Participant contributions	2,690	2,439
Actuarial (gain) loss	17,877	(6,565)
Benefits paid	(11,734)	(10,668)
Plan design changes	(3,724)	0
Balance at end of year	94,269	84,674	95,175
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	72,952	78,175
Actual return on plan assets	5,923	(617)
Employer contributions	2,863	3,623
Participant contributions	2,690	2,439
Benefits paid	(11,734)	(10,668)
Fair value of plan assets at end of year	72,694	72,952	78,175
Funded status – asset (liability) for pension benefits	(21,575)	(11,722)
Public Service Company of New Mexico [Member] | Executive Retirement Program [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Balance at beginning of year	16,105	17,730
Service cost	0	0	0
Interest cost	812	760	822
Actuarial (gain) loss	768	(908)
Benefits paid	(1,473)	(1,477)
Balance at end of year	16,212	16,105	17,730
Less current liability	1,510	1,519
Non-current liability	14,702	14,586
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Benefits paid	(1,473)	(1,477)
Texas-New Mexico Power Company [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Non-current liability	11,417	6,812
Texas-New Mexico Power Company [Member] | Pension Plan [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Balance at beginning of year	64,198	72,305
Service cost	0	0	0
Interest cost	3,304	3,043	3,193
Actuarial (gain) loss	4,318	(5,157)
Benefits paid	(4,759)	(5,993)
Balance at end of year	67,061	64,198	72,305
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	62,082	69,177
Actual return on plan assets	3,301	(1,102)
Employer contributions	0	0
Benefits paid	(4,759)	(5,993)
Fair value of plan assets at end of year	60,624	62,082	69,177
Funded status – asset (liability) for pension benefits	(6,437)	(2,116)
Texas-New Mexico Power Company [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Balance at beginning of year	13,106	14,070
Service cost	186	247	237
Interest cost	677	608	619
Participant contributions	520	320
Actuarial (gain) loss	(96)	(575)
Benefits paid	(1,563)	(1,564)
Plan design changes	0	0
Balance at end of year	12,830	13,106	14,070
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	9,111	10,094
Actual return on plan assets	476	(82)
Employer contributions	0	343
Participant contributions	520	320
Benefits paid	(1,563)	(1,564)
Fair value of plan assets at end of year	8,544	9,111	10,094
Funded status – asset (liability) for pension benefits	(4,286)	(3,995)
Texas-New Mexico Power Company [Member] | Executive Retirement Program [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Balance at beginning of year	794	878
Service cost	0	0	0
Interest cost	40	36	39
Actuarial (gain) loss	47	(26)
Benefits paid	(94)	(94)
Balance at end of year	787	794	$ 878
Less current liability	93	93
Non-current liability	694	701
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Benefits paid	$ (94)	$ (94)

Pension and Other Postretirem84

Pension and Other Postretirement Benefits - Actuarial (Gain) Loss Results (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Public Service Company of New Mexico [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rates	$ 41,849	$ (45,918)
Claims, contributions, and demographic experience	(334)	2,778
Other assumption and experience	(2,052)	4,989
Actuarial (gain) loss	39,463	(38,151)
Public Service Company of New Mexico [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rates	6,569	(7,345)
Claims, contributions, and demographic experience	19,562	780
Assumed participation rate	(6,335)	0
Mortality rate	(691)	0
Medical benefits	(1,228)	0
Actuarial (gain) loss	17,877	(6,565)
Texas-New Mexico Power Company [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rates	5,055	(6,090)
Claims, contributions, and demographic experience	(556)	877
Other assumption and experience	(181)	56
Actuarial (gain) loss	4,318	(5,157)
Texas-New Mexico Power Company [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rates	1,112	(1,322)
Claims, contributions, and demographic experience	(102)	747
Assumed participation rate	(1,013)	0
Mortality rate	(93)	0
Medical benefits	0	0
Actuarial (gain) loss	$ (96)	$ (575)

Pension and Other Postretirem85

Pension and Other Postretirement Benefits - Pre-Tax Information about Prior Service Cost and Net Actuarial (Gain) loss in AOCI (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)
Public Service Company of New Mexico [Member] | Pension Plan [Member]
Prior service cost
Amounts in AOCI not yet recognized in net periodic benefit cost (income) at beginning of year	$ (1,855)
Experience (gain) loss	0
Regulatory asset (liability) adjustment	0
Amortization recognized in net periodic benefit cost (income)	405
Amounts in AOCI not yet recognized in net periodic benefit cost (income) at end of year	(1,450)
Amortization expected to be recognized in 2017	(405)
Defined Benefit Plan, Amounts Recognized in Other Comprehensive Income (Loss), Net Actuarial Gain (Loss), before Tax [Abstract]
Amounts in AOCI not yet recognized in net periodic benefit cost (income) at beginning of year	146,775
Experience (gain) loss	43,283
Regulatory asset (liability) adjustment	(25,104)
Amortization recognized in net periodic benefit cost (income)	(5,805)
Amounts in AOCI not yet recognized in net periodic benefit cost (income) at end of year	159,149
Amortization expected to be recognized in 2017	6,320
Public Service Company of New Mexico [Member] | Executive Retirement Program [Member]
Defined Benefit Plan, Amounts Recognized in Other Comprehensive Income (Loss), Net Actuarial Gain (Loss), before Tax [Abstract]
Amounts in AOCI not yet recognized in net periodic benefit cost (income) at beginning of year	2,084
Experience (gain) loss	768
Regulatory asset (liability) adjustment	(445)
Amortization recognized in net periodic benefit cost (income)	(108)
Amounts in AOCI not yet recognized in net periodic benefit cost (income) at end of year	2,299
Amortization expected to be recognized in 2017	132
Texas-New Mexico Power Company [Member] | Pension Plan [Member]
Defined Benefit Plan, Amounts Recognized in Other Comprehensive Income (Loss), Net Actuarial Gain (Loss), before Tax [Abstract]
Amounts in AOCI not yet recognized in net periodic benefit cost (income) at beginning of year	0
Experience (gain) loss	4,960
Regulatory asset (liability) adjustment	(4,960)
Amortization recognized in net periodic benefit cost (income)	0
Amounts in AOCI not yet recognized in net periodic benefit cost (income) at end of year	0
Amortization expected to be recognized in 2017	0
Texas-New Mexico Power Company [Member] | Executive Retirement Program [Member]
Defined Benefit Plan, Amounts Recognized in Other Comprehensive Income (Loss), Net Actuarial Gain (Loss), before Tax [Abstract]
Amounts in AOCI not yet recognized in net periodic benefit cost (income) at beginning of year	0
Experience (gain) loss	47
Regulatory asset (liability) adjustment	(47)
Amortization recognized in net periodic benefit cost (income)	0
Amounts in AOCI not yet recognized in net periodic benefit cost (income) at end of year	0
Amortization expected to be recognized in 2017	$ 0

Pension and Other Postretirem86

Pension and Other Postretirement Benefits - Components of Net Periodic Benefit Cost (Income) Recognized (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Public Service Company of New Mexico [Member] | Pension Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	$ 0	$ 0	$ 0
Interest cost	30,307	28,255	30,163
Expected return on plan assets	(35,416)	(39,323)	(38,044)
Amortization of net (gain) loss	13,820	14,820	13,020
Amortization of prior service cost	(965)	(965)	(965)
Net periodic benefit cost	7,746	2,787	4,174
Public Service Company of New Mexico [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	140	204	181
Interest cost	4,346	4,089	4,630
Expected return on plan assets	(5,483)	(5,610)	(5,638)
Amortization of net (gain) loss	1,145	1,966	2,225
Amortization of prior service cost	(30)	(642)	(1,343)
Net periodic benefit cost	118	7	55
Public Service Company of New Mexico [Member] | Executive Retirement Program [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	0	0	0
Interest cost	812	760	822
Amortization of net (gain) loss	256	325	210
Amortization of prior service cost	0	0	0
Net periodic benefit cost	1,068	1,085	1,032
Texas-New Mexico Power Company [Member] | Pension Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	0	0	0
Interest cost	3,304	3,043	3,193
Expected return on plan assets	(3,943)	(4,420)	(4,526)
Amortization of net (gain) loss	700	782	665
Amortization of prior service cost	0	0	0
Net periodic benefit cost	61	(595)	(668)
Texas-New Mexico Power Company [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	186	247	237
Interest cost	677	608	619
Expected return on plan assets	(490)	(520)	(534)
Amortization of net (gain) loss	(40)	0	(122)
Amortization of prior service cost	0	0	32
Net periodic benefit cost	333	335	232
Texas-New Mexico Power Company [Member] | Executive Retirement Program [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	0	0	0
Interest cost	40	36	39
Amortization of net (gain) loss	2	5	0
Amortization of prior service cost	0	0	0
Net periodic benefit cost	$ 42	$ 41	$ 39

Pension and Other Postretirem87

Pension and Other Postretirement Benefits - Assumptions Used (Details)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	4.00%
Public Service Company of New Mexico [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate for determining PBO and APBO	4.51%	5.29%	4.48%
Discount rate for determining net periodic benefit cost (income)	5.29%	4.48%	5.27%
Expected return on plan assets	6.50%	6.80%	7.20%
Public Service Company of New Mexico [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate for determining PBO and APBO	4.47%	5.34%	4.45%
Discount rate for determining net periodic benefit cost (income)	5.34%	4.45%	5.21%
Expected return on plan assets	7.70%	7.70%	8.50%
Public Service Company of New Mexico [Member] | Executive Retirement Program [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate for determining PBO and APBO	4.51%	5.29%	4.48%
Discount rate for determining net periodic benefit cost (income)	5.29%	4.48%	5.27%
Texas-New Mexico Power Company [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate for determining PBO and APBO	4.49%	5.39%	4.39%
Discount rate for determining net periodic benefit cost (income)	5.39%	4.39%	5.06%
Expected return on plan assets	6.50%	6.80%	7.20%
Texas-New Mexico Power Company [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate for determining PBO and APBO	4.47%	5.34%	4.45%
Discount rate for determining net periodic benefit cost (income)	5.34%	4.45%	5.21%
Expected return on plan assets	5.70%	5.70%	6.50%
Texas-New Mexico Power Company [Member] | Executive Retirement Program [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate for determining PBO and APBO	4.49%	5.39%	4.39%
Discount rate for determining net periodic benefit cost (income)	5.39%	4.39%	5.06%

Pension and Other Postretirem88

Pension and Other Postretirement Benefits - Pension Benefit Payments are Expected to be Paid (Details) $ in Thousands	Dec. 31, 2016USD ($)
Public Service Company of New Mexico [Member] | Pension Plan [Member]
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]
2,017	$ 50,244
2,018	48,398
2,019	47,696
2,020	46,879
2,021	45,348
2022 – 2026	209,331
Public Service Company of New Mexico [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]
2,017	8,425
2,018	8,327
2,019	8,092
2,020	7,965
2,021	7,792
2022 – 2026	33,891
Public Service Company of New Mexico [Member] | Executive Retirement Program [Member]
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]
2,017	1,510
2,018	1,487
2,019	1,459
2,020	1,427
2,021	1,391
2022 – 2026	6,228
Texas-New Mexico Power Company [Member] | Pension Plan [Member]
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]
2,017	5,526
2,018	5,728
2,019	5,086
2,020	5,042
2,021	5,294
2022 – 2026	22,509
Texas-New Mexico Power Company [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]
2,017	803
2,018	818
2,019	827
2,020	839
2,021	859
2022 – 2026	4,466
Texas-New Mexico Power Company [Member] | Executive Retirement Program [Member]
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]
2,017	93
2,018	92
2,019	89
2,020	86
2,021	83
2022 – 2026	$ 341

Pension and Other Postretirem89

Pension and Other Postretirement Benefits - Assumed Health Care Cost Trend Rates and Impact of a One-Percentage-Point Change in Assumed Health Care Cost Trend Rates (Details) - Public Service Company of New Mexico [Member] - Other Postretirement Benefits [Member] - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Defined Benefit Plan, Assumed Health Care Cost Trend Rates [Abstract]
Health care cost trend rate assumed for next year	6.80%	7.00%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)	5.00%	5.00%
Year that the rate reaches the ultimate trend rate	2,024	2,024
Defined Benefit Plan, Effect of One-Percentage Point Change in Assumed Health Care Cost Trend Rates [Abstract]
1-Percentage-Point Increase, Effect on total of service and interest cost	$ 259
1-Percentage-Point Increase, Effect on APBO	1,575
1-Percentage-Point Decrease, Effect on total of service and interest cost	(226)
1-Percentage-Point Decrease, Effect on APBO	$ (2,193)

Pension and Other Postretirem90

Pension and Other Postretirement Benefits - Other Postretirement Benefits (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Other Retirement Plans, 401 (k) plan [Member]
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]
401(k) plan	$ 17,762	$ 16,725	$ 16,703
Other Retirement Plans, 401 (k) plan [Member] | Public Service Company of New Mexico [Member]
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]
401(k) plan	13,397	12,679	12,745
Other Retirement Plans, 401 (k) plan [Member] | Texas-New Mexico Power Company [Member]
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]
401(k) plan	4,365	4,046	3,958
Other Retirement Plans, Key Employees, Non-qualified Plan [Member]
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]
Non-qualified plan	2,017	1,436	2,257
Other Retirement Plans, Key Employees, Non-qualified Plan [Member] | Public Service Company of New Mexico [Member]
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]
Non-qualified plan	1,535	1,090	1,722
Other Retirement Plans, Key Employees, Non-qualified Plan [Member] | Texas-New Mexico Power Company [Member]
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]
Non-qualified plan	$ 482	$ 346	$ 535

Stock-Based Compensation - Perf

Stock-Based Compensation - Performance Equity Plan and Accounting for Stock Awards (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	May 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of stock options granted (in shares)		0
Compensation expense for stock-based arrangements		$ 5.6	$ 4.9	$ 5.9
Restricted Stock and Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation expense		$ 4.5
Period to recognize compensation expense		1 year 9 months 25 days
Public Service Company of New Mexico [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense for stock-based arrangements		$ 4.2	3.6	4.2
Texas-New Mexico Power Company [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense for stock-based arrangements		$ 1.5	$ 1.3	$ 1.7
Performance Equity Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period for awards		3 years
Vesting rate		100.00%
Number of shares authorized (in shares)					13,500,000
Charge to share pool for each share awarded		5
Performance Equity Plan [Member] | Nonemployee Members of the Board of Directors [Member] | Subsequent Event [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period for awards	1 year

Stock-Based Compensation - Weig

Stock-Based Compensation - Weighted Average Assumptions (Details) - $ / shares	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Restricted Stock and Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected quarterly dividends per share (in dollars per share)	$ 0.2200	$ 0.2000	$ 0.1850
Risk-free interest rate	0.94%	0.92%	0.62%
Market-Based Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Dividend yield	2.74%	2.87%	2.82%
Expected volatility	20.44%	18.73%	25.11%
Risk-free interest rate	0.97%	1.00%	0.64%

Stock-Based Compensation - Rest

Stock-Based Compensation - Restricted Stock Awards (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Feb. 28, 2017	Mar. 31, 2015	Feb. 28, 2015	Jan. 01, 2015	Mar. 31, 2012
Chairman, President, and Chief Executive Officer [Member] | Common Stock [Member] | Achieves a specified improvement in total shareholder return at the end of 2016 compared to 2011 and she remains an employee [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Number of shares authorized (in shares)								135,000
Chairman, President, and Chief Executive Officer [Member] | Common Stock [Member] | Achieves a specified improvement in total shareholder return at the end of 2014 compared to 2011 and she remains an employee [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Number of shares authorized (in shares)								35,000
Number of shares approved upon meeting target (in shares)						35,000
Chairman, President, and Chief Executive Officer [Member] | Common Stock [Member] | Achieves a specified improvement in total shareholder return at the end of 2014 compared to 2011 and she remains an employee [Member] | Subsequent Event [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Number of shares approved upon meeting target (in shares)				100,000
Chairman, President, and Chief Executive Officer [Member] | Common Stock [Member] | Achieves a specific performance target by the end of 2019 and she remains an employee [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Number of shares authorized (in shares)					53,859
Chairman, President, and Chief Executive Officer [Member] | Common Stock [Member] | Achieves a specific performance target by the end of 2017 and she remains an employee [Member] [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Number of shares authorized (in shares)					17,953
Executive Vice President and Chief Financial Officer [Member] | Common Stock [Member] | Achieved performance target for 2015 and 2016 [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Value of stock to be granted if performance targets are achieved							$ 100,000
Executive Vice President and Chief Financial Officer [Member] | Common Stock [Member] | Achieved performance target for 2015, 2016 and 2017 [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Value of stock to be granted if performance targets are achieved							$ 275,000
Executive Vice President and Chief Financial Officer [Member] | Common Stock [Member] | Subsequent Event [Member] | Achieved performance target for 2015 and 2016 [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Number of shares approved upon meeting target (in shares)				100,000
Restricted Stock [Member]
Restricted Stock
Beginning balance (in shares)	245,094
Granted (in shares)	190,276
Exercised (in shares)	(216,340)
Forfeited (in shares)	(714)
Ending balance (in shares)	218,316	245,094
Weighted-Average Grant Date Fair Value
Beginning balance (in dollars per share)	$ 24.81
Granted (in dollars per share)	26.49	$ 20.34	$ 21.27
Exercised (in dollars per share)	23.47
Forfeited (in dollars per share)	29.54
Ending balance (in dollars per share)	27.59	24.81
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)	$ 26.49	$ 20.34	$ 21.27
Total fair value of restricted shares that vested	$ 5,079,000	$ 6,507,000	$ 4,933,000
Stock Options [Member]
Stock Options
Beginning balance (in shares)	569,342
Granted (in shares)	0
Exercised (in shares)	(253,268)
Forfeited (in shares)	(2,000)
Expired (in shares)	(8,200)
Ending balance (in shares)	305,874	569,342
Weighted Average Exercise Price
Beginning balance (in dollars per share)	$ 19.35
Granted (in dollars per share)	0
Forfeited (in dollars per share)	12.22
Exercised (in dollars per share)	27.75
Expired (in dollars per share)	24.85
Ending balance (in dollars per share)	$ 12.29	$ 19.35
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Aggregate intrinsic value of stock options outstanding	$ 6,700,000
Weighted average remaining contract life	2 years 15 days
Exercise price of stock options that are greater than the closing price (in shares)	0
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Additional Disclosures [Abstract]
Weighted-average grant date fair value options granted (in dollars per share)	$ 0	$ 0	$ 0
Total fair value of options that vested	$ 0	$ 0	$ 0
Total intrinsic value of options exercised	$ 1,242,000	$ 2,350,000	$ 2,473,000
Performance Shares [Member] | Executive [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Shares excluded from shares outstanding (in shares)	49,682	79,619
Weighted percentage assigned to achieving market targets	60.00%
Weighted percentage assigned to achieving performance targets	40.00%
Shares approved, maximum number of shares available in year two (in shares)	163,712
Shares approved, maximum number of shares available in year three (in shares)	137,036
Performance period	3 years

Construction Program and Join94

Construction Program and Jointly-Owned Electric Generating Plants - Construction Program and Jointly-Owned Electric Generating Plants (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)generating_unit	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Jointly Owned Utility Plant Interests [Line Items]
Construction expenditures	$ 600,076	$ 558,589	$ 460,658
Plant in Service	6,944,534	6,307,261
Accumulated Depreciation	(2,334,938)	(2,058,772)
Regulatory disallowance	$ 15,011	167,471	1,062
Operating lease, option term extensions	2 years
Public Service Company of New Mexico [Member]
Jointly Owned Utility Plant Interests [Line Items]
Construction expenditures	$ 445,464	404,840	316,800
Plant in Service	5,359,211	4,833,303
Accumulated Depreciation	(1,809,528)	(1,569,549)
Regulatory disallowance	15,011	167,471	1,062
Public Service Company of New Mexico [Member] | Clean Air Act, SNCR [Member]
Jointly Owned Utility Plant Interests [Line Items]
Regulatory disallowance		21,600
Texas-New Mexico Power Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Construction expenditures	122,518	124,584	$ 127,191
Plant in Service	1,380,584	1,285,727
Accumulated Depreciation	(429,397)	(406,516)
Joint Projects [Member] | Public Service Company of New Mexico [Member]
Jointly Owned Utility Plant Interests [Line Items]
Construction expenditures	445,500
Joint Projects [Member] | Texas-New Mexico Power Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Construction expenditures	122,500
Joint Projects [Member] | PNMR [Member]
Jointly Owned Utility Plant Interests [Line Items]
Construction expenditures	$ 600,100
SJGS (Coal) [Member] | Unit 3 [Member] | Other Unrelated Entities 1 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, ownership percentage	41.80%
SJGS (Coal) [Member] | Unit 3 [Member] | Other Unrelated Entities 2 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Composite Interest	8.20%
SJGS (Coal) [Member] | Unit 4 [Member] | Other Unrelated Entities 3 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, ownership percentage	28.80%
SJGS (Coal) [Member] | Unit 4 [Member] | Other Unrelated Entities 4 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, ownership percentage	10.04%
SJGS (Coal) [Member] | Unit 4 [Member] | Other Unrelated Entities 5 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, ownership percentage	8.475%
SJGS (Coal) [Member] | Unit 4 [Member] | Other Unrelated Entities 6 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, ownership percentage	7.20%
SJGS (Coal) [Member] | Unit 4 [Member] | Other Unrelated Entities 7 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, ownership percentage	7.028%
SJGS (Coal) [Member] | Public Service Company of New Mexico [Member]
Jointly Owned Utility Plant Interests [Line Items]
Plant in Service	$ 1,082,537
Accumulated Depreciation	(445,597)
Construction Work in Progress	$ 4,406
Composite Interest	46.30%
SJGS (Coal) [Member] | Public Service Company of New Mexico [Member] | Unit 3 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Composite Interest	50.00%
SJGS (Coal) [Member] | Public Service Company of New Mexico [Member] | Unit 4 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Composite Interest	38.457%
Jointly owned utility plant, future proportionate ownership share	64.50%
SJGS (Coal) [Member] | PNMR Development [Member] | Unit 4 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, future proportionate ownership share	12.80%
Palo Verde Nuclear Generating Station [Member] | Public Service Company of New Mexico [Member]
Jointly Owned Utility Plant Interests [Line Items]
Plant in Service	$ 797,793
Accumulated Depreciation	(334,887)
Construction Work in Progress	$ 38,946
Composite Interest	10.20%
Period of time for the original full power operating licenses	40 years
Number of units (in generating units) | generating_unit	3
Operating lease, option term extensions	20 years
Four Corners [Member] | Public Service Company of New Mexico [Member]
Jointly Owned Utility Plant Interests [Line Items]
Number of units (in generating units) | generating_unit	2
Four Corners Units 4 and 5 (Coal) [Member] | Public Service Company of New Mexico [Member]
Jointly Owned Utility Plant Interests [Line Items]
Plant in Service	$ 188,026
Accumulated Depreciation	(103,584)
Construction Work in Progress	$ 52,869
Composite Interest	13.00%
Luna (Gas) [Member] | Public Service Company of New Mexico [Member]
Jointly Owned Utility Plant Interests [Line Items]
Plant in Service	$ 69,678
Accumulated Depreciation	(25,386)
Construction Work in Progress	$ 259
Composite Interest	33.33%
San Juan Generating Station Units 2 and 3 [Member] | Public Service Company of New Mexico [Member]
Jointly Owned Utility Plant Interests [Line Items]
Plant in Service	$ 471,800	468,200
Accumulated Depreciation	(203,900)	(193,300)
Construction Work in Progress		2,200
Net book value	$ 267,900	277,100
San Juan Generating Station Units 2 and 3 [Member] | Public Service Company of New Mexico [Member] | Clean Air Act, SNCR [Member]
Jointly Owned Utility Plant Interests [Line Items]
Regulatory disallowance		$ 127,600
SJGS Units 1 and 2 [Member] | Public Service Company of New Mexico [Member]
Jointly Owned Utility Plant Interests [Line Items]
Composite Interest	50.00%

Construction Program and Join95

Construction Program and Jointly-Owned Electric Generating Plants - Summary of Budgeted Construction Expenditures (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)MW
Summary of Budgeted Construction Expenditures [Line Items]
2,017	$ 517.3
2,018	395
2,019	434.6
2,020	403.9
2,021	332.3
Total	$ 2,083.1
Solar [Member]
Summary of Budgeted Construction Expenditures [Line Items]
Public Utilities, Number of Megawatts | MW	30
Gas-fired [Member]
Summary of Budgeted Construction Expenditures [Line Items]
Public Utilities, Number of Megawatts | MW	40
Public Service Company of New Mexico [Member]
Summary of Budgeted Construction Expenditures [Line Items]
2,017	$ 308.1
2,018	231
2,019	282.2
2,020	252.5
2,021	190.7
Total	1,264.5
Public Service Company of New Mexico [Member] | Solar [Member]
Summary of Budgeted Construction Expenditures [Line Items]
2,017	46.9
Public Service Company of New Mexico [Member] | Gas-fired [Member]
Summary of Budgeted Construction Expenditures [Line Items]
2,017	43.7
Public Service Company of New Mexico [Member] | Four Corners Units 4 and 5 (Coal) [Member]
Summary of Budgeted Construction Expenditures [Line Items]
Expenditures related to environmental upgrades	44.2
Texas-New Mexico Power Company [Member]
Summary of Budgeted Construction Expenditures [Line Items]
2,017	151
2,018	134.3
2,019	137.1
2,020	136.2
2,021	126.2
Total	684.8
Other Subsidiaries [Member]
Summary of Budgeted Construction Expenditures [Line Items]
2,017	58.2
2,018	29.7
2,019	15.3
2,020	15.2
2,021	15.4
Total	$ 133.8

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance	$ 111,895	$ 104,170	$ 96,135
Liabilities incurred	0	0	0
Liabilities settled	(14)	(730)	0
Accretion expense	9,170	8,625	7,984
Revisions to estimated cash flows	6,468	(170)	51
Ending balance	127,519	111,895	104,170
Public Service Company of New Mexico [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance	111,049	103,182	95,225
Liabilities incurred	0	0	0
Liabilities settled	(14)	(506)	0
Accretion expense	9,098	8,543	7,906
Revisions to estimated cash flows	6,468	(170)	51
Ending balance	126,601	111,049	103,182
Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Increase (decrease) to asset retirement obligation	6,100	1,000
Public Service Company of New Mexico [Member] | San Juan Generating Station [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Increase (decrease) to asset retirement obligation	300	(1,200)
Texas-New Mexico Power Company [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance	695	848	782
Liabilities incurred	0	0	0
Liabilities settled	0	(224)	0
Accretion expense	59	71	66
Revisions to estimated cash flows	0	0	0
Ending balance	$ 754	$ 695	$ 848

Commitments and Contingencies -

Commitments and Contingencies - PVNGS Decommissioning Funding (Details) - Public Service Company of New Mexico [Member] - Palo Verde Nuclear Generating Station [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Public Utilities, General Disclosures [Line Items]
Funding for decommissioning costs in qualified and non-qualified trust funds	$ 4.2	$ 4.9	$ 4.9
Estimated market value of trusts for decommissioning costs	$ 253.9	$ 249.1

Commitments and Contingencies98

Commitments and Contingencies - Nuclear Spent Fuel and Waste Disposal (Details) - Public Service Company of New Mexico [Member] - Palo Verde Nuclear Generating Station [Member] - USD ($)	May 16, 2014	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Department of energy, spent nuclear fuel removal January 2007 - June 2011 [Member]
Loss Contingencies [Line Items]
PNM's share of third party settlement claim						$ 5,900,000
Department of energy, spent nuclear fuel removal July 2011 - June 2014 [Member]
Loss Contingencies [Line Items]
PNM's share of third party settlement claim			$ 4,300,000
Litigation settlement, portion credited to customers			$ 3,100,000
Department of energy, spent nuclear fuel removal July 2014 - June 2015 [Member]
Loss Contingencies [Line Items]
PNM's share of third party settlement claim		$ 1,300,000
Litigation settlement, portion credited to customers		$ 500,000
Nuclear spent fuel and waste disposal [Member]
Loss Contingencies [Line Items]
Estimate of possible loss				$ 57,700,000
DOE adjusted one-mill fee	$ 0
Nuclear spent fuel and waste disposal [Member] | Other Deferred Credits [Member]
Loss Contingencies [Line Items]
Liability for interim storage costs				$ 12,100,000	$ 12,200,000

Commitments and Contingencies99

Commitments and Contingencies - The Clean Air Act (Details)

Feb. 09, 2016

Dec. 31, 2015USD ($)

Dec. 16, 2015USD ($)MWhMW

Oct. 23, 2015

Jul. 17, 2015

Dec. 20, 2013USD ($)$ / kwMW

Aug. 31, 2011generating_unit

Dec. 31, 2016USD ($)lb / MMBTUgenerating_unitjoint_ownerMW

Dec. 31, 2015USD ($)

Dec. 31, 2014USD ($)

Jan. 31, 2016USD ($)

Jan. 26, 2016state

Jul. 31, 2015MW

Aug. 06, 2012compliance_alternative

Jul. 31, 2005T

Dec. 31, 1999state

Public Utilities, General Disclosures [Line Items]

Plant in service, held for future use, and to be abandoned

$ 6,307,261,000

$ 6,944,534,000

$ 6,307,261,000

Accumulated depreciation and amortization

2,058,772,000

2,334,938,000

2,058,772,000

Regulatory disallowances and restructuring costs

15,011,000

167,471,000

$ 1,062,000

Reversal of deferred items related to BART at SJGS

0

1,826,000

0

Four Corners [Member]

Public Utilities, General Disclosures [Line Items]

Approved lease extension term

25 years

Public Service Company of New Mexico [Member]

Public Utilities, General Disclosures [Line Items]

Plant in service, held for future use, and to be abandoned

4,833,303,000

5,359,211,000

4,833,303,000

Accumulated depreciation and amortization

1,569,549,000

1,809,528,000

1,569,549,000

Regulatory disallowances and restructuring costs

15,011,000

167,471,000

1,062,000

Reversal of deferred items related to BART at SJGS

$ 0

1,826,000

$ 0

Public Service Company of New Mexico [Member] | San Juan Generating Station [Member]

Public Utilities, General Disclosures [Line Items]

Number of units (in generating units) | generating_unit

4

Share of costs

46.30%

Public Service Company of New Mexico [Member] | San Juan Generating Station [Member] | Surface [Member] | Loss on long-term purchase commitment [Member]

Public Utilities, General Disclosures [Line Items]

Regulatory disallowances and restructuring costs

16,500,000

16,500,000

Estimate of possible loss

$ 102,000,000

Public Service Company of New Mexico [Member] | San Juan Generating Station Units 2 and 3 [Member]

Public Utilities, General Disclosures [Line Items]

Plant in service, held for future use, and to be abandoned

468,200,000

471,800,000

468,200,000

Accumulated depreciation and amortization

193,300,000

203,900,000

193,300,000

Construction work in progress

2,200,000

2,200,000

Net book value

$ 277,100,000

$ 267,900,000

277,100,000

Public Service Company of New Mexico [Member] | Four Corners [Member]

Public Utilities, General Disclosures [Line Items]

Number of units (in generating units) | generating_unit

2

Public Service Company of New Mexico [Member] | Four Corners Units 4 and 5 (Coal) [Member]

Public Utilities, General Disclosures [Line Items]

Share of costs

13.00%

Plant in service, held for future use, and to be abandoned

$ 188,026,000

Accumulated depreciation and amortization

103,584,000

Construction work in progress

$ 52,869,000

PNMR and PNM [Member] | Palo Verde Nuclear Generating Station Unit 3 [Member]

Public Utilities, General Disclosures [Line Items]

Number of megawatts | MW

134

PNMR Development [Member] | Energy Equipment [Member]

Public Utilities, General Disclosures [Line Items]

Cost of installing equipment

$ 7,600,000

Environmental Protection Agency [Member] | Public Service Company of New Mexico [Member] | San Juan Generating Station [Member]

Public Utilities, General Disclosures [Line Items]

Number of units (in generating units) | generating_unit

4

Environmental Protection Agency and NMED [Member] | Public Service Company of New Mexico [Member] | San Juan Generating Station [Member]

Public Utilities, General Disclosures [Line Items]

Period of time to comply after approval

15 months

Clean Air Act related to Regional Haze [Member]

Public Utilities, General Disclosures [Line Items]

Number of states to address regional haze | state

50

Potential to emit tons per year of visibility impairing pollution, maximum (in tons) | T

250

Clean Air Act, SCR [Member] [Member] | Public Service Company of New Mexico [Member] | Installation Costs Including Construction Management, Gross Receipts Taxes, AFUDC, and Other PNM Costs [Member] | Minimum [Member] | San Juan Generating Station [Member]

Public Utilities, General Disclosures [Line Items]

Estimated total capital cost if requirement occurred

824,000,000

Clean Air Act, SCR [Member] [Member] | Public Service Company of New Mexico [Member] | Installation Costs Including Construction Management, Gross Receipts Taxes, AFUDC, and Other PNM Costs [Member] | Maximum [Member] | San Juan Generating Station [Member]

Public Utilities, General Disclosures [Line Items]

Estimated total capital cost if requirement occurred

$ 910,000,000

Clean Air Act, SNCR [Member] | San Juan Generating Station Unit 4 [Member]

Public Utilities, General Disclosures [Line Items]

Number of other entities (in joint owner) | joint_owner

8

Clean Air Act, SNCR [Member] | San Juan Generating Station Unit 4 [Member] | CALIFORNIA

Public Utilities, General Disclosures [Line Items]

Number of other entities (in joint owner) | joint_owner

3

Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member]

Public Utilities, General Disclosures [Line Items]

Estimated costs to remain unrecovered

$ 20,000,000

Regulatory disallowances and restructuring costs

$ 21,600,000

Net expense

$ 3,700,000

Reclamation expense

$ 4,500,000

Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | San Juan Generating Station [Member]

Public Utilities, General Disclosures [Line Items]

Overall reduction of ownership (in megawatts) | MW

340

Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | San Juan Generating Station Units 2 and 3 [Member]

Public Utilities, General Disclosures [Line Items]

Requested time period to recover retired units NBV

20 years

20 years

20 years

Number of megawatts of gas-fired generation (in megawatts) | MW

177

Newly identified replacement solar generation (in megawatts) | MW

40

Current ownership (in megawatts) | MW

418

Recovery percentage of estimated undepreciated value

50.00%

50.00%

50.00%

50.00%

Estimated undepreciated value

$ 255,300,000

$ 255,300,000

Regulatory disallowances and restructuring costs

127,600,000

Reversal of deferred items related to BART at SJGS

1,800,000

Accumulated plant write-off, disallowance

$ 128,600,000

Net carrying value

$ 139,300,000

Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | San Juan Generating Station Units 2 and 3 [Member] | Increase in coal mine decommissioning liability [Member]

Public Utilities, General Disclosures [Line Items]

Regulatory disallowances and restructuring costs

165,700,000

Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station Unit 3 [Member]

Public Utilities, General Disclosures [Line Items]

Estimated undepreciated value

$ 151,000,000

Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | San Juan Generating Station Unit 4 [Member]

Public Utilities, General Disclosures [Line Items]

Additional ownership to be obtained (in megawatts) | MW

65

132

Estimated rate base value

$ 0

Coal-fired generation (in megawatts) | MW

197

Number of megawatt hours of renewable energy certificates to be acquired and retired (in megawatt hours) | MWh

1

Percentage of ownership held by exiting owners

38.80%

Ownership percentage

38.50%

Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | San Juan Generating Station Unit 3 [Member]

Public Utilities, General Disclosures [Line Items]

Percentage of ownership held by exiting owners

50.00%

Ownership percentage

50.00%

Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | Maximum [Member] | San Juan Generating Station Unit 4 [Member]

Public Utilities, General Disclosures [Line Items]

Annual cost of renewable energy credits, maximum

$ 7,000,000

Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | Installation Costs Including Construction Management, Gross Receipts Taxes, AFUDC, and Other PNM Costs [Member] | San Juan Generating Station Units 1 and 4 [Member]

Public Utilities, General Disclosures [Line Items]

Portion of costs for SNCRs and BDT equipment

$ 77,900,000

Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | Installation Costs Including Construction Management, Gross Receipts Taxes, AFUDC, and Other PNM Costs [Member] | Minimum [Member] | San Juan Generating Station [Member]

Public Utilities, General Disclosures [Line Items]

Estimated installation capital costs

$ 85,000,000

Estimated portion of total capital costs if requirement occurred

105,000,000

Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | Installation Costs Including Construction Management, Gross Receipts Taxes, AFUDC, and Other PNM Costs [Member] | Maximum [Member] | San Juan Generating Station [Member]

Public Utilities, General Disclosures [Line Items]

Estimated installation capital costs

90,000,000

Estimated portion of total capital costs if requirement occurred

110,000,000

Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | Installation Costs Including Construction Management, Gross Receipts Taxes, AFUDC, and Other PNM Costs [Member] | Maximum [Member] | San Juan Generating Station Units 1 and 4 [Member]

Public Utilities, General Disclosures [Line Items]

Estimated installation capital costs

$ 82,000,000

Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | Scenario, Plan [Member] | San Juan Generating Station Units 1 and 4 [Member]

Public Utilities, General Disclosures [Line Items]

Ownership percentage

66.30%

Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | Scenario, Plan [Member] | San Juan Generating Station Unit 4 [Member]

Public Utilities, General Disclosures [Line Items]

Ownership percentage

77.30%

Clean Air Act, SNCR [Member] | PNMR and PNM [Member] | Palo Verde Nuclear Generating Station Unit 3 [Member]

Public Utilities, General Disclosures [Line Items]

Number of megawatts | MW

134

134

Proposed value per kilowatt (in dollars per kilowatt) | $ / kw

2,500

Clean Air Act, SNCR [Member] | PNMR Development [Member] | San Juan Generating Station Unit 4 [Member]

Public Utilities, General Disclosures [Line Items]

Additional ownership to be obtained (in megawatts) | MW

65

Reimbursement amount

$ 600,000

Potential acquisition of ownership (in megawatts) | MW

65

Restructuring fee

$ 3,100,000

Clean Air Act, SNCR Hearing Examiner Recommended Denial [Member] | Public Service Company of New Mexico [Member] | San Juan Generating Station Unit 4 [Member]

Public Utilities, General Disclosures [Line Items]

Additional ownership to be obtained (in megawatts) | MW

132

Clean Air Act, Post-2022 Coal Supply future rate case [Member] | Public Service Company of New Mexico [Member] | San Juan Generating Station Unit 4 [Member]

Public Utilities, General Disclosures [Line Items]

Period of time for stipulation agreement

6 months

Clean Air Act Related to Post Combustion Controls [Member] | Public Service Company of New Mexico [Member] | Four Corners [Member]

Public Utilities, General Disclosures [Line Items]

Number of compliance alternatives | compliance_alternative

2

Government standard emissions limit (in pounds per MMBTU) | lb / MMBTU

0.015

Plant requirement to meet opacity limit

20.00%

Rule imposes opacity limitation on certain fugitive dust emissions from coal and material handling operations

20.00%

Estimate of possible loss

$ 90,400,000

Clean Air Act Related to Post Combustion Controls [Member] | Public Service Company of New Mexico [Member] | Four Corners Units 4 and 5 (Coal) [Member]

Public Utilities, General Disclosures [Line Items]

Ownership percentage

13.00%

Clean Power Plan [Member]

Public Utilities, General Disclosures [Line Items]

Period of potential extension to submit initial plans to meet environmental targets

2 years

Number of states that filed a petition against the Clean Power Plan | state

29

Proposed percentage reduction in CO2 emissions

32.00%

Period of time currently remaining to submit initial plans to meet environmental targets

6 months

Period of time currently remaining to submit initial plans to meet environmental targets, including potential extension

2 years 6 months

Commitments and Contingencie100

Commitments and Contingencies - National Ambient Air Quality Standards (Details) - Public Service Company of New Mexico [Member]	Feb. 25, 2016	Mar. 02, 2015lb / MMBTUT	Oct. 01, 2015parts_per_billion	Sep. 30, 2015parts_per_billion	May 14, 2015lb / MMBTU	Jan. 31, 2010parts_per_billion
Minimum [Member] | San Juan Generating Station And Four Corners [Member]
Public Utilities, General Disclosures [Line Items]
Proposed government standard emission limit (in parts per billion)						60
Maximum [Member] | San Juan Generating Station And Four Corners [Member]
Public Utilities, General Disclosures [Line Items]
Proposed government standard emission limit (in parts per billion)						70
Government standard emissions limit (in parts per billion)			70	75
National Ambient Air Quality Standards, 2015 EPA Legal Settlement [Member]
Public Utilities, General Disclosures [Line Items]
Period of time to act on settlement		16 months
Emissions tons of SO2 per year | T		16,000
National Ambient Air Quality Standards, 2015 EPA Legal Settlement [Member] | Minimum [Member]
Public Utilities, General Disclosures [Line Items]
Emissions tons of SO2 per year | T		2,600
SO2 emissions rate (in pounds per MMBTU) | lb / MMBTU		0.45
National Ambient Air Quality Standards [Member] | San Juan Generating Station [Member]
Public Utilities, General Disclosures [Line Items]
Revised SO2 emissions agreed upon (in pounds per MMBTU) | lb / MMBTU					0.10
National Ambient Air Quality Standards, Proposed 2016 SO2 Rule [Member]
Public Utilities, General Disclosures [Line Items]
Period of time from state designation to provide implementation plans	36 months

Commitments and Contingencie101

Commitments and Contingencies - Clean Air Act, Lawsuits (Details) - USD ($) $ in Millions	Aug. 17, 2015	May 31, 2010
Public Service Company of New Mexico [Member] | San Juan Generating Station [Member] | Mercury Control [Member]
Loss Contingencies [Line Items]
Current annual mercury control costs		$ 0.7
Public Service Company of New Mexico [Member] | San Juan Generating Station [Member] | Mercury Control [Member] | Maximum [Member]
Loss Contingencies [Line Items]
Contingent estimated annual mercury control cost		$ 6.6
Public Service Company of New Mexico [Member] | Four Corners Units 4 and 5 (Coal) [Member] | Clean Air Act Lawsuit [Member]
Loss Contingencies [Line Items]
Litigation settlement, amount	$ 1.5
Litigation settlement, expected capital spend, environmental	$ 6.7
Ownership percentage	13.00%
Former Four Corners Co-Owner [Member] | Four Corners Units 4 and 5 (Coal) [Member] | Clean Air Act Lawsuit [Member]
Loss Contingencies [Line Items]
Litigation settlement, expected capital spend, environmental	$ 3.2
Current Four Corners Co-Owners [Member] | Four Corners Units 4 and 5 (Coal) [Member] | Clean Air Act Lawsuit [Member]
Loss Contingencies [Line Items]
Litigation settlement, expected capital spend, environmental	$ 3.5

Commitments and Contingencie102

Commitments and Contingencies - WEG v. OSM NEPA Lawsuit (Details) - Public Service Company of New Mexico [Member] - WEG v OSM Lawsuit [Member]	Feb. 28, 2013stateminelawsuit
Loss Contingencies [Line Items]
Number of mines affected | mine	7
Number of states | state	4
Number of claims filed for relief (in lawsuits)	15
San Juan Generating Station [Member]
Loss Contingencies [Line Items]
Number of claims filed for relief (in lawsuits)	2

Commitments and Contingencie103

Commitments and Contingencies - Hazardous Air Pollutants Rulemaking (Details) - Public Service Company of New Mexico [Member] - San Juan Generating Station [Member] - MW	Dec. 31, 2016	Dec. 31, 2011
Public Utilities, General Disclosures [Line Items]
Minimum megawatt capacity from coal and oil-fired electric generating units under jurisdiction of the Mercury and Air Toxics Standards (in megawatts)		25
Mercury removal efficiency	99.00%

Commitments and Contingencie104

Commitments and Contingencies - Coal Supply (Details)	Feb. 01, 2017USD ($)	Feb. 01, 2016USD ($)	Jan. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Jul. 31, 2016USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Feb. 21, 2017USD ($)	Jul. 19, 2016USD ($)	Jul. 07, 2016payment	Jun. 30, 2016	Apr. 30, 2016USD ($)	Mar. 31, 2016USD ($)
Other Commitments [Line Items]
Other current assets				$ 82,104,000		$ 73,444,000	$ 82,104,000
Regulatory disallowances and restructuring costs						15,011,000	167,471,000	$ 1,062,000
Funds contributed to mine reclamation trust					$ 1,900,000
San Juan Generating Station [Member] | Coal Supply [Member]
Other Commitments [Line Items]
Replacement reclamation bonds										$ 118,700,000
Public Service Company of New Mexico [Member]
Other Commitments [Line Items]
Other current assets				74,990,000		67,355,000	74,990,000
Regulatory disallowances and restructuring costs						15,011,000	167,471,000	1,062,000
Regulatory assets				342,910,000		368,855,000	342,910,000
Public Service Company of New Mexico [Member] | Increase in coal mine decommissioning liability [Member]
Other Commitments [Line Items]
Net expense						4,500,000
Public Service Company of New Mexico [Member] | Loss on long-term purchase commitment [Member] | San Juan Generating Station [Member]
Other Commitments [Line Items]
Annual funding post-term reclamation trust						7,000,000	4,300,000	$ 1,000,000
Public Service Company of New Mexico [Member] | Mine Reclamation Trust [Member]
Other Commitments [Line Items]
Reclamation trust funding, year 3						8,700,000
Public Service Company of New Mexico [Member] | Mine Reclamation Trust [Member] | San Juan Generating Station [Member]
Other Commitments [Line Items]
Reclamation trust funding, next fiscal year						7,800,000
Reclamation trust funding, year 2						8,300,000
Public Service Company of New Mexico [Member] | Mine Reclamation Trust [Member] | Four Corners [Member]
Other Commitments [Line Items]
Reclamation trust funding, next fiscal year						2,000,000
Reclamation trust funding, year 2						2,000,000
Reclamation trust funding, year 3						2,100,000
Number of annual installments (in payments) | payment											13
Public Service Company of New Mexico [Member] | Surface [Member]
Other Commitments [Line Items]
Regulatory assets						100,000,000
Public Service Company of New Mexico [Member] | Surface [Member] | Loss on long-term purchase commitment [Member]
Other Commitments [Line Items]
Liability for interim storage costs				38,800,000		41,000,000	38,800,000
Capped amount that can be collected from retail customers for final reclamation						100,000,000
Public Service Company of New Mexico [Member] | Underground [Member] | Loss on long-term purchase commitment [Member]
Other Commitments [Line Items]
Liability for interim storage costs				11,400,000		14,000,000	11,400,000
Public Service Company of New Mexico [Member] | San Juan Generating Station [Member] | Surface [Member] | Loss on long-term purchase commitment [Member]
Other Commitments [Line Items]
Regulatory disallowances and restructuring costs				16,500,000			16,500,000
Estimate of possible loss						102,000,000
Public Service Company of New Mexico [Member] | San Juan Generating Station [Member] | Underground [Member] | Loss on long-term purchase commitment [Member]
Other Commitments [Line Items]
Estimate of possible loss						127,800,000
Public Service Company of New Mexico [Member] | San Juan Generating Station [Member] | Coal Supply [Member]
Other Commitments [Line Items]
Other current assets				$ 49,000,000		48,700,000	$ 49,000,000
Estimated increase in coal cost												48.00%
NM Capital [Member] | BTMU Term Loan Agreement [Member]
Other Commitments [Line Items]
Long-term debt		$ 125,000,000				92,200,000
NM Capital [Member] | BTMU Term Loan Agreement [Member] | Subsequent Event [Member]
Other Commitments [Line Items]
Long-term debt									$ 82,800,000
NM Capital [Member] | San Juan Generating Station [Member] | Coal Supply [Member]
Other Commitments [Line Items]
Funding provided		$ 125,000,000	$ 125,000,000
Variable interest rate		7.25%
Coal mine reclamation bonds to be posted with NMMMD													$ 118,700,000	$ 161,600,000
Cash used to support bank letter or credit arrangement			30,300,000							$ 30,300,000			$ 40,000,000
NM Capital [Member] | San Juan Generating Station [Member] | Coal Supply [Member] | Subsequent Event [Member] | Westmoreland San Juan [Member]
Other Commitments [Line Items]
Principal payment received	$ 9,600,000
NM Capital [Member] | San Juan Coal Company, Westmoreland [Member] | Coal Supply [Member]
Other Commitments [Line Items]
Amount outstanding			$ 125,000,000			95,000,000
Prepayment penalty						$ 0
NM Capital [Member] | San Juan Coal Company, Westmoreland [Member] | Coal Supply [Member] | Subsequent Event [Member]
Other Commitments [Line Items]
Amount outstanding									$ 85,400,000

Commitments and Contingencie105

Commitments and Contingencies - Mining Royalty Rate (Details) - Continuous Highwall Mining [Member] - San Juan Generating Station [Member] - USD ($) $ in Millions	Aug. 31, 2013	Aug. 31, 2006	Dec. 31, 2003
Public Utilities, General Disclosures [Line Items]
Proposed retroactive surface mining royalty rate	12.50%
Surface mining royalty rate applied between 2000 and 2003			8.00%
Estimated underpaid surface mining royalties under proposed rate change		$ 5
PNM's share of estimated underpaid surface mining royalties under proposed rate change		46.30%

Commitments and Contingencie106

Commitments and Contingencies - Arbitration (Details) - SJCC Arbitration [Member] - San Juan Generating Station [Member] $ in Millions	May 31, 2014USD ($)
Loss Contingencies [Line Items]
Potential unbilled mining costs owed to SJCC	$ 5.2
Potential overbilled mining costs SJCC owes to SJGS owners	1.1
Potential capital improvements billed as mining costs to SJGS owners	$ 13.9
Public Service Company of New Mexico [Member]
Loss Contingencies [Line Items]
PNM's share of arbitration ruling	46.30%
FFPAC percentage of mining costs overbilled or unbilled ruled by arbitration	33.00%

Commitments and Contingencie107

Commitments and Contingencies - Tax Assessment (Details) - Four Corners [Member] - NMTRD Coal Severance Tax [Member] - USD ($) $ in Millions	Mar. 31, 2016	May 23, 2013
Public Utilities, General Disclosures [Line Items]
Assessed coal severance surtax penalty and interest		$ 30
Payment of settlement	$ 0.1

Commitments and Contingencie108

Commitments and Contingencies - Liability and Insurance Matters (Details) - Public Service Company of New Mexico [Member] - Palo Verde Nuclear Generating Station [Member]	12 Months Ended
	Dec. 31, 2016USD ($)generating_unit
Public Utilities, General Disclosures [Line Items]
Number of units (in generating units) | generating_unit	3
Nuclear Plant [Member]
Public Utilities, General Disclosures [Line Items]
Ownership percentage in nuclear reactor	10.20%
Number of units (in generating units) | generating_unit	3
Maximum potential assessment per incident	$ 38,900,000
Annual payment limitation related to incident	5,800,000
Aggregate amount of all risk insurance	2,750,000,000
Sublimit amount for non-nuclear property damage losses	2,250,000,000
Retrospective premium assessment	5,400,000
Nuclear Plant [Member] | Commercial Providers [Member]
Public Utilities, General Disclosures [Line Items]
Liability insurance coverage	450,000,000
Nuclear Plant [Member] | Industry Wide Retrospective Assessment Program [Member]
Public Utilities, General Disclosures [Line Items]
Liability insurance coverage	13,000,000,000
Nuclear Plant [Member] | Maximum [Member]
Public Utilities, General Disclosures [Line Items]
Liability insurance coverage	$ 13,400,000,000

Commitments and Contingencie109

Commitments and Contingencies - Water Supply (Details) - Public Service Company of New Mexico [Member] - Palo Verde Nuclear Generating Station [Member]	1 Months Ended
	Apr. 30, 2010city
Public Utilities, General Disclosures [Line Items]
Providing water to a number of cities	5
Providing water, term	40 years

Commitments and Contingencie110

Commitments and Contingencies - Right-of-Way, Complaints, and Navajo National Allottee Matters (Details) $ in Millions	Jan. 04, 2016	Oct. 29, 2015USD ($)	Dec. 01, 2015Allotment_Parcel	Jul. 13, 2015a	Jan. 22, 2015Allotment_Parcel	Apr. 02, 2014landownerAllotment_Parcel	Feb. 27, 2014lawsuit	Jan. 06, 2014Allotment_Parcel	Sep. 30, 2012landowner
SPS Complaint, Federal Power Act [Member] | Public Service Company of New Mexico [Member]
Loss Contingencies [Line Items]
Amount received, including interest, under settlement | $		$ 4.2
Settlement amount passed back to customers | $		$ 2.6
Navajo Nation Allottee Matters [Member] | Public Service Company of New Mexico [Member]
Loss Contingencies [Line Items]
Number of landowners claiming to be Navajo allottees (in landowners) | landowner						43			43
Number of appraisals requested for review (in allotment parcels)								58
Number of allotments where landowners are revoking rights of way renewal consents (in allotment parcels)						6
Allotments with right-of-way renewals not previously contested (in allotment parcels)					10
Acres of land at issue (in acres) | a				15.49
Number of allotment parcels that cannot be condemned			2
Number of allotment parcels at issue			5
Pending Litigation [Member]
Loss Contingencies [Line Items]
Number of claims (in lawsuits) | lawsuit							2
Written notification requirement to terminate agreement, minimum period	30 days
Settled Litigation [Member]
Loss Contingencies [Line Items]
Number of claims (in lawsuits) | lawsuit							1

Regulatory and Rate Matters - N

Regulatory and Rate Matters - New Mexico General Rate Cases (Details) $ in Millions	Dec. 07, 2016USD ($)	Sep. 30, 2016	Sep. 28, 2016USD ($)MW	Aug. 04, 2016USD ($)MW	Jan. 15, 2016USD ($)leaseMW	Aug. 27, 2015USD ($)	Jan. 15, 2015	Dec. 11, 2014USD ($)	Sep. 30, 2016USD ($)	Dec. 31, 2016USD ($)	May 31, 2016MW
NMPRC [Member]
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease)	$ 99.2
Requested return on equity	10.125%
Public Service Company of New Mexico [Member] | Clean Air Act, Balanced Draft Technology [Member] | San Juan Generating Station Units 1 and 4 [Member]
Public Utilities, General Disclosures [Line Items]
Net book value										$ 50
Public Service Company of New Mexico [Member] | Clean Air Act, Balanced Draft Technology [Member] | San Juan Generating Station Units 1 and 4 [Member] | Installation Costs Including Construction Management, Gross Receipts Taxes, AFUDC, and Other PNM Costs [Member]
Public Utilities, General Disclosures [Line Items]
Portion of costs for SNCRs and BDT equipment				$ 52.3
Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station, Unit 2 Leases [Member]
Public Utilities, General Disclosures [Line Items]
Number of megawatts purchased (in megawatts) | MW					64.1						64.1
Number of leases under which assets were purchased | lease					3
Estimated annual property tax expense				$ 0.8
Number of leases under which lease term was extended | lease					1
Lease term extension period					8 years
Number of megawatts | MW			114.6	114.6
Net book value										76.9
Net book value of capital improvements										39.9
Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station, Unit 1 Leases, extended [Member]
Public Utilities, General Disclosures [Line Items]
Estimated annual property tax expense					$ 1.5
Estimated annual rent expense				$ 18.1
Number of leases under which lease term was extended | lease					4
Lease term extension period							8 years
Public Service Company of New Mexico [Member] | 2014 Electric Rate Case [Member]
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease)								$ 107.4
Public Service Company of New Mexico [Member] | 2015 Electric Rate Case [Member]
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease)						$ 123.5
Requested return on equity						10.50%
Requested rate increase (decrease) in fuel-related costs									$ (42.9)
Change in requested rate increase (decrease) in non-fuel related revenues										(0.2)
Requested rate increase (decrease) in non-fuel related revenue				121.5						121.5
Proposed increase (decrease) in non-fuel revenue				$ 41.3
Proposed return on equity				9.575%
Approved rate increase (decrease)			$ 61.2
Estimated period of time for New Mexico Supreme Court Appeal decision		15 months
Minimum amount of loss of capital cost recovery		15 months
Increase (decrease) of income tax expense										(2.1)
Estimate of possible loss										155.6
Public Service Company of New Mexico [Member] | 2015 Electric Rate Case [Member] | San Juan Generating Station [Member] | Refined Coal [Member]
Public Utilities, General Disclosures [Line Items]
Proposed credit to retail customers				100.00%
Public Service Company of New Mexico [Member] | 2015 Electric Rate Case [Member] | Clean Air Act, Balanced Draft Technology [Member] | San Juan Generating Station Units 1 and 4 [Member]
Public Utilities, General Disclosures [Line Items]
Amount of equipment costs included in rate base				$ 40
Public Service Company of New Mexico [Member] | 2015 Electric Rate Case [Member] | Palo Verde Nuclear Generating Station, Unit 2 Leases [Member]
Public Utilities, General Disclosures [Line Items]
Proposed disallowance of recovery of purchase price of assets				163.3
Approved lease acquisition costs			83.7
Disallowed leasehold improvements			43.8
Pre-tax regulatory disallowance for capital costs										6.8
Public Service Company of New Mexico [Member] | 2015 Electric Rate Case [Member] | Palo Verde Nuclear Generating Station, Unit 1 Leases, extended [Member]
Public Utilities, General Disclosures [Line Items]
Approved recovery of assumed operating and maintenance expense savings annually related to BDT			$ 0.3
Public Service Company of New Mexico [Member] | 2015 Electric Rate Case [Member] | Alvarado square [Member]
Public Utilities, General Disclosures [Line Items]
Proposed disallowance of recovery of assets and deferred charges from retail customers				$ 4.5
Pre-tax regulatory disallowance of costs recorded as regulatory assets and deferred charges										$ 4.5
Public Service Company of New Mexico [Member] | 2015 Electric Rate Case [Member] | Non-Fuel Energy [Member]
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease)						$ 121.7

Regulatory and Rate Matters - P

Regulatory and Rate Matters - Proceeding Regarding Definition of Future Test Year (Details) - 2014 Electric Rate Case [Member] - Public Service Company of New Mexico [Member]	Nov. 30, 2015	Jul. 31, 2015	May 27, 2015
Public Utilities, General Disclosures [Line Items]
Defined future test year as period that begins a period of time following the filing of an application to increase rates (no later than)			45 days
Belief that the correct interpretation of future test year is period time after filing of an application (up to)			13 months
Motion for a temporary stay		30 days
Redefined future test year as period that begins a period of time following the filing of a rate case application (up to)	13 months

Regulatory and Rate Matters - R

Regulatory and Rate Matters - Renewable Portfolio Standard (Details) - Public Service Company of New Mexico [Member] - MW	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Renewable Portfolio Standard [Member]
Public Utilities, General Disclosures [Line Items]
Solar photovoltaic capacity (in mw)	107	40	23
Current output of solar photovoltaic capacity (in mw)			4
Solar distributed generation (in mw)	62.7
Renewable Portfolio Standard [Member] | Minimum [Member]
Public Utilities, General Disclosures [Line Items]
Reasonable cost threshold	3.00%
Renewable Portfolio Standard [Member] | Minimum [Member] | Wind [Member]
Public Utilities, General Disclosures [Line Items]
Required percentage of diversification	30.00%
Renewable Portfolio Standard [Member] | Minimum [Member] | Solar [Member]
Public Utilities, General Disclosures [Line Items]
Required percentage of diversification	20.00%
Renewable Portfolio Standard [Member] | Minimum [Member] | Distributed Generation [Member]
Public Utilities, General Disclosures [Line Items]
Required percentage of diversification	3.00%
Renewable Portfolio Standard [Member] | Minimum [Member] | Other [Member]
Public Utilities, General Disclosures [Line Items]
Required percentage of diversification	5.00%
Renewable Portfolio Standard [Member] | Required Percentage by 2011 [Member]
Public Utilities, General Disclosures [Line Items]
Required percentage of renewable energy in portfolio to electric sales	10.00%
Renewable Portfolio Standard [Member] | Required Percentage by 2015 [Member]
Public Utilities, General Disclosures [Line Items]
Required percentage of renewable energy in portfolio to electric sales	15.00%
Renewable Portfolio Standard [Member] | Required Percentage by 2020 [Member]
Public Utilities, General Disclosures [Line Items]
Required percentage of renewable energy in portfolio to electric sales	20.00%
Renewable Portfolio Standard Supplemental Procurement [Member]
Public Utilities, General Disclosures [Line Items]
Solar photovoltaic capacity (in mw)				1.5
Renewable Portfolio Standard 2014 [Member]
Public Utilities, General Disclosures [Line Items]
Wind energy capacity (in mw)	204	102
Wind capacity, planned purchase agreement, term		20 years

Regulatory and Rate Matters 114

Regulatory and Rate Matters - Renewable Energy Rider (Details) - Public Service Company of New Mexico [Member] - Renewable Energy Rider [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Public Utilities, General Disclosures [Line Items]
Revenue from renewable energy rider	$ 42	$ 41.9	$ 31.9
Maximum [Member]
Public Utilities, General Disclosures [Line Items]
Annual revenue to be collected	42.4
Proposed collection through energy rider	$ 50
NMPRC-approved return on equity	0.50%		10.50%
Initial approved return on equity	10.00%

Regulatory and Rate Matters - E

Regulatory and Rate Matters - Energy Efficiency and Load Management (Details) - Public Service Company of New Mexico [Member] $ in Millions	Sep. 29, 2016USD ($)	Apr. 15, 2016USD ($)GWhprogram	Oct. 06, 2014USD ($)	Jan. 31, 2015USD ($)	Nov. 30, 2013	Oct. 31, 2012USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Dec. 31, 2016	Jan. 30, 2015USD ($)
Energy Efficiency and Load Management [Member] | Disincentives/Incentives Added [Member]
Public Utilities, General Disclosures [Line Items]
Program costs related to energy efficiency						$ 22.5
Authorization to recover an incentive equal to a percentage of annual program costs					7.60%
Annual incentive								$ 1.7
2014 Energy Efficiency and Load Management Program [Member] | Disincentives/Incentives Added [Member]
Public Utilities, General Disclosures [Line Items]
Program costs related to energy efficiency			$ 25.8
Proposed energy efficiency incentive							$ 2.1
Anticipated future profit incentive 2015										$ 1.7
Anticipated future profit incentive 2016										$ 1.8
2017 Energy Efficiency and Load Management Program [Member] | Disincentives/Incentives Added [Member]
Public Utilities, General Disclosures [Line Items]
Program costs related to energy efficiency	$ 26	$ 28
Number of energy efficiency and load management programs (in programs) | program		10
Application of incentive based on target savings		$ 2.4
Energy efficiency targeted savings (in gwh) | GWh		75
Minimum profit incentive	$ 1.8			$ 1.8
Maximum [Member] | Renewable Portfolio Standard [Member]
Public Utilities, General Disclosures [Line Items]
Reasonable cost threshold	3.00%							3.00%
Sliding scale profit incentive	9.00%
Minimum [Member] | Renewable Portfolio Standard [Member]
Public Utilities, General Disclosures [Line Items]
Reasonable cost threshold									3.00%
Sliding scale profit incentive	7.10%

Regulatory and Rate Matters - F

Regulatory and Rate Matters - FPPAC Continuation Application (Details) - FPPAC Continuation Application [Member] - Public Service Company of New Mexico [Member] - USD ($) $ in Millions	Apr. 30, 2014	Apr. 23, 2014	Dec. 31, 2013
Public Utilities, General Disclosures [Line Items]
Retention percentage of sales margins		10.00%
Under-collected balance write-off			$ 10.5
Under-collected balance to be recovered	$ 63.5
Period of time to collect		18 months

Regulatory and Rate Matters - I

Regulatory and Rate Matters - Integrated Resource Plan (Details) - portfolio	May 04, 2016	Jul. 01, 2014	Dec. 31, 2017	Dec. 31, 2016
NMPRC [Member]
Public Utilities, General Disclosures [Line Items]
Period of action plan				4 years
Public Service Company of New Mexico [Member]
Public Utilities, General Disclosures [Line Items]
Required filing of Integrated Resource Plan				3 years
Planning period covered, IRP				20 years
Public Service Company of New Mexico [Member] | Scenario, Forecast [Member]
Public Utilities, General Disclosures [Line Items]
Planning period covered, IRP			20 years
Period of action plan			4 years
Number of resource portfolios (in portfolio)			2
Public Service Company of New Mexico [Member] | Scenario, Forecast [Member] | San Juan Generating Station [Member]
Public Utilities, General Disclosures [Line Items]
Number of continued operations resource portfolios (in portfolio)			1
Number of discontinued operations resource portfolios (in portfolio)			1
Public Service Company of New Mexico [Member] | NMPRC [Member]
Public Utilities, General Disclosures [Line Items]
Period of action plan		4 years
Period of time to show good cause why a docket should remain open	30 days

Regulatory and Rate Matters - A

Regulatory and Rate Matters - Application for Certificate of Convenience and Necessity (Details) - San Juan Generating Station Units 2 and 3 [Member] - Clean Air Act, SNCR [Member] - Public Service Company of New Mexico [Member] - MW	Apr. 26, 2016	Jun. 30, 2015
Public Utilities, General Disclosures [Line Items]
Newly-identified replacement gas plant (in mw)	80	187
Additional peaking capacity (in mw)	40

Regulatory and Rate Matters 119

Regulatory and Rate Matters - Advanced Metering Infrastructure Application and Facebook Data Center Project (Details) $ in Millions	Jul. 08, 2016service_rateMW	Feb. 26, 2016USD ($)
Public Utilities, General Disclosures [Line Items]
Number of requested service rates | service_rate	2
Public Service Company of New Mexico [Member] | Advanced metering infrastructure [Member]
Public Utilities, General Disclosures [Line Items]
Application to seek recovery of costs of project | $		$ 87.2
Application to seek recovery of undepreciated investment | $		$ 33
PNMR Development [Member]
Public Utilities, General Disclosures [Line Items]
Solar distributed generation (in mw) | MW	30
Solar capacity (in mw) | MW	10

Regulatory and Rate Matters - H

Regulatory and Rate Matters - Hazard Sharing Agreement (Details) - Public Service Company of New Mexico [Member] - Tri-State [Member] $ in Millions	Nov. 30, 2016	Jun. 01, 2016MW	Dec. 31, 2016USD ($)MWh
Public Utilities, General Disclosures [Line Items]
Hazard sharing agreement		1 year
Agreement to sell the other party capacity and energy (in mw) | MW		100
Number of megawatt hours sold (in mwh) | MWh			482,342
Megawatt hours sold | $			$ 12.8
Number of megawatt hours purchased (in mwh) | MWh			484,632
Megawatt hours purchased | $			$ 12.9
NMPRC [Member]
Public Utilities, General Disclosures [Line Items]
Hazard sharing agreement	5 years		5 years

Regulatory and Rate Matters 121

Regulatory and Rate Matters - Formula Transmission Rate Case (Details) - Public Service Company of New Mexico [Member] $ in Millions	Mar. 20, 2015USD ($)party	Mar. 01, 2013	Dec. 31, 2012USD ($)
Wholesale Electric Transmission Rate Case [Member] [Member]
Public Utilities, General Disclosures [Line Items]
Approved rate increase (decrease)			$ 3.2
Initial approved return on equity			10.81%
Lease ownership in EIP		60.00%
Approved additional rate increase	$ 1.3
Formula Transmission Rate Case [Member]
Public Utilities, General Disclosures [Line Items]
Number of additional parties entered into settlement agreement (in parties) | party	5
Return on equity	10.00%

Regulatory and Rate Matters 122

Regulatory and Rate Matters - Firm-Requirements Wholesale Customers (Details) - Public Service Company of New Mexico [Member] $ in Millions	Dec. 06, 2012USD ($)	Jun. 30, 2015USD ($)	Jun. 30, 2014USD ($)	Dec. 31, 2017MW	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Firm Requirements Wholesale Power Rate Case, Navopache [Member] [Member]
Public Utilities, General Disclosures [Line Items]
Approved rate increase (decrease)	$ 5.3
Revenue for power sold under specific contract					$ 20	$ 27.1	$ 28.4
Firm Requirements Wholesale Power Rate Case, Navopache [Member] [Member] | Scenario, Forecast [Member]
Public Utilities, General Disclosures [Line Items]
Serving megawatts of load under a lower tariff (in mw) | MW				10
Firm Requirements Wholesale Power Rate Case [Member]
Public Utilities, General Disclosures [Line Items]
Contract extension	10 years
Firm Requirements Wholesale Power Contract, Gallup [Member]
Public Utilities, General Disclosures [Line Items]
Revenue for power sold under specific contract			$ 6.1
City of Gallup, New Mexico Contract [Member]
Public Utilities, General Disclosures [Line Items]
Gain on sale of substation		$ 1.1

Regulatory and Rate Matters - T

Regulatory and Rate Matters - TNMP Narrative (Details) - Texas-New Mexico Power Company [Member] advanced_meter in Thousands	Jan. 20, 2017USD ($)	Jul. 31, 2011USD ($)	Dec. 31, 2016USD ($)advanced_meter	Feb. 21, 2017customer	Oct. 02, 2015USD ($)	Jun. 20, 2014USD ($)	Aug. 15, 2013USD ($)customer
Advanced Meter System Deployment and Surcharge Request [Member]
Public Utilities, General Disclosures [Line Items]
Approved deployment costs		$ 113,400,000
Period of time to collect deployment costs through surcharge period		12 years
Number of advanced meters installed | advanced_meter			242
Non-standard metering service cost total to be borne by opt-out customers							$ 200,000
Non-standard metering ongoing annual expenses to be borne by opt-out customers							$ 500,000
Non-standard metering ongoing expenses monthly charge						$ 36.78
Presumed number of customers that will elect non-standard meter service (in customers) | customer							1,081
Cost and savings reconciliation filed with regulators, capital cost savings					$ 71,000,000
Cost and savings reconciliation filed with regulators, operations and maintenance expense					$ 18,000,000
Program costs incurred to date			$ 1,500,000
Advanced Meter System Deployment and Surcharge Request [Member] | Subsequent Event [Member]
Public Utilities, General Disclosures [Line Items]
Current number of customers that have elected non-standard meter service (in customers) | customer				104
Advanced Meter System Deployment and Surcharge Request [Member] | Minimum [Member]
Public Utilities, General Disclosures [Line Items]
Non-standard metering service cost initial fee range							$ 63.97
Advanced Meter System Deployment and Surcharge Request [Member] | Maximum [Member]
Public Utilities, General Disclosures [Line Items]
Non-standard metering service cost initial fee range							$ 168.61
Transmission Cost of Service Rates [Member] | Subsequent Event [Member]
Public Utilities, General Disclosures [Line Items]
Requested increase in annual transmission service revenue	$ 4,800,000
Requested rate increase (decrease)	$ 30,200,000

Regulatory and Rate Matters 124

Regulatory and Rate Matters - TNMP Schedules (Details) - Texas-New Mexico Power Company [Member] - USD ($) $ in Millions	Sep. 08, 2016	Mar. 23, 2016	Sep. 10, 2015	Sep. 09, 2015	Mar. 15, 2015	Sep. 07, 2014	Feb. 28, 2018	Feb. 28, 2017	Feb. 29, 2016	Feb. 28, 2015
Energy Efficiency [Member]
Public Utilities, General Disclosures [Line Items]
Aggregate Collection Amount									$ 5.7	$ 5.6
Performance Bonus									$ 1.5	$ 0.7
Energy Efficiency [Member] | Scenario, Forecast [Member]
Public Utilities, General Disclosures [Line Items]
Aggregate Collection Amount							$ 6	$ 6
Performance Bonus							$ 0.8	$ 0.7
Transmission Cost of Service Rates [Member]
Public Utilities, General Disclosures [Line Items]
Approved Increase in Rate Base	$ 9.5	$ 25.8	$ 7	$ 27.1	$ 25.2	$ 18.2
Annual Increase in Revenue	$ 1.8	$ 4.3	$ 1.4	$ 4.4	$ 4.2	$ 2.9

Goodwill (Details)

Goodwill (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2008	Dec. 31, 2016	Apr. 01, 2016	Dec. 31, 2015	Apr. 01, 2015	Dec. 31, 2014	Apr. 01, 2014	Apr. 01, 2012
Schedule of Goodwill and Other Intangible Assets [Line Items]
Goodwill		$ 278,297		$ 278,297		$ 278,297
Goodwill impairment	$ 174,400
Public Service Company of New Mexico [Member]
Schedule of Goodwill and Other Intangible Assets [Line Items]
Goodwill		51,632	$ 51,600	51,632	$ 51,600		$ 51,600
Percentage of fair value in excess of carrying amount			25.00%		25.00%	30.00%
Percentage increase in expected return on equity			0.50%		0.50%		0.50%
Reduced percentage of fair value in excess of carrying value			18.00%		18.00%		23.00%
Goodwill impairment	51,100
Texas-New Mexico Power Company [Member]
Schedule of Goodwill and Other Intangible Assets [Line Items]
Goodwill		$ 226,665	$ 226,700	$ 226,665
Percentage of fair value in excess of carrying amount			32.00%					26.00%
Percentage increase in expected return on equity			0.50%
Reduced percentage of fair value in excess of carrying value			21.00%
Goodwill impairment	$ 34,500

Accumulated Other Comprehens126

Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	$ 1,654,813
Amounts reclassified from AOCI (pre-tax)	(15,871)	$ (22,579)	$ (8,152)
Income tax impact of amounts reclassified	6,193	8,849	3,234
Other OCI changes (pre-tax)	(18,597)	6,665	2,038
Income tax impact of other OCI changes	7,256	(2,612)	(735)
Total Other Comprehensive Income (Loss)	(21,019)	(9,677)	$ (3,615)
Ending Balance	$ 1,675,952	$ 1,654,813
Percentage of pension liability adjustment capitalized into construction work in process	23.40%	22.20%	24.40%
Percentage of pension liability adjustment capitalized into other accounts	2.40%	2.40%	2.00%
Public Service Company of New Mexico [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	$ 1,317,933
Amounts reclassified from AOCI (pre-tax)	(16,635)	$ (22,579)	$ (8,710)
Income tax impact of amounts reclassified	6,491	8,849	3,429
Other OCI changes (pre-tax)	(17,723)	6,593	2,191
Income tax impact of other OCI changes	6,915	(2,584)	(788)
Total Other Comprehensive Income (Loss)	(20,952)	(9,721)	(3,878)
Ending Balance	1,397,872	1,317,933
Texas-New Mexico Power Company [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	533,380	524,665	502,931
Total Other Comprehensive Income (Loss)	0	0	263
Ending Balance	593,235	533,380	524,665
Unrealized Gain on Available-for-Sale Securities [Member] | Public Service Company of New Mexico [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	17,346	28,008	25,748
Amounts reclassified from AOCI (pre-tax)	(22,139)	(28,531)	(13,862)
Income tax impact of amounts reclassified	8,639	11,181	5,461
Other OCI changes (pre-tax)	778	10,998	17,473
Income tax impact of other OCI changes	(304)	(4,310)	(6,812)
Total Other Comprehensive Income (Loss)	(13,026)	(10,662)	2,260
Ending Balance	4,320	17,346	28,008
Pension Liability Adjustment [Member] | Public Service Company of New Mexico [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	(88,822)	(89,763)	(83,625)
Amounts reclassified from AOCI (pre-tax)	5,504	5,952	5,152
Income tax impact of amounts reclassified	(2,148)	(2,332)	(2,032)
Other OCI changes (pre-tax)	(18,501)	(4,405)	(15,282)
Income tax impact of other OCI changes	7,219	1,726	6,024
Total Other Comprehensive Income (Loss)	(7,926)	941	(6,138)
Ending Balance	(96,748)	(88,822)	(89,763)
Fair Value Adjustment for Cash Flow Hedges [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	44	0	0
Amounts reclassified from AOCI (pre-tax)	764	0	0
Income tax impact of amounts reclassified	(298)	0	0
Other OCI changes (pre-tax)	(874)	72	0
Income tax impact of other OCI changes	341	(28)	0
Total Other Comprehensive Income (Loss)	(67)	44	0
Ending Balance	(23)	44	0
Fair Value Adjustment for Cash Flow Hedges [Member] | Texas-New Mexico Power Company [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	0	0	(263)
Amounts reclassified from AOCI (pre-tax)	0	0	558
Income tax impact of amounts reclassified	0	0	(195)
Other OCI changes (pre-tax)	0	0	(153)
Income tax impact of other OCI changes	0	0	53
Total Other Comprehensive Income (Loss)	0	0	263
Ending Balance	0	0	0
Total [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	(71,432)	(61,755)	(58,140)
Total Other Comprehensive Income (Loss)	(21,019)	(9,677)	(3,615)
Ending Balance	(92,451)	(71,432)	(61,755)
Total [Member] | Public Service Company of New Mexico [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	(71,476)	(61,755)	(57,877)
Total Other Comprehensive Income (Loss)	(20,952)	(9,721)	(3,878)
Ending Balance	$ (92,428)	$ (71,476)	(61,755)
Total [Member] | Texas-New Mexico Power Company [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance			(263)
Total Other Comprehensive Income (Loss)			$ 263

Quarterly Operating Results 127

Quarterly Operating Results (Unaudited) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Segment Reporting Information [Line Items]
Operating revenues	$ 336,225	$ 400,374	$ 315,391	$ 310,961	$ 335,894	$ 417,433	$ 352,887	$ 332,868	$ 1,362,951	$ 1,439,082	$ 1,435,853
Operating income (loss)	63,584	108,071	64,822	41,508	(119,138)	121,505	72,414	49,569	277,985	124,350	299,697
Net earnings (loss)	28,423	58,556	30,952	13,965	(87,284)	64,855	35,655	17,852	131,896	31,078	130,909
Earnings Attributable to PNMR	$ 24,809	$ 54,418	$ 27,076	$ 10,546	$ (91,418)	$ 61,045	$ 31,673	$ 14,340	$ 116,849	$ 15,640	$ 116,254
Net Earnings Attributable to PNMR per Common Share:
Basic (dollars per share)	$ 0.32	$ 0.68	$ 0.34	$ 0.13	$ (1.15)	$ 0.77	$ 0.40	$ 0.18	$ 1.47	$ 0.20	$ 1.46
Diluted (dollars per share)	$ 0.31	$ 0.68	$ 0.34	$ 0.13	$ (1.15)	$ 0.76	$ 0.40	$ 0.18	$ 1.46	$ 0.20	$ 1.45
Regulatory disallowances and restructuring costs									$ 15,011	$ 167,471	$ 1,062
Public Service Company of New Mexico [Member]
Segment Reporting Information [Line Items]
Operating revenues	$ 255,685	$ 311,276	$ 233,346	$ 235,606	$ 260,368	$ 333,437	$ 275,450	$ 261,940	1,035,913	1,131,195	1,147,914
Operating income (loss)	42,976	80,057	41,760	23,297	(139,164)	93,710	47,179	31,655	188,090	33,380	212,713
Net earnings (loss)	19,594	44,990	19,793	7,561	(92,245)	53,056	25,363	13,502	91,938	(324)	101,453
Earnings Attributable to PNMR	16,112	40,984	16,049	4,274	(96,247)	49,378	21,513	10,122	77,419	(15,234)	87,326
Net Earnings Attributable to PNMR per Common Share:
Regulatory disallowances and restructuring costs									15,011	167,471	1,062
Public Service Company of New Mexico [Member] | Clean Air Act, SNCR [Member]
Net Earnings Attributable to PNMR per Common Share:
Regulatory disallowances and restructuring costs										21,600
Public Service Company of New Mexico [Member] | Clean Air Act, SNCR [Member] | San Juan Generating Station Units 2 and 3 [Member]
Net Earnings Attributable to PNMR per Common Share:
Regulatory disallowances and restructuring costs										127,600
Public Service Company of New Mexico [Member] | Increase in coal mine decommissioning liability [Member] | Clean Air Act, SNCR [Member] | San Juan Generating Station Units 2 and 3 [Member]
Net Earnings Attributable to PNMR per Common Share:
Regulatory disallowances and restructuring costs										165,700
Texas-New Mexico Power Company [Member]
Segment Reporting Information [Line Items]
Operating revenues									327,038	307,887	287,939
Operating revenues	80,540	89,098	82,045	75,355	75,526	83,996	77,437	70,928
Operating income (loss)	21,353	28,359	23,375	18,554	19,706	27,667	24,729	17,931	91,641	90,033	85,588
Earnings Attributable to PNMR	$ 9,855	$ 13,853	$ 10,508	$ 7,456	$ 8,715	$ 13,689	$ 11,865	$ 7,694	$ 41,672	$ 41,963	$ 37,807

Schedule I - Condensed Finan128

Schedule I - Condensed Financial Information of Parent Company - Statements of Earnings (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Condensed Financial Statements, Captions [Line Items]
Operating Expenses									$ 1,084,966	$ 1,314,732	$ 1,136,156
Operating income	$ 63,584	$ 108,071	$ 64,822	$ 41,508	$ (119,138)	$ 121,505	$ 72,414	$ 49,569	277,985	124,350	299,697
Other Income and Deductions:
Other income									17,796	26,833	12,048
Net other income and deductions									45,822	36,663	20,577
Interest Charges									128,633	114,860	119,627
Earnings before Income Taxes									195,174	46,153	200,647
Income Taxes									63,278	15,075	69,738
Net Earnings Attributable to Company	$ 24,809	$ 54,418	$ 27,076	$ 10,546	$ (91,418)	$ 61,045	$ 31,673	$ 14,340	116,849	15,640	116,254
PNM Resources [Member]
Condensed Financial Statements, Captions [Line Items]
Operating Revenues									0	0	0
Operating Expenses									2,871	1,221	650
Operating income									(2,871)	(1,221)	(650)
Other Income and Deductions:
Equity in earnings of subsidiaries									122,252	27,352	124,543
Other income									1,711	747	622
Net other income and deductions									123,963	28,099	125,165
Interest Charges									8,102	8,275	13,650
Earnings before Income Taxes									112,990	18,603	110,865
Income Taxes									(3,859)	2,963	(5,389)
Net Earnings Attributable to Company									$ 116,849	$ 15,640	$ 116,254

Schedule I - Condensed Finan129

Schedule I - Condensed Financial Information of Parent Company - Statement of Cash flow (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Condensed Financial Statements, Captions [Line Items]
Net Cash Flows From Operating Activities	$ 415,454	$ 386,874	$ 414,876
Cash Flows From Investing Activities:
Net cash flows from investing activities	(699,375)	(544,528)	(485,329)
Cash Flows From Financing Activities:
Short-term loan	100,000	50,000	0
Repayment of short-term loan	(150,000)	0	0
Short-term borrowings (repayments), net	86,500	95,000	(43,600)
Long-term borrowings	603,500	463,605	355,000
Repayment of long-term debt	(303,793)	(333,066)	(125,000)
Proceeds from stock option exercise	7,028	5,619	6,999
Dividends paid	(70,623)	(64,251)	(59,468)
Other, net	2,237	(6,707)	(2,808)
Net cash flows from financing activities	242,392	175,431	96,194
Change in Cash and Cash Equivalents	(41,529)	17,777	25,741
Cash and Cash Equivalents at Beginning of Period	46,051	28,274	2,533
Cash and Cash Equivalents at End of Period	4,522	46,051	28,274
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	115,043	103,382	108,741
Income taxes paid (refunded), net	(307)	(1,890)	(2,597)
PNM Resources [Member]
Condensed Financial Statements, Captions [Line Items]
Net Cash Flows From Operating Activities	5,702	1,375	22,744
Cash Flows From Investing Activities:
Utility plant additions	341	368	(474)
Investments in subsidiaries	(98,343)	(175,000)	0
Cash dividends from subsidiaries	35,959	127,688	46,599
Net cash flows from investing activities	(62,043)	(46,944)	46,125
Cash Flows From Financing Activities:
Short-term loan	100,000	50,000	0
Repayment of short-term loan	(150,000)	0	0
Short-term borrowings (repayments), net	84,500	41,000	600
Long-term borrowings	100,000	150,000
Repayment of long-term debt	0	(118,766)	0
Proceeds from stock option exercise	7,028	5,619	6,999
Purchases to satisfy awards of common stock	(15,451)	(17,720)	(17,319)
Dividends paid	(70,095)	(63,723)	(58,940)
Other, net	(28)	(782)	81
Net cash flows from financing activities	55,954	45,628	(68,579)
Change in Cash and Cash Equivalents	(387)	59	290
Cash and Cash Equivalents at Beginning of Period	441	382	92
Cash and Cash Equivalents at End of Period	54	441	382
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	5,906	7,559	12,152
Income taxes paid (refunded), net	$ 0	$ (730)	$ (2,014)

Schedule I - Condensed Finan130

Schedule I - Condensed Financial Information of Parent Company - Balance Sheets (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Assets
Cash and cash equivalents	$ 4,522	$ 46,051	$ 28,274	$ 2,533
Other, net	73,444	82,104
Total current assets	378,039	385,570
Property, plant and equipment, net of accumulated depreciation of $12,291 and $11,276	4,904,715	4,535,372
Other long-term assets	547	604
Total assets	6,471,080	6,009,328	5,790,237
Liabilities and Stockholders’ Equity
Short-term debt	287,100	250,600
Accrued interest and taxes	61,871	58,306
Other current liabilities	59,314	59,494
Total current liabilities	805,108	641,120
Long-term debt	2,119,364	1,966,969
Total liabilities	4,714,679	4,271,579
Common stock (no par value; 120,000,000 shares authorized; issued and outstanding 79,653,624 shares)	1,163,661	1,166,465
Accumulated other comprehensive income (loss), net of tax	(92,451)	(71,432)
Retained earnings	604,742	559,780
Total PNMR common stockholders’ equity	1,675,952	1,654,813
Total liabilities and stockholders' equity	6,471,080	6,009,328
PNM Resources [Member]
Assets
Cash and cash equivalents	54	441	$ 382	$ 92
Intercompany receivables	92,234	102,676
Other, net	233	524
Total current assets	92,521	103,641
Property, plant and equipment, net of accumulated depreciation of $12,291 and $11,276	26,366	26,707
Investment in subsidiaries	1,986,276	1,822,593
Other long-term assets	79,314	81,168
Total long-term assets	2,091,956	1,930,468
Total assets	2,184,477	2,034,109
Liabilities and Stockholders’ Equity
Short-term debt	226,100	191,600
Short-term debt-affiliate	8,819	8,819
Accrued interest and taxes	1,333	7,780
Other current liabilities	19,374	18,282
Total current liabilities	255,626	226,481
Long-term debt	249,895	149,860
Other long-term liabilities	3,004	2,955
Total liabilities	508,525	379,296
Common stock (no par value; 120,000,000 shares authorized; issued and outstanding 79,653,624 shares)	1,163,661	1,166,465
Accumulated other comprehensive income (loss), net of tax	(92,451)	(71,432)
Retained earnings	604,742	559,780
Total PNMR common stockholders’ equity	1,675,952	1,654,813
Total liabilities and stockholders' equity	$ 2,184,477	$ 2,034,109

Schedule I - Condensed Finan131

Schedule I - Condensed Financial Information of Parent Company - Balance Sheets (Parenthetical) (Details) - USD ($) $ / shares in Units, $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Condensed Financial Statements, Captions [Line Items]
Common stock, no par value (in dollars per share)	$ 0	$ 0
Common stock, shares authorized	120,000,000	120,000,000
Common stock, shares issued	79,653,624	79,653,624
Common stock, shares outstanding	79,653,624	79,653,624
PNM Resources [Member]
Condensed Financial Statements, Captions [Line Items]
Accumulated depreciation	$ 12,291	$ 11,276
Common stock, no par value (in dollars per share)	$ 0	$ 0
Common stock, shares authorized	120,000,000	120,000,000
Common stock, shares issued	79,653,624	79,653,624
Common stock, shares outstanding	79,653,624	79,653,624

Schedule II - Valuation and 132

Schedule II - Valuation and Qualifying Accounts (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of year	$ 1,397	$ 1,466	$ 1,423
Charged to costs and expenses	2,885	3,358	3,267
Charged to other accounts	0	0	0
Write-offs	3,073	3,427	3,224
Balance at end of year	1,209	1,397	1,466
Public Service Company of New Mexico [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of year	1,397	1,466	1,423
Charged to costs and expenses	2,871	3,344	3,275
Charged to other accounts	0	0	0
Write-offs	3,059	3,413	3,232
Balance at end of year	1,209	1,397	1,466
Texas-New Mexico Power Company [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of year	0	0	0
Charged to costs and expenses	14	14	(8)
Charged to other accounts	0	0	0
Write-offs	14	14	(8)
Balance at end of year	$ 0	$ 0	$ 0