10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended March 31, 2014

Commission File	Name of Registrants, State of Incorporation,	I.R.S. Employer
Number	Address and Telephone Number	Identification No.
001-32462	PNM Resources, Inc.	85-0468296
	(A New Mexico Corporation)
	414 Silver Ave. SW
	Albuquerque, New Mexico 87102-3289
	(505) 241-2700
001-06986	Public Service Company of New Mexico	85-0019030
	(A New Mexico Corporation)
	414 Silver Ave. SW
	Albuquerque, New Mexico 87102-3289
	(505) 241-2700
002-97230	Texas-New Mexico Power Company	75-0204070
	(A Texas Corporation)
	577 N. Garden Ridge Blvd.
	Lewisville, Texas 75067
	(972) 420-4189

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

PNM Resources, Inc. (“PNMR”)	YES	ü	NO
Public Service Company of New Mexico (“PNM”)	YES	ü	NO
Texas-New Mexico Power Company (“TNMP”)	YES		NO	ü

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

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

PNMR	YES	ü	NO
PNM	YES	ü	NO
TNMP	YES	ü	NO

Indicate by check mark whether registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer or a smaller reporting company (as defined in Rule 12b-2 of the Exchange Act).

	Large accelerated filer		Accelerated filer	Non-accelerated filer		Smaller Reporting Company
PNMR		ü
PNM					ü
TNMP					ü

Indicate by check mark whether any of the registrants is a shell company (as defined in Rule 12b-2 of the Exchange Act). YES   NO ü

As of April 25, 2014, 79,653,624 shares of common stock, no par value per share, of PNMR were outstanding.

The total number of shares of common stock of PNM outstanding as of April 25, 2014 was 39,117,799 all held by PNMR (and none held by non-affiliates).

The total number of shares of common stock of TNMP outstanding as of April 25, 2014 was 6,358 all held indirectly by PNMR (and none held by non-affiliates).

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

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

2

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

INDEX

	Page No.
GLOSSARY	4
PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS (UNAUDITED)
PNM RESOURCES, INC. AND SUBSIDIARIES
Condensed Consolidated Statements of Earnings	7
Condensed Consolidated Statements of Comprehensive Income	8
Condensed Consolidated Statements of Cash Flows	9
Condensed Consolidated Balance Sheets	11
Condensed Consolidated Statement of Changes in Equity	13
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
Condensed Consolidated Statements of Earnings	14
Condensed Consolidated Statements of Comprehensive Income	15
Condensed Consolidated Statements of Cash Flows	16
Condensed Consolidated Balance Sheets	18
Condensed Consolidated Statement of Changes in Equity	20
TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES
Condensed Consolidated Statements of Earnings	21
Condensed Consolidated Statements of Comprehensive Income	22
Condensed Consolidated Statements of Cash Flows	23
Condensed Consolidated Balance Sheets	24
Condensed Consolidated Statement of Changes in Common Stockholder's Equity	26
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS	27
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	66
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	89
ITEM 4. CONTROLS AND PROCEDURES	92
PART II. OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS	93
ITEM 1A. RISK FACTORS	93
ITEM 5. OTHER INFORMATION	93
ITEM 6. EXHIBITS	94
SIGNATURE	96

3

GLOSSARY

Definitions:
Afton	Afton Generating Station
AFUDC	Allowance for Funds Used During Construction
ALJ	Administrative Law Judge
AMS	Advanced Meter System
AOCI	Accumulated Other Comprehensive Income
APS	Arizona Public Service Company, which is the operator and a co-owner of PVNGS and Four Corners
BACT	Best Available Control Technology
BART	Best Available Retrofit Technology
BHP	BHP Billiton, Ltd, the parent of SJCC
Board	Board of Directors of PNMR
BTU	British Thermal Unit
CAA	Clean Air Act
CCB	Coal Combustion Byproducts
CCN	Certificate of Convenience and Necessity
CO2	Carbon Dioxide
CTC	Competition Transition Charge
D.C. Circuit	United States Court of Appeals for the District of Columbia Circuit
Delta	Delta-Person Generating Station
DOE	United States Department of Energy
DOI	United States Department of Interior
EGU	Electric Generating Unit
EIB	New Mexico Environmental Improvement Board
EIP	Eastern Interconnection Project
EIS	Environmental Impact Statement
EPA	United States Environmental Protection Agency
ERCOT	Electric Reliability Council of Texas
ESA	Endangered Species Act
Exchange Act	Securities Exchange Act of 1934
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
FIP	Federal Implementation Plan
Four Corners	Four Corners Power Plant
FPPAC	Fuel and Purchased Power Adjustment Clause
GAAP	Generally Accepted Accounting Principles in the United States of America
Gallup	City of Gallup, New Mexico
GHG	Greenhouse Gas Emissions
GWh	Gigawatt hours
IBEW	International Brotherhood of Electrical Workers
IRP	Integrated Resource Plan
KW	Kilowatt
KWh	Kilowatt Hour
Lightning Dock Geothermal	Lightning Dock geothermal power facility, also known as the Dale Burgett Geothermal Plant
Lordsburg	Lordsburg Generating Station
Luna	Luna Energy Facility
MD&A	Management’s Discussion and Analysis of Financial Condition and Results of Operations

4

MMBTU	Million BTUs
Moody’s	Moody’s Investor Services, Inc.
MW	Megawatt
MWh	Megawatt Hour
NAAQS	National Ambient Air Quality Standards
Navajo Acts	Navajo Nation Air Pollution Prevention and Control Act, Navajo Nation Safe Drinking Water Act, and Navajo Nation Pesticide Act
NDT	Nuclear Decommissioning Trusts for PVNGS
NEC	Navopache Electric Cooperative, Inc.
NERC	North American Electric Reliability Council
New Mexico Wind	New Mexico Wind Energy Center
Ninth Circuit	United States Court of Appeals for the Ninth Circuit
NMED	New Mexico Environment Department
NMPRC	New Mexico Public Regulation Commission
NOx	Nitrogen Oxides
NOPR	Notice of Proposed Rulemaking
NRC	United States Nuclear Regulatory Commission
NSPS	New Source Performance Standards
NSR	New Source Review
OCI	Other Comprehensive Income
OPEB	Other Post Employment Benefits
OSM	United States Office of Surface Mining Reclamation and Enforcement
PNM	Public Service Company of New Mexico and Subsidiaries
PNM 2014 Term Loan Agreement	PNM’s $175.0 Million Unsecured Term Loan Facility
PNM New Mexico Credit Facility	PNM’s $50.0 Million Unsecured Revolving Credit Facility
PNM Revolving Credit Facility	PNM’s $400.0 Million Unsecured Revolving Credit Facility
PNM Term Loan Agreement	PNM’s $75.0 Million Unsecured Term Loan Facility
PNMR	PNM Resources, Inc. and Subsidiaries
PNMR Development	PNMR Development and Management Corporation
PNMR Revolving Credit Facility	PNMR’s $300.0 Million Unsecured Revolving Credit Facility
PNMR Term Loan Agreement	PNMR’s $100.0 Million Unsecured Term Loan Facility
PPA	Power Purchase Agreement
PSD	Prevention of Significant Deterioration
PUCT	Public Utility Commission of Texas
PV	Photovoltaic
PVNGS	Palo Verde Nuclear Generating Station
RCRA	Resource Conservation and Recovery Act
RCT	Reasonable Cost Threshold
REA	New Mexico’s Renewable Energy Act of 2004
REC	Renewable Energy Certificates
Red Mesa Wind	Red Mesa Wind Energy Center
REP	Retail Electricity Provider
RMC	Risk Management Committee
RPS	Renewable Energy Portfolio Standard
SCR	Selective Catalytic Reduction
SEC	United States Securities and Exchange Commission

5

SIP	State Implementation Plan
SJCC	San Juan Coal Company
SJGS	San Juan Generating Station
SJPPA	San Juan Project Participation Agreement
SNCR	Selective Non-Catalytic Reduction
SO2	Sulfur Dioxide
SPS	Southwestern Public Service Company
S&P	Standard and Poor’s Ratings Services
TECA	Texas Electric Choice Act
Tenth Circuit	United States Court of Appeals for the Tenth Circuit
TNMP	Texas-New Mexico Power Company and Subsidiaries
TNMP Revolving Credit Facility	TNMP’s $75.0 Million Revolving Credit Facility
Valencia	Valencia Energy Facility
VaR	Value at Risk
WACC	Weighted Average Cost of Capital
WEG	WildEarth Guardians

6

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

PNM RESOURCES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF EARNINGS

(Unaudited)

	Three Months Ended March 31,
	2014			2013
	(In thousands, except per share amounts)
Electric Operating Revenues	$	328,897		$	317,665
Operating Expenses:
Cost of energy	112,614			104,706
Administrative and general	43,859			44,691
Energy production costs	47,288			43,573
Depreciation and amortization	41,965			40,807
Transmission and distribution costs	16,906			16,295
Taxes other than income taxes	17,512			16,889
Total operating expenses	280,144			266,961
Operating income	48,753			50,704
Other Income and Deductions:
Interest income	2,117			2,634
Gains on available-for-sale securities	2,573			1,530
Other income	1,574			1,710
Other (deductions)	(2,931		)	(3,350		)
Net other income and deductions	3,333			2,524
Interest Charges	29,535			31,297
Earnings before Income Taxes	22,551			21,931
Income Taxes	6,420			7,969
Net Earnings	16,131			13,962
(Earnings) Attributable to Valencia Non-controlling Interest	(3,531		)	(3,204		)
Preferred Stock Dividend Requirements of Subsidiary	(132		)	(132		)
Net Earnings Attributable to PNMR	$	12,468		$	10,626
Net Earnings Attributable to PNMR per Common Share:
Basic	$	0.16		$	0.13
Diluted	$	0.16		$	0.13
Dividends Declared per Common Share	$	0.185		$	0.165

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

7

PNM RESOURCES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended March 31,
	2014			2013
	(In thousands)
Net Earnings	$	16,131		$	13,962
Other Comprehensive Income:
Unrealized Gain on Available-for-Sale Securities:
Unrealized holding gains arising during the period, net of income tax (expense) of $(1,332) and $(3,111)	2,047			4,747
Reclassification adjustment for (gains) included in net earnings, net of income tax expense of $1,283 and $529	(1,972		)	(807		)
Pension Liability Adjustment:
Reclassification adjustment for amortization of experience (gain) loss recognized as net periodic benefit cost, net of income tax expense (benefit) of $(508) and $(631)	780			960
Fair Value Adjustment for Cash Flow Hedges:
Change in fair market value, net of income tax (expense) benefit of $53 and $(4)	(100		)	8
Reclassification adjustment for (gains) losses included in net earnings, net of income tax expense (benefit) of $(19) and $(17)	36			31
Total Other Comprehensive Income	791			4,939
Comprehensive Income	16,922			18,901
Comprehensive (Income) Attributable to Valencia Non-controlling Interest	(3,531		)	(3,204		)
Preferred Stock Dividend Requirements of Subsidiary	(132		)	(132		)
Comprehensive Income Attributable to PNMR	$	13,259		$	15,565

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

8

PNM RESOURCES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Three Months Ended March 31,
	2014			2013
	(In thousands)
Cash Flows From Operating Activities:
Net earnings	$	16,131		$	13,962
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	51,949			51,818
Deferred income tax expense	6,276			7,795
Net unrealized (gains) losses on commodity derivatives	2,761			4,902
Realized (gains) on available-for-sale securities	(2,573		)	(1,530		)
Stock based compensation expense	2,131			1,903
Other, net	1,005			(351		)
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	17,207			4,062
Materials, supplies, and fuel stock	5,894			944
Other current assets	8,344			2,335
Other assets	6,386			8,774
Accounts payable	(34,373		)	(17,895		)
Accrued interest and taxes	25,813			25,430
Other current liabilities	(30,359		)	(38,761		)
Other liabilities	(199		)	(64,763		)
Net cash flows from operating activities	76,393			(1,375		)
Cash Flows From Investing Activities:
Additions to utility and non-utility plant	(83,838		)	(73,584		)
Proceeds from sales of available-for-sale securities	22,804			14,284
Purchases of available-for-sale securities	(23,612		)	(15,128		)
Return of principal on PVNGS lessor notes	10,231			10,965
Other, net	13			1,247
Net cash flows from investing activities	(74,402		)	(62,216		)

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

9

PNM RESOURCES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Three Months Ended March 31,
	2014			2013
	(In thousands)
Cash Flows From Financing Activities:
Short-term borrowings (repayments), net	(49,200		)	84,600
Long-term borrowings	175,000			—
Repayment of long-term debt	(75,000		)	—
Proceeds from stock option exercise	3,258			2,293
Awards of common stock	(11,639		)	(9,651		)
Dividends paid	(14,868		)	(11,683		)
Valencia’s transactions with its owner	(4,369		)	(5,260		)
Other, net	(539		)	(584		)
Net cash flows from financing activities	22,643			59,715
Change in Cash and Cash Equivalents	24,634			(3,876		)
Cash and Cash Equivalents at Beginning of Period	2,533			8,985
Cash and Cash Equivalents at End of Period	$	27,167		$	5,109
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	$	4,718		$	4,817
Income taxes paid (refunded), net	$	(1,419	)	$	(603	)
Supplemental schedule of noncash investing activities:
Changes in accrued plant additions	$	(13,095	)	$	(3,847	)

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

10

PNM RESOURCES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

	March 31, 2014		December 31, 2013
	(In thousands)
ASSETS
Current Assets:
Cash and cash equivalents	$	27,167	$	2,533
Accounts receivable, net of allowance for uncollectible accounts of $1,423 and $1,423	81,611		90,251
Unbilled revenues	49,408		58,806
Other receivables	41,476		53,909
Materials, supplies, and fuel stock	61,329		67,223
Regulatory assets	27,163		24,416
Commodity derivative instruments	4,003		4,064
Income taxes receivable	5,503		7,066
Current portion of accumulated deferred income taxes	58,681		58,681
Other current assets	44,689		34,590
Total current assets	401,030		401,539
Other Property and Investments:
Investment in PVNGS lessor notes	17,757		32,200
Available-for-sale securities	230,250		226,855
Other investments	1,813		1,835
Non-utility property, net of accumulated depreciation of $62 and $61	4,352		4,353
Total other property and investments	254,172		265,243
Utility Plant:
Plant in service and plant held for future use	5,602,590		5,563,061
Less accumulated depreciation and amortization	1,866,635		1,838,832
	3,735,955		3,724,229
Construction work in progress	147,870		132,080
Nuclear fuel, net of accumulated amortization of $54,338 and $47,347	78,778		77,602
Net utility plant	3,962,603		3,933,911
Deferred Charges and Other Assets:
Regulatory assets	513,727		523,955
Goodwill	278,297		278,297
Commodity derivative instruments	2,474		3,002
Other deferred charges	94,723		94,263
Total deferred charges and other assets	889,221		899,517
	$	5,507,026	$	5,500,210

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

11

PNM RESOURCES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

	March 31, 2014			December 31, 2013
	(In thousands, except share information)
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current Liabilities:
Short-term debt	$	100,000		$	149,200
Current installments of long-term debt	—			75,000
Accounts payable	62,198			109,666
Customer deposits	13,065			13,456
Accrued interest and taxes	73,978			49,600
Regulatory liabilities	353			1,081
Commodity derivative instruments	5,446			2,699
Dividends declared	14,864			14,864
Other current liabilities	42,184			77,105
Total current liabilities	312,088			492,671
Long-term Debt	1,845,338			1,670,420
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	833,240			801,408
Accumulated deferred investment tax credits	25,314			25,855
Regulatory liabilities	463,106			460,649
Asset retirement obligations	98,076			96,135
Accrued pension liability and postretirement benefit cost	75,745			80,046
Commodity derivative instruments	907			1,094
Other deferred credits	99,671			109,805
Total deferred credits and other liabilities	1,596,059			1,574,992
Total liabilities	3,753,485			3,738,083
Commitments and Contingencies (See Note 11)
Cumulative Preferred Stock of Subsidiary
without mandatory redemption requirements ($100 stated value; 10,000,000 shares authorized; issued and outstanding 115,293 shares)	11,529			11,529
Equity:
PNMR common stockholders’ equity:
Common stock outstanding (no par value; 120,000,000 shares authorized; issued and outstanding 79,653,624 shares)	1,172,098			1,178,369
Accumulated other comprehensive income (loss), net of income taxes	(57,349		)	(58,140		)
Retained earnings	551,072			553,340
Total PNMR common stockholders’ equity	1,665,821			1,673,569
Non-controlling interest in Valencia	76,191			77,029
Total equity	1,742,012			1,750,598
	$	5,507,026		$	5,500,210

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

12

PNM RESOURCES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN EQUITY

(Unaudited)

	Attributable to PNMR												Non- controlling Interest in Valencia
	Common Stock			AOCI			Retained Earnings			Total PNMR Common Stockholder’s Equity						Total Equity
	(In thousands)
Balance at December 31, 2013	$	1,178,369		$	(58,140	)	$	553,340		$	1,673,569		$	77,029		$	1,750,598
Proceeds from stock option exercise	3,258			—			—			3,258			—			3,258
Awards of common stock	(11,639		)	—			—			(11,639		)	—			(11,639		)
Excess tax (shortfall) from stock-based payment arrangements	(21		)	—			—			(21		)	—			(21		)
Stock based compensation expense	2,131			—			—			2,131			—			2,131
Valencia’s transactions with its owner	—			—			—			—			(4,369		)	(4,369		)
Net earnings before subsidiary preferred stock dividends	—			—			12,600			12,600			3,531			16,131
Subsidiary preferred stock dividends	—			—			(132		)	(132		)	—			(132		)
Total other comprehensive income	—			791			—			791			—			791
Dividends declared on common stock	—			—			(14,736		)	(14,736		)	—			(14,736		)
Balance at March 31, 2014	$	1,172,098		$	(57,349	)	$	551,072		$	1,665,821		$	76,191		$	1,742,012

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

13

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF EARNINGS

(Unaudited)

	Three Months Ended March 31,
	2014			2013
	(In thousands)
Electric Operating Revenues	$	262,736		$	257,894
Operating Expenses:
Cost of energy	96,626			91,660
Administrative and general	38,609			38,758
Energy production costs	47,288			43,566
Depreciation and amortization	27,082			25,834
Transmission and distribution costs	11,327			10,603
Taxes other than income taxes	10,500			10,234
Total operating expenses	231,432			220,655
Operating income	31,304			37,239
Other Income and Deductions:
Interest income	2,128			2,673
Gains on available-for-sale securities	2,573			1,530
Other income	1,113			1,314
Other (deductions)	(2,018		)	(1,437		)
Net other income and deductions	3,796			4,080
Interest Charges	19,812			19,957
Earnings before Income Taxes	15,288			21,362
Income Taxes	4,083			6,589
Net Earnings	11,205			14,773
(Earnings) Attributable to Valencia Non-controlling Interest	(3,531		)	(3,204		)
Net Earnings Attributable to PNM	7,674			11,569
Preferred Stock Dividends Requirements	(132		)	(132		)
Net Earnings Available for PNM Common Stock	$	7,542		$	11,437

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

14

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended March 31,
	2014			2013
	(In thousands)
Net Earnings	$	11,205		$	14,773
Other Comprehensive Income:
Unrealized Gain on Available-for-Sale Securities:
Unrealized holding gains arising during the period, net of income tax (expense) of $(1,332) and $(3,111)	2,047			4,747
Reclassification adjustment for (gains) included in net earnings, net of income tax expense of $1,283 and $529	(1,972		)	(807		)
Pension Liability Adjustment:
Reclassification adjustment for amortization of experience (gain) loss recognized as net periodic benefit cost, net of income tax expense (benefit) of $(508) and $(631)	780			960
Total Other Comprehensive Income	855			4,900
Comprehensive Income	12,060			19,673
Comprehensive (Income) Attributable to Valencia Non-controlling Interest	(3,531		)	(3,204		)
Comprehensive Income Attributable to PNM	$	8,529		$	16,469

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

15

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Three Months Ended March 31,
	2014			2013
	(In thousands)
Cash Flows From Operating Activities:
Net earnings	$	11,205		$	14,773
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	35,950			34,655
Deferred income tax expense	4,185			6,685
Net unrealized (gains) losses on commodity derivatives	2,761			4,902
Realized (gains) on available-for-sale securities	(2,573		)	(1,530		)
Other, net	1,042			(346		)
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	15,018			5,467
Materials, supplies, and fuel stock	5,974			879
Other current assets	6,809			(84		)
Other assets	6,042			8,772
Accounts payable	(31,847		)	(18,857		)
Accrued interest and taxes	22,362			20,932
Other current liabilities	(29,609		)	(44,068		)
Other liabilities	(806		)	(64,893		)
Net cash flows from operating activities	46,513			(32,713		)
Cash Flows From Investing Activities:
Utility plant additions	(51,594		)	(44,389		)
Proceeds from sales of available-for-sale securities	22,804			14,284
Purchases of available-for-sale securities	(23,612		)	(15,128		)
Return of principal on PVNGS lessor notes	10,231			10,965
Other, net	(1		)	1,220
Net cash flows from investing activities	(42,172		)	(33,048		)

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

16

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Three Months Ended March 31,
	2014			2013
	(In thousands)
Cash Flows From Financing Activities:
Short-term borrowings (repayments), net	(49,200		)	67,800
Short-term borrowings (repayments), affiliate, net	(32,500		)	—
Long-term borrowings	175,000			—
Repayment of long-term debt	(75,000		)	—
Valencia’s transactions with its owner	(4,369		)	(5,260		)
Dividends paid	(132		)	(132		)
Other, net	(409		)	(584		)
Net cash flows from financing activities	13,390			61,824
Change in Cash and Cash Equivalents	17,731			(3,937		)
Cash and Cash Equivalents at Beginning of Period	21			3,958
Cash and Cash Equivalents at End of Period	$	17,752		$	21
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	$	4,222		$	4,304
Income taxes paid (refunded), net	$	(215	)	$	—
Supplemental schedule of noncash investing activities:
Changes in accrued plant additions	$	(8,133	)	$	1,128

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

17

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

	March 31, 2014		December 31, 2013
	(In thousands)
ASSETS
Current Assets:
Cash and cash equivalents	$	17,752	$	21
Accounts receivable, net of allowance for uncollectible accounts of $1,423 and $1,423	61,394		70,126
Unbilled revenues	41,874		48,992
Other receivables	40,788		52,964
Affiliate receivables	9,646		10,054
Materials, supplies, and fuel stock	58,546		64,520
Regulatory assets	23,016		19,394
Commodity derivative instruments	4,003		4,064
Income taxes receivable	3,917		4,030
Current portion of accumulated deferred income taxes	43,827		43,827
Other current assets	40,498		30,510
Total current assets	345,261		348,502
Other Property and Investments:
Investment in PVNGS lessor notes	17,757		32,200
Available-for-sale securities	230,250		226,855
Other investments	436		445
Non-utility property	976		976
Total other property and investments	249,419		260,476
Utility Plant:
Plant in service and plant held for future use	4,339,081		4,314,016
Less accumulated depreciation and amortization	1,420,194		1,402,531
	2,918,887		2,911,485
Construction work in progress	112,093		107,344
Nuclear fuel, net of accumulated amortization of $54,338 and $47,347	78,778		77,602
Net utility plant	3,109,758		3,096,431
Deferred Charges and Other Assets:
Regulatory assets	377,334		384,217
Goodwill	51,632		51,632
Commodity derivative instruments	2,474		3,002
Other deferred charges	83,757		83,356
Total deferred charges and other assets	515,197		522,207
	$	4,219,635	$	4,227,616

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

18

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

	March 31, 2014			December 31, 2013
	(In thousands, except share information)
LIABILITIES AND STOCKHOLDER’S EQUITY
Current Liabilities:
Short-term debt	$	—		$	49,200
Short-term debt - affiliate	—			32,500
Current installments of long-term debt	—			75,000
Accounts payable	44,663			84,643
Affiliate payables	12,315			20,498
Customer deposits	13,065			13,456
Accrued interest and taxes	50,096			27,665
Regulatory liabilities	353			1,081
Commodity derivative instruments	5,446			2,699
Dividends declared	132			132
Other current liabilities	30,070			50,392
Total current liabilities	156,140			357,266
Long-term Debt	1,390,627			1,215,618
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	672,136			651,239
Accumulated deferred investment tax credits	25,314			25,855
Regulatory liabilities	415,537			414,611
Asset retirement obligations	97,147			95,225
Accrued pension liability and postretirement benefit cost	72,654			76,611
Commodity derivative instruments	907			1,094
Other deferred credits	82,857			91,340
Total deferred credits and liabilities	1,366,552			1,355,975
Total liabilities	2,913,319			2,928,859
Commitments and Contingencies (See Note 11)
Cumulative Preferred Stock
without mandatory redemption requirements ($100 stated value; 10,000,000 authorized; issued and outstanding 115,293 shares)	11,529			11,529
Equity:
PNM common stockholder’s equity:
Common stock outstanding (no par value; 40,000,000 shares authorized; issued and outstanding 39,117,799 shares)	1,061,776			1,061,776
Accumulated other comprehensive income (loss), net of income taxes	(57,022		)	(57,877		)
Retained earnings	213,842			206,300
Total PNM common stockholder’s equity	1,218,596			1,210,199
Non-controlling interest in Valencia	76,191			77,029
Total equity	1,294,787			1,287,228
	$	4,219,635		$	4,227,616

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

19

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN EQUITY

(Unaudited)

	Attributable to PNM
									Total PNM Common Stockholder’s Equity			Non- controlling  Interest in Valencia
	Common Stock		AOCI			Retained Earnings									Total Equity
	(In thousands)
Balance at December 31, 2013	$	1,061,776	$	(57,877	)	$	206,300		$	1,210,199		$	77,029		$	1,287,228
Valencia’s transactions with its owner	—		—			—			—			(4,369		)	(4,369		)
Net earnings	—		—			7,674			7,674			3,531			11,205
Total other comprehensive income	—		855			—			855			—			855
Dividends declared on preferred stock	—		—			(132		)	(132		)	—			(132		)
Balance at March 31, 2014	$	1,061,776	$	(57,022	)	$	213,842		$	1,218,596		$	76,191		$	1,294,787

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

20

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF EARNINGS

(Unaudited)

	Three Months Ended March 31,
	2014			2013
	(In thousands)
Electric Operating Revenues	$	66,161		$	59,771
Operating Expenses:
Cost of energy	15,988			13,046
Administrative and general	9,840			11,119
Depreciation and amortization	11,842			11,681
Transmission and distribution costs	5,579			5,692
Taxes other than income taxes	5,650			5,179
Total operating expenses	48,899			46,717
Operating income	17,262			13,054
Other Income and Deductions:
Other income	420			337
Other (deductions)	(231		)	(129		)
Net other income and deductions	189			208
Interest Charges	6,598			7,246
Earnings before Income Taxes	10,853			6,016
Income Taxes	4,050			2,290
Net Earnings	$	6,803		$	3,726

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

21

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended March 31,
	2014			2013
	(In thousands)
Net Earnings	$	6,803		$	3,726
Other Comprehensive Income (Loss):
Fair Value Adjustment for Cash Flow Hedges:
Change in fair market value, net of income tax (expense) benefit of $53 and $(4)	(100		)	8
Reclassification adjustment for (gains) losses included in net earnings, net of income tax expense (benefit) of $(19) and $(17)	36			31
Total Other Comprehensive Income (Loss)	(64		)	39
Comprehensive Income	$	6,739		$	3,765

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

22

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Three Months Ended March 31,
	2014			2013
	(In thousands)
Cash Flows From Operating Activities:
Net earnings	$	6,803		$	3,726
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	12,851			12,686
Deferred income tax expense	3,665			2,448
Other, net	(36		)	—
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	2,189			(1,405		)
Materials and supplies	(81		)	65
Other current assets	2,446			218
Other assets	302			(58		)
Accounts payable	(2,551		)	4,130
Accrued interest and taxes	335			686
Other current liabilities	(1,768		)	(1,278		)
Other liabilities	1,465			1,076
Net cash flows from operating activities	25,620			22,294
Cash Flows From Investing Activities:
Utility plant additions	(27,420		)	(24,594		)
Net cash flows from investing activities	(27,420		)	(24,594		)
Cash Flow From Financing Activities:
Short-term borrowings (repayments), net	—			25,000
Short-term borrowings (repayments) – affiliate, net	1,800			(22,700		)
Net cash flows from financing activities	1,800			2,300
Change in Cash and Cash Equivalents	—			—
Cash and Cash Equivalents at Beginning of Period	1			1
Cash and Cash Equivalents at End of Period	$	1		$	1
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	$	73		$	171
Income taxes paid, net	$	(1,204	)	$	(604	)
Supplemental schedule of noncash investing activities:
Changes in accrued plant additions	$	(1,109	)	$	(932	)

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

23

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

	March 31, 2014		December 31, 2013
	(In thousands)
ASSETS
Current Assets:
Cash and cash equivalents	$	1	$	1
Accounts receivable	20,217		20,125
Unbilled revenues	7,534		9,814
Other receivables	1,057		1,246
Materials and supplies	2,783		2,703
Regulatory assets	4,147		5,022
Current portion of accumulated deferred income taxes	6,501		6,501
Other current assets	752		980
Total current assets	42,992		46,392
Other Property and Investments:
Other investments	245		245
Non-utility property	2,240		2,240
Total other property and investments	2,485		2,485
Utility Plant:
Plant in service and plant held for future use	1,081,881		1,074,193
Less accumulated depreciation and amortization	359,205		352,105
	722,676		722,088
Construction work in progress	33,377		16,790
Net utility plant	756,053		738,878
Deferred Charges and Other Assets:
Regulatory assets	136,393		139,738
Goodwill	226,665		226,665
Other deferred charges	8,440		8,273
Total deferred charges and other assets	371,498		374,676
	$	1,173,028	$	1,162,431

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

24

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

	March 31, 2014			December 31, 2013
	(In thousands, except share information)
LIABILITIES AND STOCKHOLDER’S EQUITY
Current Liabilities:
Short-term debt – affiliate	$	31,200		$	29,400
Accounts payable	8,878			12,543
Affiliate payables	2,209			3,181
Accrued interest and taxes	24,113			23,778
Other current liabilities	9,380			8,999
Total current liabilities	75,780			77,901
Long-term Debt	335,944			336,036
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	193,887			190,197
Regulatory liabilities	47,569			46,038
Asset retirement obligations	798			782
Accrued pension liability and postretirement benefit cost	3,091			3,435
Other deferred credits	6,289			5,111
Total deferred credits and other liabilities	251,634			245,563
Total liabilities	663,358			659,500
Commitments and Contingencies (See Note 11)
Common Stockholder’s Equity:
Common stock outstanding ($10 par value; 12,000,000 shares authorized;
issued and outstanding 6,358 shares)	64			64
Paid-in-capital	404,166			404,166
Accumulated other comprehensive income (loss), net of income taxes	(327		)	(263		)
Retained earnings	105,767			98,964
Total common stockholder’s equity	509,670			502,931
	$	1,173,028		$	1,162,431

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

25

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN COMMON STOCKHOLDER’S EQUITY

(Unaudited)

	Common Stock		Paid-in Capital		AOCI			Retained Earnings		Total Common Stockholder’s Equity
	(In thousands)
Balance at December 31, 2013	$	64	$	404,166	$	(263	)	$	98,964	$	502,931
Net earnings	—		—		—			6,803		6,803
Total other comprehensive income (loss)	—		—		(64		)	—		(64		)
Balance at March 31, 2014	$	64	$	404,166	$	(327	)	$	105,767	$	509,670

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

26

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

(1) Significant Accounting Policies and Responsibility for Financial Statements

Financial Statement Preparation

In the opinion of management, the accompanying unaudited interim Condensed Consolidated Financial Statements reflect all normal and recurring accruals and adjustments that are necessary to present fairly the consolidated financial position at March 31, 2014 and December 31, 2013, and the consolidated results of operations, comprehensive income, and cash flows for the three months ended March 31, 2014 and 2013. The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could ultimately differ from those estimated. Weather causes the Company’s results of operations to be seasonal in nature and the results of operations presented in the accompanying Condensed Consolidated Financial Statements are not necessarily representative of operations for an entire year.

The Notes to Condensed Consolidated Financial Statements include disclosures for PNMR, PNM, and TNMP. This report uses the term “Company” when discussing matters of common applicability to PNMR, PNM, and TNMP. Discussions regarding only PNMR, PNM, or TNMP are so indicated. Certain amounts in the 2013 Condensed Consolidated Financial Statements and Notes thereto have been reclassified to conform to the 2014 financial statement presentation.

These Condensed Consolidated Financial Statements are unaudited. Certain information and note disclosures normally included in the annual Consolidated Financial Statements have been condensed or omitted, as permitted under the applicable rules and regulations. Readers of these financial statements should refer to PNMR’s, PNM’s, and TNMP’s audited Consolidated Financial Statements and Notes thereto that are included in their respective 2013 Annual Reports on Form 10-K.

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

Principles of Consolidation

The Condensed Consolidated Financial Statements of each of PNMR, PNM, and TNMP include their accounts and those of subsidiaries in which that entity owns a majority voting interest. PNM also consolidates the PVNGS Capital Trust and Valencia. 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 at cost. Other significant intercompany transactions between PNMR, PNM, and TNMP include interest and income tax sharing payments, as well as dividends paid on common stock. All intercompany transactions and balances have been eliminated. See Note 14.

27

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

(2) Earnings Per Share

In accordance with GAAP, dual presentation of basic and diluted earnings per share is presented in the Condensed Consolidated Statements of Earnings of PNMR. Information regarding the computation of earnings per share is as follows:

	Three Months Ended
	March 31,
	2014		2013
	(In thousands, except per share amounts)
Net Earnings Attributable to PNMR	$	12,468	$	10,626
Average Number of Common Shares:
Outstanding during period	79,654		79,654
Vested awards of restricted stock	182		211
Average Shares - Basic	79,836		79,865
Dilutive Effect of Common Stock Equivalents (1):
Stock options and restricted stock	551		715
Average Shares - Diluted	80,387		80,580
Net Earnings Per Share of Common Stock:
Basic	$	0.16	$	0.13
Diluted	$	0.16	$	0.13

⁽¹⁾  Excludes the effect of out-of-the-money options for 486,016 shares of common stock at March 31, 2014.

(3) 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 provides generation service to firm-requirements wholesale customers and sells electricity into the wholesale market, as well as providing transmission services to third parties. The sale of electricity into the wholesale market includes the optimization of PNM’s jurisdictional capacity, as well as the capacity from PVNGS Unit 3, which is not included in retail rates. FERC has jurisdiction over wholesale and transmission rates.

TNMP

TNMP is an electric utility providing regulated transmission and distribution services in Texas under the TECA. TNMP’s operations are subject to traditional rate regulation by the PUCT.

Corporate and Other

The Corporate and Other segment includes PNMR holding company activities, primarily related to corporate level debt and PNMR Services Company.

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

28

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

PNMR SEGMENT INFORMATION

	PNM			TNMP			Corporate and Other			Consolidated
Three Months Ended March 31, 2014	(In thousands)
Electric operating revenues	$	262,736		$	66,161		$	—		$	328,897
Cost of energy	96,626			15,988			—			112,614
Margin	166,110			50,173			—			216,283
Other operating expenses	107,724			21,069			(3,228		)	125,565
Depreciation and amortization	27,082			11,842			3,041			41,965
Operating income	31,304			17,262			187			48,753
Interest income	2,128			—			(11		)	2,117
Other income (deductions)	1,668			189			(641		)	1,216
Net interest charges	(19,812		)	(6,598		)	(3,125		)	(29,535		)
Segment earnings (loss) before income taxes	15,288			10,853			(3,590		)	22,551
Income taxes (benefit)	4,083			4,050			(1,713		)	6,420
Segment earnings (loss)	11,205			6,803			(1,877		)	16,131
Valencia non-controlling interest	(3,531		)	—			—			(3,531		)
Subsidiary preferred stock dividends	(132		)	—			—			(132		)
Segment earnings (loss) attributable to PNMR	$	7,542		$	6,803		$	(1,877	)	$	12,468
At March 31, 2014:
Total Assets	$	4,219,635		$	1,173,028		$	114,363		$	5,507,026
Goodwill	$	51,632		$	226,665		$	—		$	278,297

	PNM			TNMP			Corporate and Other			Consolidated
Three Months Ended March 31, 2013	(In thousands)
Electric operating revenues	$	257,894		$	59,771		$	—		$	317,665
Cost of energy	91,660			13,046			—			104,706
Margin	166,234			46,725			—			212,959
Other operating expenses	103,161			21,990			(3,703		)	121,448
Depreciation and amortization	25,834			11,681			3,292			40,807
Operating income	37,239			13,054			411			50,704
Interest income	2,673			—			(39		)	2,634
Other income (deductions)	1,407			208			(1,725		)	(110		)
Net interest charges	(19,957		)	(7,246		)	(4,094		)	(31,297		)
Segment earnings (loss) before income taxes	21,362			6,016			(5,447		)	21,931
Income taxes (benefit)	6,589			2,290			(910		)	7,969
Segment earnings (loss)	14,773			3,726			(4,537		)	13,962
Valencia non-controlling interest	(3,204		)	—			—			(3,204		)
Subsidiary preferred stock dividends	(132		)	—			—			(132		)
Segment earnings (loss) attributable to PNMR	$	11,437		$	3,726		$	(4,537	)	$	10,626
At March 31, 2013:
Total Assets	$	4,155,257		$	1,098,942		$	116,561		$	5,370,760
Goodwill	$	51,632		$	226,665		$	—		$	278,297

29

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

(4) Accumulated Other Comprehensive Income (Loss)

Information regarding accumulated other comprehensive income (loss) for the three months ended March 31, 2014 and 2013 is as follows:

	Accumulated Other Comprehensive Income (Loss)
	Unrealized						Fair Value
	Gain on			Pension			Adjustment
	Available-for-			Liability			for Cash Flow
	Sale Securities			Adjustment			Hedges			Total
	(In thousands)
PNMR
Balance at December 31, 2013	$	25,748		$	(83,625	)	$	(263	)	$	(58,140	)
Amounts reclassified from AOCI (pre-tax)	(3,255		)	1,288			55			(1,912		)
Income tax impact of amounts reclassified	1,283			(508		)	(19		)	756
Other OCI changes (pre-tax)	3,379			—			(153		)	3,226
Income tax impact of other OCI changes	(1,332		)	—			53			(1,279		)
Net change after income taxes	75			780			(64		)	791
Balance at March 31, 2014	$	25,823		$	(82,845	)	$	(327	)	$	(57,349	)

PNM
Balance at December 31, 2013	$	25,748		$	(83,625	)	$	—	$	(57,877	)
Amounts reclassified from AOCI (pre-tax)	(3,255		)	1,288			—		(1,967		)
Income tax impact of amounts reclassified	1,283			(508		)	—		775
Other OCI changes (pre-tax)	3,379			—			—		3,379
Income tax impact of other OCI changes	(1,332		)	—			—		(1,332		)
Net change after income taxes	75			780			—		855
Balance at March 31, 2014	$	25,823		$	(82,845	)	$	—	$	(57,022	)

TNMP
Balance at December 31, 2013	$	—	$	—	$	(263	)	$	(263	)
Amounts reclassified from AOCI (pre-tax)	—		—		55			55
Income tax impact of amounts reclassified	—		—		(19		)	(19		)
Other OCI changes (pre-tax)	—		—		(153		)	(153		)
Income tax impact of other OCI changes	—		—		53			53
Net change after income taxes	—		—		(64		)	(64		)
Balance at March 31, 2014	$	—	$	—	$	(327	)	$	(327	)

30

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

	Accumulated Other Comprehensive Income (Loss)
	Unrealized						Fair Value
	Gain on			Pension			Adjustment
	Available-for-			Liability			for Cash Flow
	Sale Securities			Adjustment			Hedges			Total
	(In thousands)
PNMR
Balance at December 31, 2012	$	16,406		$	(97,820	)	$	(216	)	$	(81,630	)
Amounts reclassified from AOCI (pre-tax)	(1,336		)	1,591			48			303
Income tax impact of amounts reclassified	529			(631		)	(17		)	(119		)
Other OCI changes (pre-tax)	7,858			—			12			7,870
Income tax impact of other OCI changes	(3,111		)	—			(4		)	(3,115		)
Net change after income taxes	3,940			960			39			4,939
Balance at March 31, 2013	$	20,346		$	(96,860	)	$	(177	)	$	(76,691	)

PNM
Balance at December 31, 2012	$	16,406		$	(97,820	)	$	—	$	(81,414	)
Amounts reclassified from AOCI (pre-tax)	(1,336		)	1,591			—		255
Income tax impact of amounts reclassified	529			(631		)	—		(102		)
Other OCI changes (pre-tax)	7,858			—			—		7,858
Income tax impact of other OCI changes	(3,111		)	—			—		(3,111		)
Net change after income taxes	3,940			960			—		4,900
Balance at March 31, 2013	$	20,346		$	(96,860	)	$	—	$	(76,514	)

TNMP
Balance at December 31, 2012	$	—	$	—	$	(216	)	$	(216	)
Amounts reclassified from AOCI (pre-tax)	—		—		48			48
Income tax impact of amounts reclassified	—		—		(17		)	(17		)
Other OCI changes (pre-tax)	—		—		12			12
Income tax impact of other OCI changes	—		—		(4		)	(4		)
Net change after income taxes	—		—		39			39
Balance at March 31, 2013	$	—	$	—	$	(177	)	$	(177	)

Pre-tax amounts reclassified from AOCI related to “Unrealized Gain on Available-for-Sale Securities” are included in “Gains on available-for-sale securities” in the Condensed 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 Condensed Consolidated Statements of Earnings. For the three months ended March 31, 2014 and 2013, approximately 23.2% and 15.0% of the amount reclassified was capitalized into construction work in process and approximately 2.7% and 2.5% was 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 Condensed Consolidated Statements of Earnings. An insignificant amount was capitalized as AFUDC. The income tax impacts of all amounts reclassified from AOCI are included in “Income Taxes” in the Condensed Consolidated Statements of Earnings.

31

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

(5) 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. GAAP also requires continual reassessment of the primary beneficiary of a variable interest entity. Additional information concerning PNM’s variable interest entities is contained in Note 9 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K.

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. 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 three months ended March 31, 2014 and 2013, PNM paid $4.8 million and $4.7 million for fixed charges and $0.2 million and $0.1 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 has concluded that the third party entity that owns Valencia is a variable interest entity 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. The assets and liabilities of Valencia set forth below are immaterial to PNM and, therefore, not shown separately on the Condensed Consolidated Balance Sheets. The owner’s equity and net income of Valencia are considered attributable to non-controlling interest.

Summarized financial information for Valencia is as follows:

Results of Operations

	Three Months Ended March 31,
	2014			2013
	(In thousands)
Operating revenues	$	4,931		$	4,775
Operating expenses	(1,400		)	(1,571		)
Earnings attributable to non-controlling interest	$	3,531		$	3,204

Financial Position

	March 31,		December 31,
	2014		2013
	(In thousands)
Current assets	$	2,780	$	2,658
Net property, plant, and equipment	74,433		75,137
Total assets	77,213		77,795
Current liabilities	1,022		766
Owners’ equity – non-controlling interest	$	76,191	$	77,029

During the term of the PPA, PNM has the option to purchase and own up to 50% of the plant or the variable interest entity.

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 has been initiated since the parties failed to reach agreement on

32

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

fair market value within 60 days. After the purchase price has been determined through the appraisal process, PNM may in its sole discretion determine whether or not it desires to exercise its option to purchase the 50% interest. In that regard, PNM will evaluate all its alternatives with respect to Valencia with the goal of achieving a fair and economical benefit for its customers. Also, PNM is in the process of developing its 2014 IRP (Note 12). Through this process, PNM will evaluate all of its resource options, including Valencia, to determine the optimal way to serve its customers. If PNM decides to exercise its option, the approval of the NMPRC and FERC would be required, which process could take up to 15 months. Since the purchase price is yet to be established, PNM cannot determine whether or not it will exercise its option or if required regulatory approvals would be received.

PVNGS Leases

PNM leases interests in Units 1 and 2 of PVNGS under arrangements, which were entered into in 1985 and 1986, that are accounted for as operating leases. PNM is not the legal or tax owner of the leased assets. The leases provide PNM with an option to purchase the leased assets at appraised value at the end of the leases. PNM does not have a fixed price purchase option and does not provide residual value guarantees. The leases also provide PNM with options to renew the leases at fixed rates set forth in the leases for two years beyond the termination of the original lease terms. The option periods on certain leases may be further extended for up to an additional six years if the appraised remaining useful lives and fair value of the leased assets are greater than parameters set forth in the leases. See Note 7 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K and Note 6, for additional information regarding the leases and actions PNM has taken with respect to its renewal and purchase options. Under GAAP, these renewal options are considered to be variable interests in the trusts and result in the trusts being considered variable interest entities.

PNM is only obligated to make payments to the trusts for the scheduled semi-annual lease payments, which, net of amounts that will be returned to PNM through its ownership in related lessor notes and the Unit 2 beneficial trust, aggregate $36.5 million as of March 31, 2014 over the remaining original terms of the leases and $145.2 million during the renewal terms of the leases that PNM elected to renew. Under certain circumstances (for example, final shutdown of the plant, 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 beneficial owners and take title to the leased interests. If such an event had occurred as of March 31, 2014, PNM could have been required to pay the beneficial owners up to $144.7 million, which would result in PNM taking ownership of the leased assets and termination of the leases. Other than as discussed in Note 6, PNM has no other financial obligations or commitments to the trusts or the beneficial owners. 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 evaluated the PVNGS lease arrangements, including the notices, amendments, and agreements referred to above, and concluded that it does not have the power to direct the activities that most significantly impact the economic performance of the trusts and, therefore, is not the primary beneficiary of the trusts under GAAP. PNM has recorded no assets or liabilities related to the trusts other than the accrual of lease payments between the scheduled payment dates, which were $11.8 million at March 31, 2014 and $26.0 million at December 31, 2013, that are included in other current liabilities on the Condensed Consolidated Balance Sheets.

Delta

PNM has a 20-year PPA expiring in 2020 covering the entire output of Delta, which is a variable interest under GAAP. PNM also controls the dispatch of the generating plant, which impacts the variable payments made under the PPA and impacts the economic performance of the entity that owns Delta. PNM makes fixed and variable payments to Delta under the PPA. For the three months ended March 31, 2014 and 2013, PNM incurred fixed capacity charges of $1.6 million and $1.6 million and variable energy charges of $0.2 million and $0.2 million under the PPA. PNM’s only quantifiable obligation under the PPA is to make the fixed payments, which as of March 31, 2014, aggregated $37.7 million through the end of the PPA. PNM will also pay variable costs, which cannot be quantified since the amounts are based on how much the generating plant is in operation.

This arrangement was entered into prior to December 31, 2003 and PNM was unsuccessful in obtaining the information necessary to determine if it is the primary beneficiary of the entity that owns Delta, or to consolidate that entity if it were determined that PNM is the primary beneficiary. Accordingly, PNM was unable to make those determinations and, as provided in GAAP, accounted for this PPA as an operating lease.

33

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

In December 2012, PNM entered into an agreement with the owners of Delta under which PNM would purchase the entity that owns Delta. At closing PNM would make a cash payment of $23.0 million, which would be adjusted for actual working capital compared to a targeted working capital and certain prepayments of debt. Delta has project financing debt, which PNM would retire at closing of the purchase, amounting to $15.4 million at March 31, 2014, including $3.3 million due by March 31, 2015. FERC approved the purchase on February 26, 2013 and the NMPRC approved the purchase on June 26, 2013. Closing is subject to the seller remedying specified operational, NERC compliance, and environmental issues, as well as other customary closing conditions. PNM and Delta are working with the City of Albuquerque and EPA in order to remedy certain environmental issues. PNM anticipates closing of the purchase in the second quarter of 2014.

Delta informed PNM that at March 31, 2014 and December 31, 2013, it had total assets of $23.2 million and $23.7 million, including net property, plant, and equipment of $19.7 million and $20.3 million, and total liabilities of $17.4 million and $18.2 million. Delta also indicated its revenue for the three months ended March 31, 2014 and 2013 was $1.8 million and $1.8 million and its net earnings were $0.3 million and $0.2 million. Consolidation of Delta would be immaterial to the Condensed Consolidated Balance Sheets of PNMR and PNM. Since all of Delta’s revenues and expenses are attributable to its PPA arrangement with PNM, the primary impact of consolidating Delta to the Condensed Consolidated Statements of Earnings of PNMR and PNM would be 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.

(6) 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 an interest in the EIP transmission line. Additional information concerning the Company’s lease commitments is contained in Note 7 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K.

The PVNGS leases 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 provides PNM with an option to purchase the leased assets at fair market value at the end of the lease. In addition, the leases provide 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 may be further extended for up to an additional six years (the “Maximum Option Period”) if the appraised remaining useful lives and fair values of the leased assets are greater than parameters set forth in the leases. The rental payments during the renewal option periods would be 50% of the amounts during the original terms of the leases.

Following procedures set forth in the PVNGS leases, PNM notified each of the lessors under the Unit 1 leases that it would elect to renew those leases for the Maximum Option Period on the expiration date of the original leases. In addition, PNM notified the lessor under the one Unit 2 lease containing the Maximum Option Period provision that it would elect to renew that lease for the Maximum Option Period on the expiration date of the original lease. On December 11, 2013, PNM and each of the Unit 1 lessors entered into amendments to each of the Unit 1 leases setting forth the terms and conditions that will implement the extension of the term of the lease through the agreed upon Maximum Option Period expiring on January 15, 2023. Similarly, on March 18, 2014, PNM and the lessor under the one Unit 2 lease containing the Maximum Option Period provision entered into an amendment to that lease setting forth the terms and conditions that will implement the extension of the term of the lease through the agreed upon Maximum Option Period expiring on January 15, 2024.

For the three PVNGS Unit 2 leases which do 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. On February 25, 2014, PNM and the lessor under one of the Unit 2 leases entered into a letter agreement that establishes that the purchase price, representing the fair market value, to be paid by PNM for the assets underlying that lease will be $78.1 million on January 15, 2016. This lease is for 31.2494 MW of the entitlement from PVNGS Unit 2. The lease remains in existence and PNM will record the purchase at the termination of the lease on January 15, 2016.

On May 1, 2014, PNM and the trusts that are the lessors under the other two PVNGS Unit 2 leases signed a letter agreement that establishes a binding agreement regarding the purchase price, representing the fair market value, to be paid by PNM for the assets underlying those leases of $85.2 million on January 15, 2016. These leases are for 32.76 MW of the entitlement from

34

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

PVNGS Unit 2. PNMR Development, a wholly-owned subsidiary of PNMR, is also a party to the letter agreement, which constitutes a letter of intent providing PNMR Development with the option, subject to approval by the Board and negotiation of definitive documents, to acquire the entities that own the leased assets at any time from June 1, 2014 through January 14, 2016. The early purchase price would be equal to the January 15, 2016 purchase price discounted to the actual purchase date. The early purchase amount would be $79.9 million on June 1, 2014 and would escalate to $85.2 million on January 14, 2016. The consideration paid to the lessor on an early purchase would include an additional amount equal to the discounted value of the lessors’ equity return portion of the future lease payments. Such additional consideration would be $5.8 million on June 1, 2014 and would decline to $1.2 million on January 14, 2016. PNMR and PNM are unable to predict whether or not the early purchase will occur.

(7) Fair Value of Derivative and Other Financial Instruments

Energy Related Derivative Contracts

Overview

The primary objective for the use of derivative instruments, including energy contracts, options, 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. The Company’s energy related derivative contracts manage commodity risk. PNM is required to meet the demand and energy needs of its retail and firm-requirements wholesale customers. PNM is exposed to market risk for its share of PVNGS Unit 3 and the needs of its firm-requirements wholesale customers not covered under a FPPAC. PNM’s operations are managed primarily through a net asset-backed strategy, whereby PNM’s aggregate net open forward contract position is covered by its forecasted excess generation capabilities or market purchases. PNM could be exposed to market risk if its generation capabilities were to be disrupted or if its load requirements were to be greater than anticipated. If all or a portion of load requirements were required to be covered as a result of such unexpected situations, commitments would have to be met through market purchases. Additional information concerning the Company’s energy related derivative contracts, including how commodity risk is managed, is contained in Note 8 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K.

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. Energy contracts that meet the definition of a derivative under GAAP and do not qualify, or are not designated, for the normal purchases and normal sales exception are recorded on the balance sheet at fair value at each period end. The changes in fair value are recognized in earnings unless specific hedge accounting criteria are met and elected. Normal purchases and normal sales are not marked to market and are reflected in results of operations when the underlying transactions settle.

During the three months ended March 31, 2014 and the year ended December 31, 2013, 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.

35

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

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.

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
	March 31, 2014			December 31, 2013
PNMR and PNM	(In thousands)
Current assets	$	4,003		$	4,064
Deferred charges	2,474			3,002
	6,477			7,066
Current liabilities	(5,446		)	(2,699		)
Long-term liabilities	(907		)	(1,094		)
	(6,353		)	(3,793		)
Net	$	124		$	3,273

Included in the above table are $3.0 million of current assets and $2.3 million of deferred charges at March 31, 2014 and $3.0 million of current assets and $3.0 million of deferred charges at December 31, 2013 related to contracts, which were entered into in July 2013, for the sale of energy from PVNGS Unit 3 for 2014 and 2015 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 March 31, 2014 and December 31, 2013.

At March 31, 2014 and December 31, 2013, PNMR and PNM had no amounts recognized for the legal right to reclaim cash collateral. However, at March 31, 2014 and December 31, 2013, amounts posted as cash collateral under margin arrangements were $3.1 million and $2.8 million for both PNMR and PNM. PNMR and PNM had obligations to return cash collateral of approximately $0.1 million at March 31, 2014 and $0.2 million at December 31, 2013. Cash collateral amounts are included in other current assets and other current liabilities on the Condensed 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 $0.4 million of current assets and $0.6 million of current liabilities at March 31, 2014 and $0.4 million of current assets and $0.1 million of current liabilities at December 31, 2013 related to this plan. The offsets to these amounts are recorded as regulatory assets and liabilities on the Condensed Consolidated Balance Sheets.

36

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

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
	Three Months Ended
	March 31,
	2014			2013
PNMR and PNM	(In thousands)
Electric operating revenues	$	(4,151	)	$	(4,603	)
Cost of energy	189			756
Total gain (loss)	$	(3,962	)	$	(3,847	)

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
March 31, 2014
PNMR and PNM	775,000	(3,287,548	)
December 31, 2013
PNMR and PNM	905,000	(3,343,783	)

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)
March 31, 2014
PNMR and PNM	$	2,981	$	—	$	1,913
December 31, 2013
PNMR and PNM	$	2,398	$	—	$	2,152

Sale of Power from PVNGS Unit 3

Because PNM’s 134 MW share of Unit 3 at PVNGS is not included in retail rates, that unit’s power is being sold in the wholesale market. Since January 1, 2011, PNM has been selling power from its interest in PVNGS Unit 3 at market prices. As of March 31, 2014, PNM had contracted to sell 100% of PVNGS Unit 3 output through 2015, at market price plus a premium. 

37

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

PNM has established fixed rates, which average approximately $37 per MWh, for substantially all of these sales through the end of 2014 through hedging arrangements that are accounted for as economic hedges. PNM is also partially hedged for 2015.

Non-Derivative Financial Instruments

The carrying amounts reflected on the Condensed Consolidated Balance Sheets approximate fair value for cash, receivables, and payables due to the short period of maturity. 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 a trust for PNM’s share of post-term reclamation costs related to the coal mines serving SJGS (Note 11). The fair value and gross unrealized gains of investments in available-for-sale securities are presented in the following table. At March 31, 2014 and December 31, 2013, the fair value of available-for-sale securities included $225.8 million and $222.5 million for the NDT and $4.4 million and $4.4 million for the mine reclamation trust.

	March 31, 2014				December 31, 2013
	Unrealized Gains		Fair Value		Unrealized Gains		Fair Value
PNMR and PNM			(In thousands)
Cash and cash equivalents	$	—	$	4,246	$	—	$	3,356
Equity securities:
Domestic value	14,558		41,055		14,523		39,460
Domestic growth	23,002		74,517		25,656		76,292
International and other	1,671		17,264		1,040		16,633
Fixed income securities:
U.S. Government	377		20,662		158		21,941
Municipals	2,659		61,158		1,018		58,568
Corporate and other	458		11,348		207		10,605
	$	42,725	$	230,250	$	42,602	$	226,855

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.

	Three Months Ended
	March 31,
	2014			2013
	(In thousands)
Proceeds from sales	$	22,804		$	14,284
Gross realized gains	$	3,119		$	1,391
Gross realized (losses)	$	(545	)	$	(407	)

Held-to-maturity securities are those investments in debt securities that the Company has the ability and intent to hold until maturity. Held-to-maturity securities consist of the investment in PVNGS lessor notes and certain items within other investments.

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.

38

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

At March 31, 2014, 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		PNM
	(In thousands)
Within 1 year	$	2,798	$	11,968	$	11,968
After 1 year through 5 years	21,550		33,618		32,903
After 5 years through 10 years	11,895		—		—
After 10 years through 15 years	8,521		—		—
After 15 years through 20 years	10,705		—		—
After 20 years	37,699		—		—
	$	93,168	$	45,586	$	44,871

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.

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 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, primarily the PVNGS lessor notes and other investments, fair values were determined by discounted cash flow models that take into consideration discount rates that are observable for similar type assets and liabilities. Management of the Company independently verifies the information provided by pricing services.

39

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Items recorded at fair value on the Condensed Consolidated Balance Sheets are presented below by level of the fair value hierarchy. There were no Level 3 fair value measurements at March 31, 2014 and December 31, 2013 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 (Level 2)
March 31, 2014	(In thousands)
PNMR and PNM
Available-for-sale securities
Cash and cash equivalents	$	4,246		$	4,246	$	—
Equity securities:
Domestic value	41,055			41,055		—
Domestic growth	74,517			74,517		—
International and other	17,264			17,264		—
Fixed income securities:
U.S. Government	20,662			18,909		1,753
Municipals	61,158			—		61,158
Corporate and other	11,348			2,385		8,963
	$	230,250		$	158,376	$	71,874
Commodity derivative assets	$	6,477		$	—	$	6,477
Commodity derivative liabilities	(6,353		)	—		(6,353		)
Net	$	124		$	—	$	124
December 31, 2013
PNMR and PNM
Available-for-sale securities
Cash and cash equivalents	$	3,356		$	3,356	$	—
Equity securities:
Domestic value	39,460			39,460		—
Domestic growth	76,292			76,292		—
International and other	16,633			16,633		—
Fixed income securities:
U.S. Government	21,941			20,194		1,747
Municipals	58,568			—		58,568
Corporate and other	10,605			2,245		8,360
	$	226,855		$	158,180	$	68,675
Commodity derivative assets	$	7,066		$	—	$	7,066
Commodity derivative liabilities	(3,793		)	—		(3,793		)
Net	$	3,273		$	—	$	3,273

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 three months ended March 31, 2014 and 2013.

40

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

The carrying amounts and fair values of investments in PVNGS lessor notes, other investments, and long-term debt, which are not recorded at fair value on the Condensed Consolidated Balance Sheets are presented below:

					GAAP Fair Value Hierarchy
	Carrying Amount		Fair Value		Level 1		Level 2		Level 3
March 31, 2014	(In thousands)
PNMR
Long-term debt	$	1,845,338	$	2,040,868	$	—	$	2,040,868	$	—
Investment in PVNGS lessor notes	$	42,472	$	44,871	$	—	$	—	$	44,871
Other investments	$	1,813	$	2,529	$	681	$	—	$	1,848
PNM
Long-term debt	$	1,390,627	$	1,515,097	$	—	$	1,515,097	$	—
Investment in PVNGS lessor notes	$	42,472	$	44,871	$	—	$	—	$	44,871
Other investments	$	436	$	436	$	436	$	—	$	—
TNMP
Long-term debt	$	335,944	$	396,195	$	—	$	396,195	$	—
Other investments	$	245	$	245	$	245	$	—	$	—
December 31, 2013
PNMR
Long-term debt	$	1,745,420	$	1,905,230	$	—	$	1,905,230	$	—
Investment in PVNGS lessor notes	$	52,958	$	57,279	$	—	$	—	$	57,279
Other investments	$	1,835	$	3,196	$	690	$	—	$	2,506
PNM
Long-term debt	$	1,290,618	$	1,382,938	$	—	$	1,382,938	$	—
Investment in PVNGS lessor notes	$	52,958	$	57,279	$	—	$	—	$	57,279
Other investments	$	445	$	445	$	445	$	—	$	—
TNMP
Long-term debt	$	336,036	$	390,814	$	—	$	390,814	$	—
Other investments	$	245	$	245	$	245	$	—	$	—

(8) Stock-Based Compensation

PNMR has various stock-based compensation programs, including stock options, restricted stock, and performance shares granted under the Performance Equity Plan (“PEP”). 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 and some of these awards also have time vesting requirements. Other awards of restricted stock are only subject to time vesting requirements. Additional information concerning stock-based compensation under the PEP is contained in Note 13 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K.

Restricted stock under the PEP refers to awards of stock subject to vesting, performance, or market conditions rather than to shares with contractual post-vesting restrictions. Generally, the awards vest ratably over three years from the grant date of the award. However, certain 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 stock awards.

The stock-based compensation expense related to stock options and restricted stock awards without performance or market conditions is amortized to compensation expense over the requisite vesting period, which is generally three years. However, compensation expense for awards to participants that are retirement eligible on the grant date is recognized immediately at the grant date and is not amortized. 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

41

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

market-based shares is recognized ratably over the measurement period, regardless of the actual level of achievement, provided the employees meet their service requirements. At March 31, 2014 and December 31, 2013, PNMR had unrecognized expense related to stock awards of $8.1 million and $4.6 million. 

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:

	Three Months Ended March 31,
Restricted Shares and Performance Based Shares	2014			2013
Expected quarterly dividends per share	$	0.185		$	0.165
Risk-free interest rate	0.71		%	0.38		%
Market-Based Shares
Dividend yield	2.82		%	2.86		%
Expected volatility	25.11		%	25.11		%
Risk-free interest rate	0.64		%	0.36		%

The following table summarizes activity in stock options and restricted stock awards, including performance-based and market-based shares, for the three months endedMarch 31, 2014:

	Stock Option Shares		Weighted- Average Exercise Price		Restricted Stock		Weighted- Average Grant Date Fair Value
Outstanding at beginning of period	1,343,666		$	20.63	315,305		$	17.87
Granted	—		$	—	223,348		$	20.79
Exercised	(182,407	)	$	17.86	(262,358	)	$	16.53
Forfeited	(17,151	)	$	26.43	—		$	—
Expired	(13,501	)	$	25.82	—		$	—
Outstanding at end of period	1,130,607		$	20.92	276,295		$	21.55

Included as restricted stock granted and exercised in the table above are 112,864 shares that were based upon achieving performance or market targets for 2013. The Board approved these shares in February 2014 (based upon achieving market targets, weighted at 60%, at maximum levels, and performance targets, weighted at 40%, at below threshold levels for the 2011 through 2013 performance period).

PNMR’s stock-based compensation program provides for performance or market targets through 2016. Excluded from the above table are maximums of 198,369, 179,811, and 175,735 restricted stock shares for periods ending in 2014, 2015, and 2016 that would be awarded if all performance or market criteria are achieved 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 the Company meets specific market targets at the end of 2016 and she remains an employee of the Company. If the Company achieves specific market targets at the end of

42

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

2014 and, with certain exceptions, she remains an employee of the Company, she would receive 35,000 of the total shares at that time. The retention award was made under the PEP and was approved by the Board on February 28, 2012. The above table does not include any restricted stock shares under the retention award agreement.

At March 31, 2014, the aggregate intrinsic value of stock options outstanding, all of which are exercisable, was $8.0 million with a weighted-average remaining contract life of 3.39 years. At March 31, 2014, the exercise price of 486,016 outstanding stock options is greater than the closing price of PNMR common stock on that date; therefore, those options have no intrinsic value.

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

	Three Months Ended March 31,
Stock Options	2014		2013
Weighted-average grant date fair value of options granted	$	—	$	—
Total fair value of options that vested (in thousands)	$	—	$	620
Total intrinsic value of options exercised (in thousands)	$	1,469	$	1,824
Restricted Stock
Weighted-average grant date fair value	$	20.79	$	19.82
Total fair value of restricted shares that vested (in thousands)	$	4,336	$	3,871

(9) Financing

Additional information concerning financing activities, including a TNMP cash-flow hedge that establishes a fixed interest rate on a variable rate loan, is contained in Note 6 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K.

Financing Activities

On January 8, 2014, PNM entered into a new $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.

On March 5, 2014, PNM entered into a new $175.0 million Term Loan Agreement (the “PNM 2014 Term Loan Agreement”) among PNM and The Bank of Tokyo-Mitsubishi UFJ, Ltd., 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 PNM’s existing $75.0 million PNM Term Loan Agreement. PNM also used the funds to repay other short-term amounts outstanding. The PNM Term Loan Agreement would otherwise have terminated on October 21, 2014. There were no prepayment penalties paid in connection with the termination of the PNM Term Loan Agreement. The PNM 2014 Term Loan Agreement bears interest at a variable rate, which was 1.11% at March 31, 2014, must be repaid on or before September 4, 2015, and is reflected as long-term debt on the Condensed Consolidated Balance Sheets. The PNM 2014 Term Loan Agreement includes customary covenants, including requirements to not exceed a maximum consolidated debt-to-consolidated capitalization ratio and customary events of default. The PNM 2014 Term Loan Agreement has a cross default provision and a change of control provision.

The existing TNMP 2011 Term Loan Agreement has an outstanding balance of $50.0 million that must be repaid by June 30, 2014. On December 9, 2013, TNMP entered into an agreement (the “TNMP 2013 Bond Purchase Agreement”), which provides that TNMP will issue $80.0 million aggregate principal amount of 4.03% first mortgage bonds, due 2024 (the “Series 2014A Bonds”). The terms of the TNMP 2013 Bond Purchase Agreement provide that, subject to satisfaction of certain conditions, TNMP will issue the Series 2014A Bonds on or about June 27, 2014. TNMP anticipates using $50.0 million of the proceeds from the

43

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

issuance to repay the TNMP 2011 Term Loan Agreement at its maturity and using the remaining proceeds to reduce short-term debt under the TNMP Revolving Credit Facility and/or TNMP’s intercompany borrowings from PNMR. In accordance with GAAP, borrowings under the TNMP 2011 Term Loan Agreement, which are due on June 30, 2014, are reflected as being long-term in the Condensed Consolidated Balance Sheet since the TNMP 2013 Bond Purchase Agreement demonstrates TNMP’s ability and intent to re-finance the TNMP 2011 Term Loan Agreement on a long-term basis.

Short-term Debt

PNMR has a revolving credit financing capacity of $300.0 million under the PNMR Revolving Credit Facility. PNM has a revolving credit financing capacity of $400.0 million under the PNM Revolving Credit Facility. Both of these facilities currently expire on October 31, 2018. TNMP has a revolving credit financing capacity of $75.0 million under the TNMP Revolving Credit Facility that is secured by $75.0 million aggregate principal amount of TNMP first mortgage bonds and matures on September 18, 2018. PNM also has the PNM New Mexico Credit Facility, a $50.0 million unsecured revolving credit facility that expires on January 8, 2018. At March 31, 2014, there were no borrowings outstanding under any of these facilities and the weighted average interest rate was 1.01% for borrowings outstanding under the twelve-month PNMR Term Loan Agreement, which matures in December 2014. Short-term debt outstanding consisted of:

	March 31,		December 31,
Short-term Debt	2014		2013
	(In thousands)
PNM:
Revolving credit facility	$	—	$	49,200
PNM New Mexico Credit Facility	—		—
TNMP – Revolving credit facility	—		—
PNMR:
Revolving credit facility	—		—
PNMR Term Loan Agreement	100,000		100,000
	$	100,000	$	149,200

At April 25, 2014, PNMR, PNM, and TNMP had $291.4 million, $396.8 million, and $68.7 million of availability under their respective revolving credit facilities, including reductions of availability due to outstanding letters of credit, and PNM had $50.0 million of availability under the PNM New Mexico Credit Facility. Total availability at April 25, 2014, on a consolidated basis, was $806.9 million for PNMR. As of April 25, 2014, TNMP had $41.2 million in borrowings from PNMR under their intercompany loan agreement. At April 25, 2014, PNMR, PNM and TNMP had consolidated invested cash of $2.0 million, $9.3 million, and none.

(10) Pension and Other Postretirement Benefit Plans

PNMR and its subsidiaries maintain qualified defined benefit pension plans, postretirement benefit plans providing medical and dental benefits, and executive retirement programs (“PNM Plans” and “TNMP Plans”). PNMR maintains the legal obligation for the benefits owed to participants under these plans.

Additional information concerning pension and OPEB plans is contained in Note 12 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K. Annual net periodic benefit cost (income) for the plans is actuarially determined using the methods and assumptions set forth in that note and is recognized ratably throughout the year.

44

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

PNM Plans

The following tables present the components of the PNM Plans’ net periodic benefit cost:

	Three Months Ended March 31,
	Pension Plan						OPEB Plan						Executive Retirement Program
	2014			2013			2014			2013			2014		2013
	(In thousands)
Components of Net Periodic
Benefit Cost
Service cost	$	—		$	—		$	45		$	65		$	—	$	—
Interest cost	7,541			7,035			1,159			1,028			205		180
Expected return on plan assets	(9,511		)	(10,482		)	(1,410		)	(1,261		)	—		—
Amortization of net (gain) loss	3,255			3,710			556			1,061			52		58
Amortization of prior service cost	(241		)	19			(336		)	(336		)	—		—
Net periodic benefit cost	$	1,044		$	282		$	14		$	557		$	257	$	238

PNM does not anticipate making any contributions to its pension trust in 2014 due to the current funded status of the pension plan.  PNM made contributions to its pension plan trust of $60.0 million in the three months ended March 31, 2013. Based on current law, including recent amendments to funding requirements, and estimates of portfolio performance, contributions to the PNM pension plan trust for 2015-2018 are estimated to total $61.5 million. These anticipated contributions were developed using current funding assumptions, with discount rates of 5.2% to 5.5%. Actual amounts required to be funded in the future will depend on the actuarial assumptions at that time, including the appropriate discount rate. PNM may make additional contributions at its discretion. PNM made contributions to the OPEB trust of $0.8 million and $0.5 million in the three months ended March 31, 2014 and 2013. PNM expects to make contributions to the OPEB trust totaling $3.3 million in 2014 and $14.0 million for 2015-2018.  Disbursements under the executive retirement program, which are funded by PNM and considered to be contributions to the plan, were $0.4 million and $0.4 million in the three months ended March 31, 2014 and 2013 and are expected to total $1.5 million during 2014.

TNMP Plans

The following tables present the components of the TNMP Plans’ net periodic benefit cost (income):

	Three Months Ended March 31,
	Pension Plan						OPEB Plan						Executive Retirement Program
	2014			2013			2014			2013			2014		2013
	(In thousands)
Components of Net Periodic
Benefit Cost (Income)
Service cost	$	—		$	—		$	59		$	75		$	—	$	—
Interest cost	798			772			155			141			10		9
Expected return on plan assets	(1,132		)	(1,212		)	(133		)	(126		)	—		—
Amortization of net (gain) loss	166			262			(31		)	—			—		—
Amortization of prior service cost	—			—			8			14			—		—
Net Periodic Benefit Cost (Income)	$	(168	)	$	(178	)	$	58		$	104		$	10	$	9

TNMP does not anticipate making additional contributions to its pension trust in 2014 due to the current funded status of the pension plan. TNMP made contributions to its pension plan trust of $1.0 million in the three months ended March 31, 2013.

45

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Based on current law, including recent amendments to funding requirements, and estimates of portfolio performance, TNMP estimates there would be no contributions to its pension plan trust for 2015-2018. The anticipated contributions were developed using current funding assumptions, including discount rates of 5.2% and 5.5%. Actual amounts to be funded in the future will depend on the actuarial assumptions at that time, including the appropriate discount rate. TNMP may make additional contributions at its discretion. TNMP made no contributions to the OPEB trust in the three months ended March 31, 2014 and 2013. TNMP expects to make contributions to the OPEB trust totaling $0.4 million in 2014 and $1.4 million for 2015-2018. Disbursements under the executive retirement program, which are funded by TNMP and considered to be contributions to the plan, were less than $0.1 million in the three months ended March 31, 2014 and 2013 and are expected to total $0.1 million during 2014.

(11) Commitments and Contingencies

Overview

There are various claims and lawsuits pending against the Company. The Company is also 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 occasionally enters into financial commitments in connection with its business operations. The Company is also involved in various legal and regulatory (Note 12) 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. Notwithstanding these facts, the Company has assessed these matters based on current information and made judgments concerning their potential outcome, giving due consideration to the nature of the claim, the amount and nature of damages sought, and the probability of success. Such judgments are made with the understanding that the outcome of any litigation, investigation, and 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. The Company does not expect that any known lawsuits, environmental costs, and commitments will have a material effect on its financial condition, results of operations, or cash flows.

Additional information concerning commitments and contingencies is contained in Note 16 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K.

Commitments and Contingencies Related to the Environment

Nuclear Spent Fuel and Waste Disposal

Nuclear power plant operators are required to enter into spent fuel disposal contracts with the DOE that require the DOE to accept and dispose of all spent nuclear fuel and other high-level radioactive wastes generated by domestic power reactors. Although the Nuclear Waste Policy Act required the DOE to develop a permanent repository for the storage and disposal of spent nuclear fuel by 1998, the DOE announced that it would not be able to open the repository by 1998 and sought to excuse its performance of these requirements. In November 1997, the D.C. 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. In 2010, the court ordered an award to the PVNGS owners for their damages claim for costs incurred through December 2006. APS filed a subsequent lawsuit, on behalf of itself and the other PVNGS owners, against DOE in the Court of Federal Claims on December 19, 2012. The lawsuit alleges that from January 1, 2007 through June 30, 2011, additional damages were incurred due to DOE’s continuing failure to remove spent nuclear fuel and high level waste from PVNGS. PNM is unable to predict the outcome of this matter.

46

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

PNM estimates that it will incur approximately $58.0 million (in 2013 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 March 31, 2014 and December 31, 2013, PNM had a liability for interim storage costs of $12.0 million and $11.9 million included in other deferred credits.

On June 8, 2012, the D.C. 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. The D.C. Circuit found that the agency’s 2010 Waste Confidence Decision update constituted a major federal action, which requires either an EIS or a finding of no significant impact from the agency’s actions. The D.C. Circuit found that the NRC’s evaluation of the environmental risks from spent nuclear fuel was deficient, and therefore remanded the 2010 Waste Confidence Decision update for further action. In September 2012, the NRC issued a directive to its staff to proceed with development of a generic EIS to support an updated Waste Confidence Decision within 24 months. In September 2013, the NRC issued its draft EIS to support an updated Waste Confidence Decision. In late 2013, the NRC held a series of nationwide public meetings to receive stakeholder input on the draft EIS. NRC Commissioners have instructed the staff to issue the final generic EIS and rule by no later than September 2014. Untimely resolution by the NRC of the remand from the D.C. Circuit could have an adverse impact on certain NRC licensing actions. Currently, PVNGS does not have any licensing actions pending with the NRC. The petitioners had also sought a writ requiring the NRC to comply with the law and resume processing DOE’s pending license application for a nuclear waste site at Yucca Mountain in Nevada. In August 2013, the D.C. Circuit ordered the NRC to resume reviewing the license application. PNM is unable to predict the impact of these decisions.

In 2011, the National Association of Regulatory Utility Commissioners and the Nuclear Energy Institute challenged 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. The fee applicable to PVNGS Units 1 and 2 is recovered by PNM in its retail rates. In June 2012, the D.C. Circuit held that DOE failed to conduct a sufficient fee analysis in making the 2010 determination. The D.C. Circuit remanded the 2010 determination to the DOE with instructions to conduct a new fee adequacy determination within six months. In February 2013, upon completion of DOE’s revised one-mill fee adequacy determination, the court reopened the proceedings. On November 19, 2013, the D.C. Circuit ordered the DOE to notify Congress of the intent to suspend collecting annual fees for nuclear waste disposal from nuclear power plant operators. On January 3, 2014, the DOE notified Congress of the intention to suspend collection of the one-mill fee, subject to Congress’ disapproval. PNM anticipates challenges to this action and is unable to predict its ultimate outcome, but is continuing to accrue the one-mill fee. In 2013, the one-mill fee for PNM’s share of the output from all three units at PVNGS amounted to $3.0 million.

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 Determination Process - 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 found that BART to reduce NOx emissions from SJGS is selective non-catalytic reduction

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technology (“SNCR”). Nevertheless, in August 2011, EPA published its FIP, stating that it was required to do so by virtue of a consent decree it had entered into with an environmental group in litigation concerning the interstate transport requirements of the CAA. The FIP included a regional haze BART determination for SJGS that requires installation of selective catalytic reduction technology (“SCR”) with stringent NOx emission limits on all four units by September 21, 2016.

PNM, the Governor of New Mexico, and NMED petitioned the Tenth Circuit to review EPA’s decision and requested EPA to reconsider its decision. The Tenth Circuit denied petitions to stay the effective date of the rule on March 1, 2012. These parties have also formally asked EPA to stay the effective date of the rule. Several environmental groups have intervened in support of EPA. WEG also filed an action to challenge EPA’s rule in the Tenth Circuit, seeking to shorten the rule’s compliance period from five years to three years and PNM has intervened in this action. Oral arguments on the merits of the FIP challenges were held in October 2012 in the Tenth Circuit. In accordance with the court’s order, the parties have filed supplemental information.

In litigation involving several environmental groups, the United States District Court for the District of Columbia entered a consent decree, which, as amended, required EPA to issue a final rulemaking on New Mexico’s regional haze SIP by November 15, 2012. EPA approved all components of the SIP, except for the NOx BART determination for SJGS. With respect to that element of the SIP, EPA determined that with the FIP in place, it had met its obligation under the consent decree.

Because the unchanged compliance deadline of the FIP required PNM to continue to take steps to commence installation of SCRs at SJGS, PNM entered into a contract in October 2012 with an engineering, procurement, and construction contractor to install SCRs on behalf of the SJGS owners. The construction contract, which includes termination provisions in the event that SCRs are determined in the future to be unnecessary, has been suspended through November 1, 2014. At that time, PNM estimated the total cost to install SCRs on all four units of SJGS to be between approximately $824 million and $910 million, which amounts include costs for construction management, gross receipts taxes, AFUDC, and other PNM costs, although final costs were to be refined through an “open book” subcontractor bidding process. The costs for the project to install SCRs would also encompass installation of technology to comply with the NAAQS requirements described below.

Also, 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 equipment would be required to be installed to meet the NAAQS requirements described below, the cost of which had been estimated to total between approximately $105 million and $110 million for all four units of SJGS. The estimates for SNCRs and the NAAQS requirements include gross receipts taxes, AFUDC, and other PNM costs.

Based upon its current SJGS ownership interest, PNM’s share under either SCRs or SNCRs would be about 46.3%.

During 2012 and early 2013, PNM, as the operating agent for SJGS, engaged in discussions with NMED and EPA regarding an alternative to the FIP and SIP. Following approval by a majority of the other SJGS owners, PNM, NMED, and EPA agreed on February 15, 2013 to pursue a revised plan that could provide a new BART path to comply with federal visibility rules at SJGS, subject to approval by EIB and EPA. The terms of the non-binding agreement would result in 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. Certain aspects of this alternative are subject to approval by the NMPRC. At March 31, 2014, PNM’s net book value of its current ownership share of SJGS Units 2 and 3 was approximately $286 million.

Contemporaneously with the signing of the non-binding agreement, EPA indicated in writing that if the terms agreed to do not move forward due to circumstances outside of the control of PNM and NMED, EPA will work with the State of New Mexico and PNM to create a reasonable FIP compliance schedule to reflect the time used to develop the revised SIP.

This revised plan primarily focuses on how SJGS would meet the regional haze rule and also indicates that PNM would build a natural gas-fired generating plant in the “four corners” region to partially replace the capacity from the retired coal units. Detailed replacement power strategies also would be finalized.  PNM believes adequate replacement power alternatives will be available to meet its generation needs and ensure reliability.

It was contemplated that the retirement of SJGS Units 2 and 3 under the revised plan might result in shifts in ownership among SJGS owners or other changes in the contractual cost sharing arrangements, as may be agreed upon by the owners. See SJGS Ownership Restructuring Matters below. Owners of the affected units also may seek approvals of their utility commissions

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or governing boards.

The parties file periodic status reports with the Tenth Circuit.  To demonstrate that progress has been made toward settling the Tenth Circuit litigation, information, including the non-binding agreement and its accompanying timeline, was submitted to the Tenth Circuit. Following the parties’ submission of their status reports, on February 28, 2013, the Tenth Circuit referred the litigation to the Tenth Circuit Mediation Office, which has authority to require the parties to attend mediation conferences to informally resolve issues in the pending appeals. On October 17, 2013, the court ruled on a motion filed by PNM for abatement of the pending petitions for review and seeking deferral of briefing on a simultaneously filed motion to stay the EPA rule. The court placed the pending petitions for review in abeyance and set a schedule for the parties to file status reports. The court ruled that, if at any time the agreement in principle fails or is not implemented as was indicated in the term sheet and timeline, any party to the litigation may file a motion seeking to lift the abatement.  PNM is continuing to evaluate the impacts of these matters, but is unable to predict their ultimate outcomes.

Due to the long lead times on certain equipment purchases, PNM began taking steps to prepare for the potential installation of SNCRs on Units 1 and 4. In April 2013, PNM issued an RFP for SNCR system design and technology. In May 2013, PNM entered into an SNCR equipment and related services contract with an SNCR technology provider, but has not yet entered into a construction and procurement contract.

In accordance with the revised plan, PNM submitted a new BART analysis to NMED on April 1, 2013, reflecting the terms of the non-binding agreement, including the installation of SNCRs on Units 1 and 4 and the retirement of Units 2 and 3. NMED developed a revised SIP and submitted it to the EIB for approval in May 2013. After a public hearing, the EIB approved the revised SIP in September 2013 and the revised SIP was submitted to EPA for approval on October 18, 2013. EPA deemed the SIP application complete on December 17, 2013. It is anticipated that EPA will publish its proposed action on the revised SIP within 135 days of determining it was complete. On April 30, 2014, EPA issued an advance copy of its proposed approval of the revised SIP. It is anticipated that the notice will be published in the Federal Register in mid-May 2014, which will start the 30-day public comment period that is part of the EPA process. Final EPA action on the revised SIP is expected by about the end of September 2014.

On December 20, 2013, PNM made a filing with the NMPRC requesting certain approvals necessary to effectuate the revised SIP. In this filing, PNM requests:

• 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, currently estimated to be approximately $205 million, 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 equipment and the additional equipment to comply with NAAQS requirements on SJGS Units 1 and 4, not to exceed a total cost of $82 million

• A CCN for an exchange of capacity out of SJGS Unit 3 and into SJGS Unit 4, resulting in ownership of an additional 78 MW in Unit 4 for PNM; the net impact of this exchange and the retirement of Units 2 and 3 would be a reduction of 340 MW in PNM’s ownership of SJGS

In its filing, PNM requested the NMPRC to issue its final ruling on the application no later than December 2014. On February 11, 2014, the Hearing Examiner issued an order finding that PNM’s application is complete. The order also stated that there was not a statutory time clock for the request to retire SJGS Units 2 and 3 and the statutory time clock on the CCN requests has not yet begun. The Hearing Examiner found that the NMPRC should proceed with the review of PNM’s application and establish a schedule that would allow NMPRC action on the application by the end of 2014. A public hearing is scheduled to begin on August 19, 2014.

The above estimate of PNM’s share of the costs to install SNCRs and the additional equipment to comply with NAAQS requirements on SJGS Units 1 and 4 includes gross receipts taxes, AFUDC, and other PNM costs. This amount and the above estimate of net book value of SJGS Units 2 and 3 at December 31, 2017 reflect the requested exchange of 78 MW of capacity out of SJGS Unit 3 and into SJGS Unit 4 resulting in PNM’s ownership share of SJGS Units 1 and 4 aggregating approximately 52%. The December 20, 2013 NMPRC filing identifies a new 177 MW natural gas fired generation source and 40 MW of new utility-

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(Unaudited)

scale solar PV generation to replace a portion of PNM’s share of the reduction in generating capacity due to the retirement of SJGS Units 2 and 3. Specific approvals to acquire these facilities and the treatment of associated costs will be made in future filings. PNM estimates the cost of these identified resources would be approximately $276.3 million. These amounts are included in PNM’s current construction expenditure forecast although approval of the plan remains subject to numerous conditions. 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 would increase with the installation of either SCRs or SNCRs. See Note 12 for additional information concerning PNM’s filing for NMPRC approvals regarding these matters.

As discussed under SJGS Ownership Restructuring Matters below, the owners of SJGS are attempting to negotiate agreements concerning numerous matters, the resolution of which is necessary in order to facilitate the shutdown of SJGS Units 2 and 3 and comply with the revised SIP. 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. Although the negotiations among the SJGS owners are continuing, no agreements have been reached. PNM’s ultimate ownership percentage in SJGS Unit 4 will depend on the final resolution of the negotiations among the SJGS owners. Depending upon the terms and conditions agreed to as a result of the negotiations, including PNM’s share of the capacity of SJGS Unit 4, PNM may amend its December 20, 2013 filing with the NMPRC. However, PNM does not anticipate a change in the nature and capacity of replacement power required by PNM as a result of the on-going negotiations.

PNM can provide no assurance that the requirements of the plan agreed to on February 15, 2013 will be accomplished within the required timeframes or at all. If the February 15, 2013 plan is not implemented, PNM would seek to work with NMED and EPA to develop a revised timetable for implementation of the FIP. If an agreement on a revised timetable cannot be reached, PNM will likely be unable to complete the installation of SCRs on all four units at SJGS by the FIP deadline of September 21, 2016. In such event, PNM would need to rely on EPA’s pledge to work with PNM and the State of New Mexico to develop a reasonable FIP compliance plan or otherwise negotiate a solution with EPA or seek relief from the Tenth Circuit in order to continue to be able to operate the plant, including during the installation process for any alternate solution. If relief is not granted, PNM could be forced to temporarily cease operation of some or all of the SJGS units. If a shutdown was required, PNM would then have to acquire temporary replacement power through short-term or open-market purchases in order to serve the needs of its customers. There can be no assurance that sufficient replacement power will be available to serve PNM’s needs or, if available, what costs would be incurred.

PNM is unable to predict the ultimate outcome of these matters or what additional pollution control equipment will be required at SJGS.PNM will seek recovery from its ratepayers for all costs that may be incurred as a result of the CAA requirements. Although the additional equipment and other final requirements will result in additional capital and operating costs being incurred, PNM believes that its access to the capital markets is sufficient to be able to finance its share of the installation. It is possible that requirements to comply with the CAA, combined with the financial impact of possible future climate change regulation or legislation, if any, 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.

SJGS Ownership Restructuring Matters - As discussed in the 2013 Annual Report on Form 10-K, 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 and the contract with SJCC to supply the coal requirements of the plant expires on December 31, 2017. The California participants have indicated that, under California law, they may be prohibited from making significant capital improvements to SJGS. The California participants have stated they would be unable to fully fund the construction of either SCRs or SNCRs at SJGS and have expressed the intent to exit their ownership in SJGS no later than the expiration of the current SJPPA. One other participant has also expressed a similar intent to exit ownership in the plant. The participants intending to exit ownership in SJGS currently own 50.0% of SJGS Unit 3 and 38.8% of SJGS Unit 4. PNM currently owns 50.0% of SJGS Unit 3 and 38.5% of SJGS Unit 4. PNM is unable to predict the actions of the SJGS participants. Likewise, PNM cannot predict the impact of those actions on the ownership of SJGS or the operations of SJGS and PNM.

The SJGS participants have engaged in negotiations concerning the implementation of the revised SIP to address BART at SJGS. These negotiations included potential shifts in ownership among participants and between Units 3 and 4 in order to facilitate the shutdown of Units 2 and 3 to comply with the revised SIP and to accommodate the intent of the participants desiring

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(Unaudited)

to exit ownership in SJGS. This could have resulted in certain of the continuing participants, including PNM, acquiring additional ownership interests in Unit 4 prior to the shutdown of SJGS Units 2 and 3. Based on the status of negotiations at the time of PNM’s December 20, 2013 NMPRC filing, PNM requested NMPRC approval to exchange 78 MW of its capacity in SJGS Unit 3 for an equal amount of capacity in SJGS Unit 4. Although negotiations are continuing, no agreements have been reached. The ultimate outcome of these negotiations could result in PNM acquiring more than 78 MW of SJGS Unit 4. The discussions among the SJGS participants regarding restructuring have also included, among other matters, the treatment of plant decommissioning obligations, mine reclamation obligations, environmental matters, and certain ongoing operating costs. The SJGS participants have engaged a mediator to assist in facilitating resolution of a number of outstanding matters among the owners. PNM is unable to predict the outcome of the negotiations.

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 common property. As provided in the SJPPA, specified percentages of both the outstanding participant shares, based on MW ownership, and the number of participants in the unit or common property must be obtained in order for a capital improvement project to be approved. PNM presented the SNCR project, including NAAQS compliance requirements, to the SJGS participants in Unit 1 and Unit 4 for approval in late October 2013. The project was approved for Unit 1, but the Unit 4 project, which includes some of the California participants, did not obtain the required percentage of votes for approval. Other capital projects related to Unit 4 were also not approved by the participants. The SJPPA provides that PNM, in its capacity as operating agent of SJGS, is authorized and obligated to take reasonable and prudent actions necessary for the successful and proper operation of SJGS pending the resolution, by arbitration or otherwise, of any inability or failure to agree by the participants. PNM must evaluate its responsibilities and obligations as operating agent under the SJPPA regarding the SJGS Unit 4 capital projects that were not approved by the participants and take reasonable and prudent actions as it deems necessary. On March 11, 2014, PNM requested that the owners of Unit 4 approve the expenditure of $1.9 million of costs critical to being able to comply with the time frame in the revised SIP with respect to the Unit 4 project. The Unit 4 owners did not approve the expenditures. Thereupon, PNM issued a “Prudent Utility Practice” notice under the SJPPA indicating PNM was restarting certain critical activities to keep the Unit 4 SNCR project on schedule. PNM cannot predict the outcome of this matter, its impact on SJGS’ compliance with the CAA, or the impact on PNM’s financial position, results of operations, and cash flows.

Four Corners

On August 6, 2012, EPA issued its 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 close permanently 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 shutdown 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.

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.  The Navajo Nation approved these amendments in March 2011.  The effectiveness of the amendments also requires the approval of the DOI, as does a related federal rights-of-way grant, which the Four Corners participants are pursuing.  A federal environmental review is underway as part of the DOI review process.  In March 2014, APS received a draft of the EIS in connection with the DOI review process.  Comments on the draft EIS are due by the May 27, 2014.  APS will also require a PSD permit from EPA to install SCR control technology at Four Corners.  PNM cannot predict whether these federal approvals will be granted, and if so on a timely basis, or whether any conditions that may be attached to them will be acceptable to the Four Corners participants.

The Four Corners participants’ obligations to comply with EPA’s final BART determinations, coupled with the financial impact of possible future climate change regulation or legislation, other environmental regulations, and other business considerations, could jeopardize the economic viability of Four Corners or the ability of individual participants to continue their participation in Four Corners.

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(Unaudited)

PNM is continuing to evaluate the impacts of EPA’s BART determination for Four Corners. PNM estimates its share of costs, including PNM’s AFUDC, to be up to approximately $80.3 million for post-combustion controls at Four Corners Units 4 and 5. PNM would seek recovery from its ratepayers of all costs that are ultimately incurred. PNM is unable to predict the ultimate outcome of this matter.

Four Corners BART FIP Challenge

On October 22, 2012, WEG filed a petition for review in the Ninth Circuit challenging the Four Corners BART FIP.  In its petition, WEG alleges that the final BART rule results in more air pollution being emitted into the air than allowed by law and that EPA failed to follow the requirements of the ESA.  APS intervened in this matter and filed a motion to dismiss this lawsuit for lack of jurisdiction or alternatively to transfer the lawsuit to the Tenth Circuit. On February 25, 2013, the Ninth Circuit denied APS’ motion to dismiss, but granted the request to transfer the case to the Tenth Circuit. Oral argument was presented before the Tenth Circuit on January 23, 2014. A decision is expected before the end of 2014. PNM cannot currently predict the outcome of this matter or the range of its potential impact.

Regional Haze Challenges

On December 27, 2012, WEG filed a petition for review in the Tenth Circuit challenging the SO₂ and particulate matter emissions elements of EPA’s approval of New Mexico’s Regional Haze SIP.  On February 26, 2013, HEAL Utah and other environmental groups filed petitions in the Tenth Circuit challenging EPA’s final approval of the remaining elements of New Mexico’s Regional Haze SIP, as well as EPA’s approval of the Albuquerque/Bernalillo County Air Quality Control Board SIP. PNM was granted intervention in both matters and the Tenth Circuit consolidated the two matters based on the similarity of issues. Oral argument was heard before the Tenth Circuit on March 20, 2014. PNM is continuing to evaluate the impacts of these matters, but is unable to predict their ultimate outcomes.

National Ambient Air Quality Standards (“NAAQS”)

The CAA requires EPA to set NAAQS for pollutants considered harmful to public health and the environment. EPA has set NAAQS for certain pollutants, including NOx, SO₂,ozone, and particulate matter. In 2010, EPA updated the primary NOx and SO₂ NAAQS to include a 1-hour maximum standard while retaining the annual standards for NOx and SO₂ and the 24-hour SO₂ standard. New Mexico is in attainment for the 1-hour NOx NAAQS. EPA has issued draft guidance on how to determine whether areas in a state comply with the new 1-hour SO₂ NAAQS. On May 21, 2013, EPA released draft guidance on characterizing air quality in areas with limited or no monitoring data near existing SO₂ sources. This characterization will result in these areas being designated as attainment, nonattainment, or unclassified for compliance with the 1-hour SO₂ NAAQS.  Several states and environmental groups have filed lawsuits challenging EPA’s decision to designate only a few areas as “nonattainment” within the 3-year deadline, while leaving the rest of the country to wait until the states either obtain better monitoring data or conduct computer modeling.  Although the determination process has not been finalized, PNM believes that compliance with the 1-hour SO₂ standard may require operational changes and/or equipment modifications at SJGS. On April 6, 2012, PNM filed an application for an amendment to its air permit for SJGS, which would be required for the installation of either SCRs or SNCRs described above. In addition, this application included a proposal by PNM to install equipment modifications for the purpose of reducing fugitive emissions, including NOx, SO₂, and particulate matter. These modifications would help SJGS meet the NAAQS. It is anticipated that this technology would be installed at the same time as the installation of regional haze BART controls, in order to most efficiently and cost effectively conduct construction activities at SJGS. The cost of this technology is dependent upon the type of control technology that is ultimately determined to be NOx BART at SJGS. See Regional Haze - SJGS above.

EPA finalized revisions to its NAAQS for fine particulate matter on December 14, 2012. PNM believes the equipment modifications discussed above will assist the plant in complying with the particulate matter NAAQS.

In January 2010, EPA announced it would strengthen the 8-hour ozone standard by setting a new standard in a range of 0.060-0.070 parts per million. EPA is reviewing its 2008 standard and has stated it intends to propose a new standard. Although EPA has not announced a timeline for its review, it may release new proposed standards in the second half of 2014.  Depending upon where the standard for ozone is set, San Juan County, where SJGS is situated, could be designated as not attaining the standard for ozone. If that were to occur, NMED would have responsibility for bringing the county into compliance and would look at all sources of NOx and volatile organic compounds since these are the pollutants that form ground-level ozone. As a result, SJGS

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(Unaudited)

could be required to install further NOx controls to meet a new ozone NAAQS. In addition, other counties in New Mexico, including Bernalillo County, may be designated as non-attainment. PNM cannot predict the outcome of this matter, the impact of other potential environmental mitigations, or if additional NOx controls would be required at any of its affected facilities as a result of ozone non-attainment designation.

Citizen Suit Under the Clean Air Act

The operations of SJGS are covered by a Consent Decree with the Grand Canyon Trust and Sierra Club and with the NMED that includes stipulated penalties for non-compliance with specified emissions limits. Stipulated penalty amounts are placed in escrow on a quarterly basis pending review of SJGS’s emissions performance. In May 2010, PNM filed a petition with the federal district court seeking a judicial determination on a dispute relating to PNM’s mercury controls. NMED and plaintiffs seek to require PNM to implement additional mercury controls. PNM estimates the implementation would increase annual mercury control costs for the entire station, which are currently $0.7 million, to a total of $6.6 million. On March 23, 2014, the court entered a stipulated order reflecting an agreement reached by the parties. In accordance with the stipulated order, PNM will repeat the mercury study required under the Consent Decree using sorbent traps instead of the monitoring system used in the initial study. The results of the mercury study will establish the activated carbon injection rate that maximizes mercury removal at SJGS, as required under the Consent Decree. PNM cannot predict the ultimate outcome of this matter.

Section 114 Request

In April 2009, APS received a request from EPA under Section 114 of the CAA seeking detailed information regarding projects at and operations of Four Corners. EPA has taken the position that many utilities have made physical or operational changes at their plants that should have triggered additional regulatory requirements under the NSR provisions of the CAA. APS has responded to EPA’s request. PNM is currently unable to predict the timing or content of EPA’s response, if any, or any resulting actions.

Four Corners Clean Air Act Lawsuit

In October 2011, Earthjustice, on behalf of several environmental organizations, filed a lawsuit in the United States District Court for the District of New Mexico against APS and the other Four Corners participants alleging violations of the NSR provisions of the CAA and NSPS violations. The plaintiffs seek to have the court enjoin operations at Four Corners until APS applies for and obtains any required NSR permits and complies with the NSPS. The plaintiffs further request the court to order the payment of civil penalties, including a beneficial mitigation project. On April 2, 2012, the Four Corners participants filed motions to dismiss. The case is being held in abeyance while the parties seek to negotiate a settlement. On March 30, 2013, upon joint motion of the parties, the court issued an order deeming the motions to dismiss withdrawn without prejudice during pendency of the stay. At such time as the stay is lifted, the Four Corners owners may reinstate their motions to dismiss without risk of default. PNM cannot currently predict the outcome of this matter or the range of its potential impact.

WEG v. OSM NEPA Lawsuit

In February 2013, WEG filed a Petition for Review in the United States District Court of Colorado against OSM challenging federal administrative decisions affecting seven different mines in four states issued at various times from 2007 through 2012.  In its petition, WEG challenges several unrelated mining plan modification approvals, which were each separately approved by OSM.  Of the fifteen claims for relief in the WEG Petition, two concern SJCC’s San Juan mine.  WEG’s allegations concerning the San Juan mine arise from OSM administrative actions in 2008.  WEG alleges various National Environmental Policy Act violations against OSM, including, but not limited to, OSM’s alleged failure to provide requisite public notice and participation, alleged failure to analyze certain environmental impacts, and alleged reliance on outdated and insufficient documents.  WEG’s petition seeks various forms of relief, including voiding, reversing, and remanding the various mining modification approvals, enjoining the federal defendants from re-issuing the mining plan approvals for the mines, and enjoining operations at the seven mines. SJCC intervened in this matter. The Court granted SJCC’s motion to sever its claims from the lawsuit and transfer venue to the United States District Court for the District of New Mexico. PNM cannot currently predict the outcome of this matter or the range of its potential impact.

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PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Navajo Nation Environmental Issues

Four Corners is located on the Navajo Reservation and is held under an easement granted by the federal government, as well as a lease from the Navajo Nation. The Navajo Acts purport to give the Navajo Nation Environmental Protection Agency authority to promulgate regulations covering air quality, drinking water, and pesticide activities, including those activities that occur at Four Corners. In October 1995, the Four Corners participants filed a lawsuit in the District Court of the Navajo Nation challenging the applicability of the Navajo Acts to Four Corners. Although an agreement was reached resolving claims related to the CAA, the agreement does not address or resolve any dispute relating to other aspects of the Navajo Acts. PNM cannot currently predict the outcome of these matters or the range of their potential impacts.

Cooling Water Intake Structures

EPA issued its proposed cooling water intake structures rule in April 2011, which would provide national standards for certain cooling water intake structures at existing power plants and other facilities under the Clean Water Act to protect fish and other aquatic organisms by minimizing impingement mortality (the capture of aquatic wildlife on intake structures or against screens) and entrainment mortality (the capture of fish or shellfish in water flow entering and passing through intake structures). The proposed rule would require facilities such as Four Corners and SJGS to either demonstrate that impingement mortality at its cooling water intakes does not exceed a specified rate or reduce the flow at those structures to less than a specified velocity and to take certain protective measures with respect to impinged fish. The proposed rule would also require these facilities to either meet the definition of a closed cycle recirculating cooling system or conduct a “structured site-specific analysis” to determine what site-specific controls, if any, should be required.

The proposed rule would require existing facilities to comply with the impingement mortality requirements as soon as possible, but no later than eight years after the effective date of the rule, and to comply with the entrainment requirements as soon as possible under a schedule of compliance established by the permitting authority. EPA was required to issue a final rule by June 27, 2013; however, that date was extended to January 14, 2014. On January 10, 2014, EPA announced it would not meet that deadline. On February 10, 2014, EPA indicated it would issue the final rule by April 17, 2014 and did not intend to seek any more extensions. However, on April 16, 2014, EPA announced the final rule will not be published until May 16, 2014 due to the pending consultation activities with the U.S. Fish and Wildlife Service and the National Marine Fisheries Service. PNM and APS continue to follow the rulemaking and are performing analyses to determine the potential costs of compliance with the proposed rule. PNM is unable to predict the outcome of this matter or a range of the potential costs of compliance.

Effluent Limitation Guidelines

On June 7, 2013, EPA published proposed revised wastewater effluent limitation guidelines establishing technology-based wastewater discharge limitations for fossil fuel-fired electric power plants.  EPA’s proposal offers numerous options that target metals and other pollutants in wastewater streams originating from fly ash and bottom ash handling activities, scrubber activities, and non-chemical metal cleaning waste operations.  The preferred alternatives differ with respect to the scope of requirements that would be applicable to existing discharges of pollutants found in wastestreams generated at existing power plants. All four alternatives would establish a “zero discharge” effluent limit for all pollutants in fly ash transport water. However, requirements governing bottom ash transport water differ depending on which alternative EPA ultimately chooses and could range from effluent limits based on Best Available Technology Economically Achievable to “zero discharge” effluent limits. Depending on which alternative EPA finalizes, Four Corners may be required to change equipment and operating practices affecting boilers and ash handling systems, as well as change its waste disposal techniques. PNM has reviewed the proposed rule and continues to assess the potential impact to SJGS and Reeves Station, the only PNM-operated power plants that would be covered by the proposed rule. On April 9, 2014, several environmental groups agreed to allow EPA until September 30, 2015 to issue final effluent limits. Under the agreement, EPA will not seek any further extensions and will follow through on a separate agreement to issue a final rule on coal ash waste disposal by December 19, 2014. If EPA misses the December 19, 2014 deadline to issue a coal ash rule, then the agreement allows the environmental groups to require the EPA to issue the final effluent limits earlier. PNM is unable to predict the outcome of this matter or a range of the potential costs of compliance. 

54

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Santa Fe Generating Station

PNM and the NMED are parties to agreements under which PNM installed a remediation system to treat water from a City of Santa Fe municipal supply well, an extraction well, and monitoring wells to address gasoline contamination in the groundwater at the site of the former Santa Fe Generating Station and service center. PNM believes the observed groundwater contamination originated from off-site sources, but agreed to operate the remediation facilities until the groundwater meets applicable federal and state standards or until the NMED determines that additional remediation is not required, whichever is earlier. The City of Santa Fe has indicated that since the City no longer needs the water from the well, the City would prefer to discontinue its operation and maintain it only as a backup water source. However, for PNM’s groundwater remediation system to operate, the water well must be in service. Currently, PNM is not able to assess the duration of this project or estimate the impact on its obligations if the City of Santa Fe ceases to operate the water well.

The Superfund Oversight Section of the NMED has conducted multiple investigations into the chlorinated solvent plume in the vicinity of the site of the former Santa Fe Generating Station. In February 2008, a NMED site inspection report was submitted to EPA, which states that neither the source nor extent of contamination has been determined and also states that the source may not be the former Santa Fe Generating Station. The NMED investigation is ongoing. In January 2013, NMED notified PNM that monitoring results from April 2012 showed elevated concentrations of nitrate in three monitoring wells and an increase in free-phase hydrocarbons in another well. None of these wells are routinely monitored as part of PNM’s obligations under the settlement agreement. In April 2013, NMED conducted the same level of testing on the wells as was conducted in April 2012, which produced similar results. PNM voluntarily agreed to conduct similar sampling activities on the site beginning in April 2014, as well as more specific “fingerprint” analysis, which may help identify potential off-site sources. PNM is unable to predict the outcome of this matter and does not believe the former generating station is the source of the nitrates or the increased levels of free-phase hydrocarbons, but no conclusive determinations have been made.

Coal Combustion Byproducts Waste Disposal

CCBs consisting of fly ash, bottom ash, and gypsum from SJGS are currently disposed of in the surface mine pits adjacent to the plant. SJGS does not operate any CCB impoundments. The Mining and Minerals Division of the New Mexico Energy, Minerals and Natural Resources Department currently regulates mine placement of ash with federal oversight by the OSM. APS disposes of CCBs in ash ponds and dry storage areas at Four Corners and also sells a portion of its fly ash for beneficial uses, such as a constituent in concrete production.  Ash management at Four Corners is regulated by EPA and the New Mexico State Engineer’s Office. 

In June 2010, EPA published a proposed rule that includes two options for waste designation of coal ash. One option is to regulate CCBs as a hazardous waste, which would allow EPA to create a comprehensive federal program for waste management and disposal of CCBs. The other option is to regulate CCBs as a non-hazardous waste, which would provide EPA with the authority to develop performance standards for waste management facilities handling the CCBs and would be enforced primarily by state authorities or through citizen suits. Both options allow for continued use of CCBs in beneficial applications. EPA’s proposal does not address the placement of CCBs in surface mine pits for reclamation. An OSM CCB rulemaking team has been formed to develop a proposed rule. 

On April 5, 2012, several environmental groups, including Sierra Club, filed a citizen suit in the D.C. Circuit claiming that EPA has failed to review and revise RCRA’s regulations with respect to CCBs. The groups allege that EPA has already determined that revisions to the CCBs regulations are necessary and that EPA now has a non-discretionary duty to revise the regulations. The environmental groups asked the court to direct EPA to complete its review of the regulation of CCBs and a hazardous waste analytical procedure and to issue necessary revisions of such regulations as soon as possible. Two industry group members subsequently filed separate lawsuits in the D.C. Circuit seeking to ensure that disposal of coal ash would not be regulated as a hazardous waste. The environmental and industry lawsuits have been consolidated. On January 29, 2014, EPA entered into a consent decree directing EPA to publish its final action regarding whether or not to pursue the proposed non-hazardous waste option for CCBs by December 19, 2014.

PNM advocates for the non-hazardous regulation of CCBs. If CCBs are ultimately regulated as a hazardous waste, costs could increase significantly. PNM would seek recovery from its ratepayers of all costs that are ultimately incurred. PNM cannot

55

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

predict the outcome of EPA’s or OSM’s proposed rulemaking regarding CCB regulation, including mine placement of CCBs, or whether these actions will have a material impact on its operations, financial position, or cash flows.

Hazardous Air Pollutants (“HAPs”) Rulemaking

In December 2011, the EPA issued its final Mercury and Air Toxics Standards (“MATS”) to reduce emissions of heavy metals, including mercury, arsenic, chromium, and nickel, as well as acid gases, including hydrochloric and hydrofluoric gases, from coal and oil-fired electric generating units with a capacity of at least 25 MW. Existing facilities will generally have up to four years to demonstrate compliance with the new rule. PNM’s assessment of MATS indicates that the control equipment currently used at SJGS allows the plant to meet the emission standards set forth in the rule. With regard to mercury, stack testing performed for EPA during the MATS rulemaking process showed that SJGS achieved a mercury removal rate of 99% or greater. APS has determined that no additional equipment will be required at Four Corners Units 4 and 5 to comply with the rule. 

Other Commitments and Contingencies

Coal Supply

The coal requirements for SJGS are being supplied by SJCC, a wholly owned subsidiary of BHP. In addition to coal delivered to meet the current needs of SJGS, PNM prepays SJCC for certain coal mined but not yet delivered to the plant site. At March 31, 2014 and December 31, 2013, prepayments for coal, which are included in other current assets, amounted to $16.0 million and $12.3 million. These amounts reflect delivery of a portion of the prepaid coal and its utilization due to the mine fire incident described below. SJCC holds certain federal, state, and private coal leases and has an underground coal sales agreement to supply processed coal for operation of SJGS through 2017. Under the coal sales agreement, SJCC is reimbursed for all costs for mining and delivering the coal, including an allocated portion of administrative costs, and receives a return on its investment. BHP Minerals International, Inc. has guaranteed the obligations of SJCC under the coal agreement. The coal agreement contemplates the delivery of coal that would supply substantially all the requirements of SJGS through December 31, 2017.

APS purchases all of Four Corners’ coal requirements from a supplier that was also a subsidiary of BHP and had a long-term lease of coal reserves with the Navajo Nation. That contract was to expire on July 6, 2016 with pricing determined using an escalating base-price. On December 30, 2013, ownership of the mine was transferred to an entity owned by the Navajo Nation and a new coal supply contract for Four Corners, expiring in 2031, was entered into with that entity. The BHP subsidiary is to be retained as the mine manager and operator until July 2016. Coal costs are anticipated to increase approximately 21% for the first full year of the new contract and will further increase over the contract term. PNM anticipates that its share of the increased costs will be recovered through its FPPAC.

In 2013, PNM updated its study of the final reclamation costs for both the surface mines that previously provided coal to SJGS and the current underground mine providing coal and revised its estimates of the final reclamation costs. This estimate reflects that, with the proposed shutdown of SJGS Units 2 and 3 described above, the mine providing coal to SJGS will continue to operate through 2053, the anticipated life of SJGS. The 2013 estimate for decommissioning the Four Corners mine reflects the operation of the mine through 2031, the term of the new coal supply agreement. Based on the 2013 estimates, remaining payments for mine reclamation, in future dollars, are estimated to be $55.1 million for the surface mines at both SJGS and Four Corners and $93.3 million for the underground mine at SJGS as of March 31, 2014. At March 31, 2014 and December 31, 2013, liabilities, in current dollars, of $23.6 million and $23.8 million for surface mine reclamation and $7.9 million and $7.8 million for underground mine reclamation were recorded in other deferred credits.

PNM collects a provision for surface and underground mine reclamation costs in its rates. The NMPRC has capped the amount that can be collected from ratepayers for final reclamation of the surface mines at $100.0 million. Previously, PNM recorded a regulatory asset for the $100.0 million and recovers the amortization of this regulatory asset in rates. If future estimates increase the liability for surface mine reclamation, the excess would be expensed at that time. In conjunction with the proposed shutdown of SJGS Units 2 and 3 to comply with the BART requirements of the CAA discussed under The Clean Air Act - Regional Haze - SJGS above, an updated coal mine reclamation study was requested by the SJGS participants. As discussed under Coal Combustion Byproducts Waste Disposal above, SJGS currently disposes of CCBs from the plant in the surface mine pits adjacent to the plant. The updated coal mine reclamation study indicates reclamation costs have increased, including significant increases due to the proposed shutdown of SJGS Units 2 and 3, although the timing of payments will be delayed. The shutdown of Units

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PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

2 and 3 would reduce the amount of CCBs generated over the remaining life of SJGS, which could result in a significant increase in the amount of fill dirt required to remediate the underground mine area thereby increasing the overall reclamation costs. It has not been decided how costs would be divided among the owners of SJGS. Regulatory determinations made by the NMPRC may also affect the impact on PNM. The reclamation amounts discussed above reflect PNM’s estimates of its share of the revised costs. PNM is currently unable to determine the outcome of these matters or the range of possible impacts.

San Juan Underground Mine Fire Incident

On September 9, 2011, a fire was discovered at the underground mine owned and operated by SJCC that provides coal for SJGS. The federal Mine Safety and Health Administration (“MSHA”) was notified of the incident. On September 12, 2011, SJCC informed PNM that the fire was extinguished. However, MSHA required sealing the incident area and confirmation of a noncombustible environment before allowing re-entry of the sealed area. SJCC regained entry into the sealed area of the mine in early March 2012. At that time, MSHA conducted a root cause analysis inspection of the incident area, but has not yet issued its report. SJCC has completed inspection of the mine equipment and reported no significant damage. SJCC removed the equipment from the impacted mine panel and reassembled it at a new panel face. On May 4, 2012, SJCC received approval from MSHA and resumed longwall mining operations.

The costs of the mine recovery flowed through the cost-reimbursable component of the coal supply agreement. PNM included the portion of such costs allocable to its customers subject to New Mexico regulation in its FPPAC. PNM’s filings with the NMPRC reflected an estimate that this incident increased coal costs and the deferral of cost recovery under the FPPAC by between $17.4 million and $21.6 million. SJCC submitted an insurance claim regarding the costs it incurred due to the mine fire and informed PNM that it settled with its insurance carrier. PNM’s portion of the insurance recovery is estimated to be $18.7 million. PNM has credited its FPPAC balancing account for the amount of its estimated insurance proceeds allocable to PNM’s New Mexico jurisdictional customers. SJCC is refunding the insurance recovery to the owners of SJGS through reductions of the cost of purchases under the coal supply agreement. See Note 12.

Continuous Highwall Mining Royalty Rate

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

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

SJCC Arbitration

The coal supply agreement for SJGS provides that the participants in SJGS have the right to audit the costs billed by SJCC. An independent accounting firm has been engaged to perform audits of the costs billed under the provisions of the contract. The audit for the period from 2006 through 2009 resulted in disagreements between the SJGS participants and SJCC. As provided in the contract, certain issues have been submitted to a panel for binding arbitration. The issues are: 1) whether the SJGS participants owe SJCC unbilled mining costs of $5.2 million or whether SJCC owes the SJGS participants overbilled mining costs of $1.1 million, and 2) whether SJCC billed the SJGS participants $13.9 million as mining costs that SJCC should have considered to be capital costs, which are not billable under the mining contract.  PNM’s share of any amounts resulting from the arbitration would be approximately 46.3%. Of PNM’s share of the costs, approximately 33% of the first issue as well as approximately 25% of the

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PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

second issue would be passed through PNM’s FPPAC and the rest would impact earnings. A hearing before the arbitration panel on the remaining issues is scheduled to be held in May 2014. PNM is unable to predict the outcome of the arbitration hearing.

Four Corners Severance Tax Assessment

On May 23, 2013, the New Mexico Taxation and Revenue Department (“NMTRD”) issued a notice of assessment for coal severance surtax, penalty, and interest totaling approximately $30 million related to coal supplied under the coal supply agreement for Four Corners. PNM’s share of any amounts paid related to this assessment would be approximately 8%, all of which would be passed through PNM’s FPPAC. For procedural reasons, on behalf of the Four Corners co-owners, including PNM, the coal supplier made a partial payment of the assessment and immediately filed a refund claim with respect to that partial payment in August 2013. The NMTRD denied the refund claim. On December 19, 2013, the coal supplier and APS, on its own behalf and as operating agent for Four Corners, filed a complaint in the New Mexico District Court contesting both the validity of the assessment and the refund claim denial. PNM believes the assessment and the refund claim denial are without merit, but cannot predict the outcome of this matter.

PVNGS Liability and Insurance Matters

Public liability for incidents at nuclear power plants is governed by the Price-Anderson Act, which limits the liability of nuclear reactor owners to the amount of insurance available from both private sources and an industry retrospective payment plan. In accordance with the Price-Anderson Act, the PVNGS participants have insurance for public liability exposure for a nuclear incident totaling $13.6 billion per occurrence. Commercial insurance carriers provide $375 million and $13.2 billion is provided through a mandatory industry wide retrospective assessment program. If losses at any nuclear power plant covered by the program exceed the accumulated funds, PNM could be assessed retrospective premium adjustments. Based on PNM’s 10.2% interest in each of the three PVNGS units, PNM’s maximum potential retrospective premium assessment per incident for all three units is $38.9 million, with an annual payment limitation of $5.7 million.

The PVNGS participants maintain “all risk” (including nuclear hazards) insurance for damage to, and decontamination of, property at PVNGS in the aggregate amount of $2.75 billion, a substantial portion of which must first be applied to stabilization and decontamination. These coverages are provided by Nuclear Electric Insurance Limited (“NEIL”). Effective April 1, 2014, a sublimit of $2.25 billion for non-nuclear property damage losses has been enacted to the primary policy offered by NEIL. If NEIL’s losses in any policy year exceed accumulated funds, PNM is subject to retrospective assessments of $4.8 million for each retrospective assessment declared by NEIL’s Board of Directors. The insurance coverages discussed in this and the previous paragraph are subject to policy conditions and exclusions.

Water Supply

Because of New Mexico’s arid climate and periodic drought conditions, there is concern in New Mexico about the use of water, including that used for power generation. PNM has secured groundwater rights in connection with the existing plants at Reeves Station, Delta, Afton, Luna, and Lordsburg. Water availability is not an issue for these plants at this time. However, prolonged drought, ESA activities, and a Federal lawsuit by the State of Texas (suing the State of New Mexico over water allocations) could pose a threat of reduced water availability for these plants.

PNM, APS, and BHP have undertaken activities to secure additional water supplies for SJGS, Four Corners, and related mines to accommodate the possibility of inadequate precipitation in coming years. Since 2004, PNM has entered into agreements for voluntary sharing of the impacts of water shortages with tribes and other water users in the San Juan basin. This agreement has been extended through 2016. In addition, in the case of water shortage, PNM, APS, and BHP have reached agreement with the Jicarilla Apache Nation on a long-term supplemental contract relating to water for SJGS and Four Corners that runs through 2016. Although PNM does not believe that its operations will be materially affected by drought conditions at this time, it cannot forecast the weather or its ramifications, or how policy, regulations, and legislation may impact PNM should water shortages occur in the future.

In April 2010, APS signed an agreement on behalf of the PVNGS participants with five cities to provide cooling water essential to power production at PVNGS for forty years.

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PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

PVNGS Water Supply Litigation

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

San Juan River Adjudication

In 1975, the State of New Mexico filed an action in New Mexico District Court to adjudicate all water rights in the San Juan River Stream System, including water used at Four Corners and SJGS. PNM was made a defendant in the litigation in 1976. In March 2009, President Obama signed legislation confirming a 2005 settlement with the Navajo Nation. Under the terms of the settlement agreement, the Navajo Nation’s water rights would be settled and finally determined by entry by the court of two proposed adjudication decrees.  The court issued an order in August 2013 finding that no evidentiary hearing was warranted in the Navajo Nation proceeding, and on November 1, 2013 issued a Partial Final Judgment and Decree of the Water Rights of the Navajo Nation approving the proposed settlement with the Navajo Nation. Several parties filed a joint motion for a new trial, which was denied by the court. A number of parties subsequently appealed to the New Mexico Court of Appeals. PNM is in the process of entering its appearance in the appellate case. No hearing dates or deadlines have been set at this time.

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

Rights-of-Way Matter

On January 28, 2014, the County Commission of Bernalillo County, New Mexico passed an ordinance requiring utilities to enter into a use agreement and pay a yet to be determined fee as a condition to installing, maintaining, and operating facilities on county rights-of-way. The fee is purported to compensate the county for costs of administering, maintaining, and capital improvements to the rights-of-way. On February 27, 2014, PNM and other utilities filed a Complaint for Declaratory and Injunctive Relief in the United States District Court for the District of New Mexico challenging the validity of the ordinance. If the challenge to the ordinance is unsuccessful, PNM believes any fees paid pursuant to the ordinance would be considered franchise fees and would be recoverable from customers. PNM is unable to predict the outcome of this matter or its impact on PNM’s operations.

Complaint Against Southwestern Public Service Company

In September 2005, PNM filed a complaint under the Federal Power Act against SPS alleging SPS overcharged PNM for deliveries of energy through its fuel cost adjustment clause practices and that rates for sales to PNM were excessive. PNM also intervened in a proceeding brought by other customers raising similar arguments relating to SPS’ fuel cost adjustment clause practices and issues relating to demand cost allocation (the “Golden Spread Proceeding”). In addition, PNM intervened in a proceeding filed by SPS to revise its rates for sales to PNM (“SPS 2006 Rate Proceeding”). In 2008, FERC issued its order in the Golden Spread Proceeding affirming an ALJ decision that SPS violated its fuel cost adjustment clause tariffs, but shortening the refund period applicable to the violation of the fuel cost adjustment clause issues that had been ordered by the ALJ.  FERC also reversed the decision of the ALJ, which had been favorable to PNM, on the demand cost allocation issues. PNM and SPS filed petitions for rehearing and clarification of the scope of the remedies that were ordered and seeking reversal of various rulings in the order. On August 15, 2013, FERC issued separate orders in the Golden Spread Proceeding and in the SPS 2006 Rate Proceeding. The order in the Golden Spread Proceeding determined that PNM was not entitled to refunds for SPS’ fuel cost adjustment clause practices. That order and the order in the SPS 2006 Rate Proceeding decided the demand cost allocation issues using the method

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PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

that PNM had advocated.  PNM, SPS, and other customers of SPS have filed requests for rehearing of these orders and they are pending further action by FERC. PNM cannot predict the final outcome of the case at FERC or the range of possible outcomes.

Navajo Nation Allottee Matters

A putative class action was filed against PNM and other utilities in February 2009 in the United States District Court for the District of New Mexico. Plaintiffs claim to be allottees, members of the Navajo Nation, who pursuant to the Dawes Act of 1887, were allotted ownership in land carved out of the Navajo Nation and allege that defendants, including PNM, are rights-of-way grantees with rights-of-way across the allotted lands and are either in trespass or have paid insufficient fees for the grant of rights-of-way or both.  In March 2010, the court ordered that the entirety of the plaintiffs’ case be dismissed. The court did not grant plaintiffs leave to amend their complaint, finding that they instead must pursue and exhaust their administrative remedies before seeking redress in federal court.  In May 2010, plaintiffs filed a Notice of Appeal with the Bureau of Indian Affairs (“BIA”), which was denied by the BIA Regional Director. In May 2011, plaintiffs appealed the Regional Director’s decision to the DOI, Office of Hearings and Appeals, Interior Board of Indian Appeals. Following briefing on the merits, on August 20, 2013, that board issued a decision upholding the Regional Director’s decision that the allottees had failed to perfect their appeals, and dismissed the allottees’ appeals, without prejudice.  The allottees have not refiled their appeals. Although this matter was dismissed without prejudice, PNM considers the matter concluded. However, PNM continues to monitor this matter in order to preserve its interests regarding any PNM-acquired rights-of-way.

In a separate matter, in September 2012, forty-three landowners claiming to be Navajo allottees filed a notice of appeal with the BIA appealing a March 2011 decision of the BIA Regional Director regarding renewal of a right-of-way for a PNM transmission line. The allottees, many of whom are also allottees in the above matter, generally allege that they were not paid fair market value for the right-of-way, that they were denied the opportunity to make a showing as to their view of fair market value, and thus denied due process. On January 6, 2014, PNM received notice that the BIA, Navajo Region, requested a review of an appraisal report on 58 allotment parcels. After review, the BIA concluded it would continue to rely on the values of the original appraisal. On March 27, 2014, while this matter was stayed, the allottees filed a motion to dismiss their appeal with prejudice.  On April 2, 2014, the allotees’ appeal was dismissed with prejudice concluding this matter.

(12) Regulatory and Rate Matters

The Company is involved in various regulatory matters, some of which contain contingencies that are subject to the same uncertainties as those described in Note 11. Additional information concerning regulatory and rate matters is contained in Note 17 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K.

PNM

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. The NMPRC requires renewable energy portfolios to be “fully diversified.” The current diversity requirements are 30% wind, 20% solar, 5% other, and 1.5% distributed generation, increasing to 3% in 2015, subject to the limitation of the RCT. In December 2013, the NMPRC modified the RCT calculation to establish a two to one REC weighting for renewable energy from the non-wind/non-solar category, such as geothermal resources. On motions for rehearing, the NMPRC reversed its weighting decision in April 2014.

The REA provides for streamlined proceedings for approval of utilities’ renewable energy procurement plans, assures utilities that they recover costs incurred consistent with approved procurement plans, and requires the NMPRC to establish a RCT for the procurement of renewable resources to prevent excessive costs being added to rates. The currently NMPRC approved RCT is set at 3% of customers’ annual electric charges.

PNM filed its 2014 renewable energy procurement plan on July 1, 2013. The plan meets RPS and diversity requirements within the RCT in 2014 and 2015. PNM’s procurements include 50,000 MWh of wind generated RECs in 2014, the construction by December 31, 2014 of 23 MW of PNM-owned solar PV facilities at a cost of $46.7 million, a 20-year PPA for the output of Red Mesa Wind, an existing wind facility having an aggregate capacity of 102 MW, beginning January 1, 2015 at a first year cost

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PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

estimated to be $5.8 million, and the purchase of 120,000 MWh of wind RECs in 2015. The NMPRC approved the plan on December 18, 2013.

PNM is recovering certain renewable procurement costs from customers through a rate rider. See Renewable Energy Riderbelow.

Renewable Energy Rider

The NMPRC has authorized PNM to recover certain renewable procurement costs through a rate rider billed on a per KWh basis. The rider will terminate upon a final order in PNM’s next general rate case unless the NMPRC authorizes PNM to continue it. 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 10.5%, PNM would be required to refund the amount over 10.5% to customers during May through December of the following year. On April 1, 2014, PNM made a filing with the NMPRC demonstrating that it had not exceeded the 10.5% return for 2013. The 2013 approved rider rate was $0.0028371 per KWh through May 28, 2013 when it changed to $0.0030468 per KWh. The rider rate increased to $0.0044391 effective January 1, 2014 and to $0.0045959 per KWh on April 25, 2014. At the currently approved rider rate, PNM would collect an estimated $34.6 million annually.

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. Costs to implement approved programs are recovered through a rate rider. In 2013, this act was amended to set an annual program budget equal to 3% of an electric utility’s annual revenue.

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.

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. In 2010, PNM began implementing a NMPRC rule that authorized electric utilities to collect rate adders to remove disincentives and to provide incentives for energy and demand savings related to energy efficiency and demand response programs. 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 currently approved program costs, this equates to an estimated annual incentive of $1.7 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. Included in the proposed rule is a provision that would limit incentive awards to an amount equal to the product (expressed in dollars) of the utility’s WACC (expressed as a percent) and its approved annual program costs. The NMPRC received comments and a public hearing was held on November 20, 2013.

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PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

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 May 28, 2013, PNM filed the required continuation application and requested that its current FPPAC be modified to increase the reset frequency of the fuel factor from annually to quarterly, to allow PNM to retain 10% of its off-system sales margin, and to apply the same carrying charge rate to both over and under collections in the balancing account. On December 20, 2013, a stipulated agreement was filed to resolve this case. A public hearing on the stipulation was held on February 25, 2014. The Hearing Examiner recommended approval of the settlement in its entirety to the NMPRC. On April 23, 2014, the NMPRC approved the stipulation. The settlement allows PNM to retain 10% of off-system sales margin from July 1, 2013 through December 31, 2016, resolves all costs related to the San Juan Coal mine fire discussed in Note 11, resolves the ratemaking treatment for coal pre-treatment at SJGS until the next rate case, requires PNM to write-off $10.5 million of the under-collected balance in its FPPAC balancing account, and requires PNM to extend the recovery of the remaining under-collected balance over 18 months beginning July 1, 2014. PNM recorded the $10.5 million write-off as a regulatory disallowance in the fourth quarter of 2013.

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. In its most recent IRP, which was filed in July 2011, PNM indicated that it planned to meet its anticipated load growth through a combination of new natural gas-fired generating plants, renewable energy resources, load management, and energy efficiency programs. PNM has initiated the process to prepare its 2014 IRP. Public participation meetings have been held. The 2014 IRP is scheduled to be filed at the NMPRC by June 30, 2014.

Applications for Approvals to Purchase Delta

As discussed in Note 9 of the Notes to Consolidated Financial Statements in the 2013 Annual Report on Form 10-K, PNM has entered in to an agreement to purchase Delta, a 132 MW natural gas peaking unit from which PNM currently acquires energy and capacity under a PPA. The agreement to purchase Delta required approvals by the NMPRC and FERC. On June 26, 2013, the NMPRC granted PNM’s CCN application and approved PNM’s proposed ratemaking treatment. FERC approved the purchase on February 26, 2013. PNM anticipates closing on the purchase in the second quarter of 2014.

Application for Approval of La Luz Generating Station

On May 17, 2013, PNM filed an application with the NMPRC for a CCN to construct, own, and operate a 40 MW gas-fired generating facility near Belen, New Mexico. The application also requested a determination of related ratemaking principles and treatment. The facility was initially expected to cost approximately $63.2 million and go into service in the first quarter of 2016. PNM has entered into a contract for purchase of the turbine to be used for this project and a separate contract for the construction of the facility on a turn-key basis. Both contracts allow PNM to cancel if NMPRC approval is not obtained. On February 20, 2014, a stipulated agreement was filed that would resolve the case. The parties to the stipulation are PNM, the NMPRC staff, and another intervenor. The parties to the stipulation agree that a CCN should be granted and establishes a value of up to $56 million to be included in rate base for the facility. A public hearing was held on April 29, 2014. At the conclusion of the hearing, the Hearing Examiner requested that the parties to the stipulation draft a recommended decision approving the stipulation. PNM is unable to predict the outcome of this matter.

San Juan Generating Station Units 2 and 3 Retirement

As discussed in Note 11, on December 20, 2013, PNM filed an application at the NMPRC to retire SJGS Units 2 and 3 on December 31, 2017. In that application, PNM also seeks approval to recover the net book value of SJGS Units 2 and 3 at the date of retirement, for a CCN to include PNM’s share of PVNGS Unit 3 as a resource to serve New Mexico consumers, authority to install SNCRs on SJGS Units 1 and 4, and a CCN to exchange 78 MW in SJGS Unit 3 for the same amount of capacity in SJGS Unit 4. PNM requested the NMPRC issue its final ruling on the application no later than December 2014. A public hearing on the application has been scheduled to commence on August 19, 2014. Depending upon the terms and conditions agreed to as a result of the negotiations, including PNM’s share of the capacity of SJGS Unit 4, PNM may amend its December 20, 2013 filing with the NMPRC. PNM will also make an application at FERC to seek approval of the restructured SJGS participation agreements. PNM is unable to predict the outcome of these matters.

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PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Formula Transmission Rate Case

On December 31, 2012, PNM filed an application with FERC for authorization to move from charging stated rates for wholesale electric transmission service to a formula rate mechanism pursuant to which rates for wholesale transmission service are calculated annually in accordance with an approved formula. In a settlement of a prior transmission rate case, the parties agreed that no party would oppose the general principle of a formula rate, although the parties may still object to particular aspects of the formula. PNM’s proposed formula includes updating cost of service components, including investment in plant and operating expenses, based on information contained in PNM’s annual financial report filed with FERC, as well as including projected large transmission capital projects to be placed into service in the following year. The projections included are subject to true-up in the following year formula rate. Certain items, including changes to return on equity and depreciation rates, require a separate filing to be made with FERC before being included in the formula rate. As filed, PNM’s request would result in a $3.2 million wholesale electric transmission rate increase, based on PNM’s 2011 data and a 10.81% return on equity (“ROE”), and authority to adjust transmission rates annually based on an approved formula.

On March 1, 2013, FERC issued an order (1) accepting PNM’s revisions to its rates for filing and suspending the proposed revisions to become effective August 2, 2013, subject to refund; (2) directing PNM to submit a compliance filing to establish its ROE using the median, rather than the mid-point, of the ROEs from a proxy group of companies; (3) directing PNM to submit a compliance filing to remove from its rate proposal the acquisition adjustment related to PNM’s 60% ownership of the EIP transmission line, which was acquired in 2003 ; and (4) setting the proceeding for hearing and settlement judge procedures. PNM would be allowed to make a separate filing related to recovery of the EIP acquisition adjustment. On April 1, 2013, PNM made the required compliance filing. In addition, PNM filed for rehearing of FERC’s order regarding the ROE. On June 3, 2013, PNM made additional filings incorporating final 2012 data into the formula rate request. The updated formula rate would result in a $1.3 million rate increase over the rates approved by FERC on January 2, 2013. The new rates will apply to all of PNM’s wholesale electric transmission service customers. The new rates will not apply to PNM’s retail customers. On June 10, 2013, FERC denied PNM’s motion for rehearing regarding FERC’s order requiring PNM to use the median, instead of the midpoint, to calculate its ROE for the formula rate case. On August 2, 2013, the new rates went into effect, subject to refund. On May 1, 2014, PNM updated its formula rate incorporating 2013 data resulting in a $0.5 million rate increase over the current rates. PNM anticipates filing the updated rate request with FERC on June 1, 2014, at which time the new rates will be effective, subject to refund. Settlement negotiations are ongoing concerning issues in this proceeding. PNM is unable to predict the outcome of this proceeding.

City of Gallup, New Mexico Contract

PNM provides both energy and power services to Gallup, PNM’s second largest firm-requirements wholesale customer, under an electric service agreement that was to expire on June 30, 2013. On May 1, 2013, PNM and Gallup agreed to extend the term of the agreement to June 30, 2014 and to increase the demand and energy rates under the agreement. On May 1, 2013, PNM requested FERC approval of the amended agreement to be effective July 1, 2013. On June 21, 2013, FERC approved the amended agreement. Revenue from Gallup will have increased by $3.1 million during the term of the amended agreement.

On September 26, 2013, Gallup issued a request for proposals for long-term power supply. PNM submitted a proposal in November 2013. On March 26, 2014, Gallup notified PNM that the contract for long-term power supply had been awarded to another utility.  PNM’s contract with Gallup will expire on June 29, 2014.  PNM’s 2013 revenues for power sold under the Gallup contract were $11.7 million. 

TNMP

Advanced Meter System Deployment

In July 2011, the PUCT approved a settlement and authorized an AMS deployment plan that permits TNMP to collect $113.3 million in deployment costs through a surcharge over a 12-year period. TNMP began collecting the surcharge on August 11, 2011. Deployment of advanced meters began in September 2011 and is scheduled to be completed over a 5-year period.

In February 2012, the PUCT opened a proceeding to consider the feasibility of an “opt-out” program for retail consumers that wish to decline receipt of an advanced meter. The PUCT has requested comments and convened a public meeting to hear various issues. However, various individuals filed a petition with the PUCT seeking a moratorium on any advanced meter deployment. The PUCT denied the petition and an appeal was filed with the Texas District Court on September 28, 2012.

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PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

On February 21, 2013, the PUCT filed a proposed rule to permit customers to opt-out of the AMS deployment. The PUCT adopted a rule on August 15, 2013 creating a non-standard metering service for retail customers choosing to decline standard metering service via an advanced meter. The cost of providing non-standard metering service will be borne by opt-out customers through an initial fee and ongoing monthly charge. All transmission and distribution utilities in ERCOT are required to initiate proceedings to establish these charges.

On September 30, 2013, TNMP filed an application to set the initial fee and monthly charges to be assessed for non-standard metering service provided to those retail customers who choose to decline the advanced meter necessary for standard metering service. TNMP’s filing seeks recovery of $0.2 million through proposed initial fees ranging from $142.84 to $247.48. An additional $0.5 million in ongoing expenses would be recovered via a proposed monthly charge of $38.99. The April 8, 2014 hearing on this matter has been suspended as the parties attempt to reach a settlement. TNMP cannot predict the outcome of this proceeding although TNMP does not expect it to have a material impact on its financial position, results of operations, or cash flows.

Energy Efficiency

TNMP recovers the costs of its energy efficiency programs through an energy efficiency cost recovery factor that includes projected program costs, under or over collected costs from prior years, case expenses, and performance bonuses (if the programs exceed expectations). On August 28, 2012, the PUCT approved a settlement that permitted TNMP to collect an aggregate of $5.2 million effective January 1, 2013. On October 25, 2013, the PUCT approved a settlement that permits TNMP to collect an aggregate of $5.6 million beginning March 1, 2014. By June 1, 2014, TNMP will file its 2015 energy efficiency cost recovery factor application with the PUCT.

Transmission Cost of Service Rates

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.

On January 31, 2013, TNMP filed an application to update its transmission rates to reflect changes in its invested capital. The requested increase in total rate base is $21.9 million, which will increase revenues $2.9 million annually. The PUCT ALJ approved TNMP’s interim transmission cost of service filing and rates went into effect with bills rendered on March 20, 2013.

On August 1, 2013, TNMP filed an application to further update its transmission rates to reflect changes in its invested capital. The requested increase in total rate base is $18.1 million, which would increase revenues by $2.8 million annually. The PUCT ALJ approved TNMP’s interim transmission cost of service filing and rates went into effect with bills rendered on September 17, 2013.

On January 21, 2014, TNMP filed an application to further update its transmission rates resulting from changes in its invested capital. The requested increase in total rate base is $18.2 million, which would increase revenues by $2.9 million annually. The PUCT ALJ approved TNMP’s interim transmission cost of service filing and rates went into effect with bills rendered on March 13, 2014.

(13) Income Taxes

On January 3, 2013, the American Taxpayer Relief Act of 2012, which extended fifty percent bonus depreciation, was signed into law.  Due to provisions in the act, taxes payable to the State of New Mexico for 2013 were reduced, which resulted in an impairment of New Mexico wind energy production tax credits. In accordance with GAAP, PNMR was required to record this impairment, which after federal income tax benefit, amounted to $1.5 million as additional income tax expense during the three months ended March 31, 2013. This impairment is reflected in PNMR’s Corporate and Other segment.

On April 4, 2013, New Mexico House Bill 641 was signed into law. One of the provisions of the bill was to reduce the New Mexico corporate income tax rate from 7.6% to 5.9%. The rate reduction will be 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 three months ended June 30, 2013. At that time,

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PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

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. The increase in the regulatory liability was $23.9 million. In addition, the portion of the adjustment that is not related to PNM’s regulated activities was recorded as a reduction in deferred tax assets and an increase in income tax expense of $1.2 million. 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. In the three months ended March 31, 2014, PNM’s regulatory liability was reduced by $4.6 million, which increased deferred tax liabilities. Additionally, deferred tax assets not related to PNM’s regulatory activities were reduced by $0.2 million, which increased income tax expense.

In 2013, the future reduction in taxes payable to the State of New Mexico resulting from the rate reduction in House Bill 641 and revisions in estimates of future taxable income resulted in a further impairment of New Mexico wind energy production tax credits. In accordance with GAAP, PNMR was required to record this impairment, which after federal income tax benefit, amounted to $2.4 million as additional income tax expense during the three months ended June 30, 2013.

In 2013, the FASB issued Accounting Standards Update 2013-11, which requires entities to present an unrecognized tax benefit as a reduction to a deferred tax asset for a net operating loss carryforward, a similar tax loss, or a tax credit carryforward if such carryforward could be used to offset the unrecognized tax benefit upon settlement.  The update is required to be applied prospectively for periods beginning after December 15, 2013, and early adoption was permitted.  The Company elected not to adopt the change for 2013, but did adopt it for 2014 as required by the update.  Had the Company applied the update at December 31, 2013, the effect would have been decreases in net operating deferred tax assets of $19.9 million for PNMR, $11.2 million for PNM, and $6.8 million for TNMP, along with the elimination of the corresponding assets and liabilities associated with unrecognized tax benefits. There was no impact to earning from adopting the update.

(14) Related Party Transactions

PNMR, PNM, and TNMP are considered related parties as defined under GAAP. PNMR Services Company provides corporate services to PNMR and its subsidiaries in accordance with shared services agreements. The table below summarizes the nature and amount of related party transactions of PNMR, PNM, and TNMP:

	Three Months Ended
	March 31,
	2014		2013
	(In thousands)
Services billings:
PNMR to PNM	$	21,066	$	22,652
PNMR to TNMP	7,261		7,361
PNM to TNMP	109		108
TNMP to PNMR	—		2
Interest billings:
PNMR to TNMP	96		96
PNMR to PNM	53		1
PNM to PNMR	26		41
Income tax sharing payments:
PNMR to PNM	—		—
PNMR to TNMP	—		—

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

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

MD&A FOR PNMR

EXECUTIVE SUMMARY

Overview and Strategy

PNMR is a holding company with two regulated utilities serving approximately 748,000 residential, commercial, and industrial customers and end-users of electricity in New Mexico and Texas. PNMR’s electric utilities are PNM and TNMP.

Strategic Goals

PNMR is focused on achieving the following strategic goals:

• Earning authorized returns on its regulated businesses

• Maintaining investment grade credit ratings

• Providing a top-quartile total return to investors

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

• Achieving industry-leading safety performance

• Maintaining strong plant performance and system reliability

• Delivering a superior customer experience

• Demonstrating environmental leadership in its business operations

Earning Authorized Returns on Regulated Businesses

PNMR’s success in accomplishing its strategic goals is highly dependent on continued favorable regulatory treatment for its utilities and their strong operating performance. The Company has multiple strategies to achieve favorable regulatory treatment, all of which have as their foundation a focus on the basics: safety, operational excellence, and customer satisfaction, while engaging stakeholders to build productive relationships.

Both PNM and TNMP seek cost recovery for their investments through general rate cases and various rate riders. The PUCT has approved mechanisms that allow TNMP to recover capital invested in transmission and distribution projects without having to file a general rate case, which allows for more timely recovery. The PUCT approved TNMP’s most recent request for additional investments in transmission assets on March 13, 2014. The NMPRC has approved rate riders for renewable energy and energy efficiency that also allow for more timely recovery of investments and improve the ability to earn authorized returns from PNM’s retail customers. Recently, PNM completed rate proceedings for all of its FERC regulated transmission customers and for NEC, its largest wholesale generation services customer, which improved PNM’s returns for providing those services. In addition, PNM currently has a pending case before FERC in which it is requesting an increase in rates charged to transmission customers based on a formula rate mechanism. However, Gallup, PNM’s second largest customer for wholesale generation services, has informed PNM that it will obtain power from another utility at the end of the current contract on June 29, 2014. Additional information about rate filings is provided in Note 17 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K and in Note 12.

Fair and timely rate treatment from regulators is crucial to PNM and TNMP earning their allowed returns, which is critical for PNMR’s ability to achieve its strategic goals. PNMR believes that if the utilities earn their allowed returns, it would be viewed positively by credit rating agencies and would further improve the Company’s ratings, which could lower costs to utility customers.

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Also, earning allowed returns should result in increased earnings for PNMR, which would lead to increased total returns to investors.

PNM’s interest in PVNGS Unit 3 is currently excluded from NMPRC jurisdictional rates. While PVNGS Unit 3’s financial results are not included in the authorized returns on its regulated business, it impacts PNM’s earnings and has been demonstrated to be a valuable asset. Power generated from PNM’s 134 MW interest in PVNGS Unit 3 is currently sold into the wholesale market and any earnings or losses are attributable to shareholders. As part of compliance with the requirements for BART at SJGS discussed below, PNM has requested NMPRC approval to include PVNGS Unit 3 as a jurisdictional resource in the determination of rates charged to customers in New Mexico beginning in 2018.

Maintaining Investment Grade Credit Ratings

PNM is committed to maintaining investment grade credit ratings. The credit ratings for PNMR, PNM, and TNMP were set forth under the heading Liquidity in the MD&A contained in the 2013 Annual Reports on Form 10-K. As discussed under the subheading Liquidity in MD&A - Liquidity and Capital Resources below, S&P raised the corporate credit ratings and senior debt ratings for PNMR, PNM, and TNMP, as well as the preferred stock rating for PNM, on April 5, 2013. S&P retained the outlook as stable for all entities. On June 21, 2013, Moody’s changed the ratings outlook for PNMR, PNM, and TNMP to positive from stable. On January 30, 2014, Moody’s raised the credit ratings for PNMR, PNM and TNMP by one notch, while maintaining the positive outlook. All of the Company’s credit ratings issued by both Moody’s and S&P are now investment grade. On April 30, 2014, S&P changed the outlook for PNMR, PNM, and TNMP to positive from stable.

Providing Top-Quartile Total Returns to Investors

PNMR’s strategic goal to provide top quartile total return to investors over the 2012 to 2016 period is based on five-year ongoing earnings per share growth plus five-year average dividend yield from a group of regulated electric utility companies with similar market capitalization. Top quartile total return currently is equal to an average annual rate of 10 percent to 13 percent.

PNMR’s long-term target is a dividend payout ratio of 50 percent to 60 percent of its ongoing earnings. Ongoing earnings, which is a non-GAAP financial measure, excludes certain non-recurring, infrequent, and other items from earnings determined in accordance with GAAP. The annual common stock dividend was raised by 16 percent in February 2012, 14 percent in February 2013, and 12 percent in December 2013. PNMR expects to provide above-average dividend growth in the near-term and to manage the payout ratio to meet its long-term target. The Board will continue to evaluate the dividend on an annual basis, considering sustainability and growth, capital planning, and industry standards.

Business Focus

In addition to its strategic goals, PNMR’s strategy and decision-making are focused on safely providing reliable, affordable, and environmentally responsible power to create enduring value for customers and communities. To accomplish this, PNMR works closely with customers, stakeholders, legislators, and regulators to ensure that resource plans and infrastructure investments benefit from robust public dialogue and balance the diverse needs of our communities.

Reliable and Affordable Power

PNMR and its utilities are keenly aware of the roles they play in enhancing economic vitality in their New Mexico and Texas service territories. Management believes that maintaining strong and modern electric infrastructure is critical to ensuring reliability and economic growth. When considering expanding or relocating to other communities, businesses consider energy affordability and reliability to be important factors. PNM and TNMP strive to balance service affordability with infrastructure investment to maintain a high level of electric reliability and to deliver a superior customer experience. The utilities also work to ensure that rates reflect actual costs of providing service.

Investing in PNM’s and TNMP’s infrastructure is critical to ensuring reliability and meeting future energy needs. Both utilities have long-established records of providing customers with top-tier electric reliability.

In September 2011, TNMP began its deployment of smart meters in homes and businesses across its Texas service area. Through March 31, 2014, TNMP had completed installation of more than 142,000 smart meters, which is approximately 62% of the anticipated total. TNMP’s deployment is expected to be completed in 2016.

As part of the State of Texas’ long-term initiative to create a smart electric grid, installation of smart meters will ultimately give consumers more data about their energy consumption and help them make more informed decisions. In 2014, TNMP will install a new outage management system that will leverage capabilities of the smart meters to enhance TNMP’s responsiveness

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to outages.

During the 2011 to 2013 period, PNM and TNMP together invested $937.5 million in utility plant, including substations, power plants, nuclear fuel, and transmission and distribution systems. In 2012, PNM announced plans for the 40 MW natural gas-fired La Luz peaking generating station to be located near Belen, New Mexico. PNM filed a request in May 2013 with the NMPRC for approval to construct the La Luz plant, which is expected to begin in 2014, with the facility going into service in 2016. PNM also announced an agreement to purchase Delta, a 132 MW gas-fired peaking facility, which has served PNM jurisdictional needs under a 20-year PPA since 2000. The purchase has been approved by the NMPRC and FERC. PNM anticipates closing on the Delta purchase in the second quarter of 2014.

Environmentally Responsible Power

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

• Developing strategies to meet regional haze rules at the coal-fired SJGS as cost-effectively as possible while providing broad environmental benefits

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

•Increasing energy efficiency participation

Another area of emphasis is the reduction of the amount of fresh water used during electricity generation at PNM’s power plants. The fresh water used per MWh generated has dropped by 21.0% since 2002, primarily due to the growth of renewable energy sources, the expansion of Afton to a combined-cycle plant that has both air and water cooling systems, and the use of gray water for cooling at Luna. In addition to the above areas of focus, the Company is also working to reduce the amount of solid waste going to landfills through increased recycling and reduction of waste. The Company has performed well in this area in the past and has set goals for even further reductions.

Renewable Energy

PNM’s 2013 renewable procurement strategy almost doubled PNM’s existing solar capacity with the addition of 21.5 MW of utility-owned solar capacity. In addition to the solar expansion, the 2013 plan included a 20-year agreement to purchase energy from a geothermal facility built near Lordsburg, New Mexico. The facility began providing power to PNM in January 2014. The current output of the facility is 4 MW and future expansion may result in up to 10 MW of generation capacity. PNM’s 2014 renewable procurement strategy calls for the construction of an additional 23 MW of utility-owned solar capacity, a 20-year PPA for the output of an existing 102 MW wind energy center beginning in 2015, and the purchase of RECs in 2014 and 2015 to meet the RPS.

In addition to PNM’s utility-owned PV solar facilities, PNM also owns the 500 KW PNM Prosperity Energy Storage Project, which uses advanced batteries to store solar power and dispatch the energy either during high-use periods or when solar production is limited. The project features one of the largest combinations of battery storage and PV energy in the nation and involves extensive research and development of smart grid concepts. The facility was the nation’s first solar storage facility fully integrated into a utility’s power grid.

PNM also purchases 204 MW of wind power and power from a customer-owned distributed solar generation program having an installed capacity of 30.5 MW at the end of 2013. These renewable resources are key means for PNM to meet the RPS and related regulations, which require PNM to achieve prescribed levels of energy sales from renewable sources, if that can be accomplished without exceeding the RCT cost limit set by the NMPRC.

PNM makes renewable procurements consistent with the plans approved by the NMPRC. PNM believes its currently planned resources will enable it to comply with the NMPRC’s diversity requirements, as amended in December 2012. PNM will continue to procure renewable resources while balancing the bill impact to customers in order to meet New Mexico’s escalating RPS requirements.

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SJGS

PNM continues its efforts to comply with the EPA regional haze rule in a manner that minimizes the cost impact to customers while still achieving broad environmental benefits. Additional information about BART at SJGS is contained in Note 16 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K and in Note 11.

In August 2011, EPA issued a FIP for regional haze that would require the installation of SCRs on all four units at SJGS by September 2016. Following approval by the majority of the other SJGS owners, PNM, NMED, and EPA agreed, on February 15, 2013, to pursue a revised plan that could provide a new BART path to comply with federal visibility rules at SJGS. The terms of the non-binding agreement would result in 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 from the State of New Mexico. The revised SIP has been approved by the EIB and submitted to EPA for its approval. On April 30, 2014, EPA issued an advance copy of the proposed approval of the revised SIP. The 30-day public comment period will begin upon publication in the Federal Register. Final EPA action is expected by about the end of September 2014.

Contemporaneously with the signing of the non-binding agreement, EPA indicated in writing that if the above plan does not move forward due to circumstances outside of the control of PNM and NMED, EPA will work with the State of New Mexico and PNM to create a reasonable FIP compliance schedule to reflect the time used to develop the new state plan.

On December 20, 2013, PNM made a filing with the NMPRC requesting certain approvals necessary to effectuate the revised SIP. In this filing, PNM requests authorization 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

• Include PNM’s ownership of PVNGS Unit 3 as a resource to serve New Mexico retail customers effective January 1, 2018

• Allow cost recovery for the installation of SNCR equipment and the additional equipment to comply with NAAQS requirements on SJGS Units 1 and 4

• Exchange ownership of 78 MW of PNM’s capacity in SJGS Unit 3 for 78 MW in SJGS Unit 4

PNM requested the NMPRC issue its final ruling on the application no later than December 2014. On February 11, 2014, PNM’s application was determined to be complete. The Hearing Examiner indicated the NMPRC should proceed with the review of PNM’s application and establish a schedule that would allow NMPRC action on the application by the end of 2014. A public hearing on the application is scheduled to begin on August 19, 2014.

The December 20, 2013 filing also identifies a new 177 MW natural gas fired generation source and 40 MW of new utility-scale solar generation to replace a portion of PNM’s share of the reduction in generating capacity due to the retirement of SJGS Units 2 and 3. Specific approvals to acquire these facilities and the treatment of associated costs will be requested in future filings.

In connection with the implementation of the revised plan and the proposed retirement of SJGS Units 2 and 3, some of the SJGS participants have expressed a desire to exit their ownership in the plant. As a result, the SJGS participants are attempting to negotiate a restructuring of the ownership in SJGS, as well as addressing the obligations of the exiting participants for plant decommissioning, mine reclamation, environmental matters, and certain ongoing operating costs, among other items. The SJGS participants have engaged a mediator to assist in facilitating resolution of a number of outstanding matters among the owners. Although negotiations are continuing, no agreements have been reached. Owners of the affected units also may seek approvals of their utility commissions or governing boards. The December 20, 2013 NMPRC filing was based on the status of negotiations among the SJGS owners at that time. Depending upon the terms and conditions agreed to as a result of the negotiations, including PNM’s share of the capacity of SJGS Unit 4, PNM may amend its December 20, 2013 filing with the NMPRC. PNM is unable to predict the outcome of the negotiations.

PNM, as the SJGS operating agent, presented the SNCR project to the participants in Unit 1 and Unit 4 for approval in late October 2013. The project was approved for Unit 1, but the Unit 4 project did not obtain the required percentage of votes for approval. Other capital projects related to Unit 4 were also not approved by the participants. The SJPPA provides that PNM is authorized and obligated to take reasonable and prudent actions necessary for the successful and proper operation of SJGS pending resolution by the participants. PNM must evaluate its responsibilities and obligations as operating agent under the SJPPA regarding the SJGS Unit 4 capital projects that were not approved by the participants and take reasonable and prudent actions as it deems necessary. In March 2014, PNM requested that the owners of Unit 4 approve the expenditure of $1.9 million of costs critical to

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being able to comply with the time frame in the revised SIP with respect to Unit 4 project. The Unit 4 owners did not approve the expenditures. Thereupon, PNM issued a “Prudent Utility Practice” notice that, under the SJPPA, PNM was restarting certain critical activities to keep the Unit 4 project on schedule. PNM cannot predict the outcome of this matter.

This revised BART plan would achieve similar visibility improvements as the installation of SCRs on all four units at SJGS. It has the added advantage of reducing other emissions beyond NOx, including SO₂, particulate matter, CO₂, and mercury, as well as reducing water usage. PNM has begun taking steps to prepare for the potential installation of SNCRs on Units 1 and 4. In May 2013, PNM entered into an SNCR equipment and related services contract with an SNCR technology provider, but has not yet entered into a construction and procurement contract. PNM can provide no assurance that the requirements of this plan will be accomplished at all or within the required timeframes.

In addition to the regional haze rule, SJGS is required to comply with other rules currently being developed or implemented that affect coal-fired generating units. Because of environmental upgrades completed in 2009, SJGS is well positioned to outperform the mercury limit imposed by EPA in the 2011 Mercury and Air Toxics Standards. The major environmental upgrades on each of the four units at SJGS have significantly reduced emissions of NOx, SO₂, particulate matter, and mercury. Since 2006, SJGS has reduced NOx emissions by 41 percent, SO₂ by 60 percent, particulate matter by 69 percent, and mercury by 99 percent.

Energy Efficiency

Energy efficiency also plays a significant role in helping to keep customers' electricity costs low while continuing to meet their energy needs. PNM's and TNMP's energy efficiency and load management portfolios continue to achieve robust results. In 2013, annual energy saved as a result of PNM’s portfolio of energy efficiency programs was approximately 75 GWh. This is equivalent to the annual consumption of approximately 10,200 homes in PNM’s service territory. PNM’s load management and energy efficiency programs also help lower peak demand requirements. TNMP’s energy efficiency programs in 2013 resulted in energy savings totaling an estimated 17.0 GWh. This is equivalent to the annual consumption of approximately 1,650 homes in TNMP’s service territory.

Creating Value for Customers and Communities

The Company strives to deliver a superior customer experience by understanding the dynamic needs of its customers through ongoing market research, identifying and establishing best-in-class services and programs, and proactively communicating and engaging with customers at a regional and community level. In 2013, PNM refocused its efforts to improve the customer experience through an integrated marketing and communications strategy that encompassed brand repositioning and advertising, customer service improvements, and strategic customer and stakeholder engagement. As part of this effort, in February 2014, PNM launched an updated website that provides an increase in self-service options for customers, as well as a mobile platform.

Integrated communication around known satisfaction drivers, including billing and payment options, bill redesign, energy efficiency, and environmental and community stewardship ensured PNM retained traction from prior efforts, as well as gained new ground in critical areas, notably corporate citizenship perceptions. PNM’s perceived value to customers has also improved.

Recognizing the importance of environmental stewardship to customers and other stakeholders, PNM expanded engagement with environmental stakeholders to promote ongoing dialogue and input. Similarly, PNM also proactively communicated with communities about its efforts and plans related to environmental stewardship. Customers took note of PNM’s efforts in this area. A nationally recognized customer satisfaction benchmark revealed gains in awareness of PNM’s efforts to improve environmental impact, as well as customer perceptions around the commitment to preserving the environment now and for future generations. Benchmark data also demonstrates positive movement in the communication component of the customer experience.

Through outreach, collaboration, and various community-oriented programs, PNMR has a demonstrated commitment to build productive relationships with stakeholders, including customers, regulators, legislators, and intervenors.

Building off work that began in 2008, PNM has continued outreach efforts to connect low-income customers with nonprofit community service providers offering support and help with such needs as utility bills, food, clothing, medical programs, services for seniors, and weatherization. In 2013, PNM hosted 22 community events throughout its service territory to assist low-income customers. Furthermore, the PNM Good Neighbor Fund provided $0.3 million of assistance with utility bills to 3,610 families in 2013. In 2013, PNM committed funding of $0.9 million to the PNM Good Neighbor Fund.

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The PNM Resources Foundation helps nonprofits become more energy efficient through Reduce Your Use grants. In 2013, PNMR committed funding of $3.5 million to the PNM Resources Foundation. For 2013, the foundation awarded $0.2 million to support 56 projects in New Mexico to provide shade structure installations, window replacements, and efficient appliance purchases. Since the program’s inception in 2008, Reduce Your Use grants have provided nonprofit agencies in New Mexico with a total of $1.4 million of support. In 2013, in connection with the PNM Resources Foundation’s 30^th anniversary, the foundation awarded thirty $10,000 environmental grants to nonprofit agencies.

PNM continues to expand its environmental stakeholder outreach, piloting small environmental stakeholder dialogue groups on key issues such as renewable energy and energy efficiency planning. PNM also employed proactive stakeholder outreach in two key projects - the development of PNM’s renewable energy procurement plans that involved distributed solar energy developers early in the conversation and the siting of the planned gas-fired peaking generation facility near Belen, New Mexico, which featured in-depth community involvement and education early in the planning stages of the project. In both cases highly favorable outcomes were achieved, and controversial negative media coverage was virtually eliminated.

In Texas, community outreach has focused on supporting employee volunteerism, as well as customer education to address questions about the ongoing smart meter deployment. TNMP also offers energy efficiency programs specific to government buildings and schools and has successfully used the programs to improve customer relationships.

Economic Factors

In the three months ended March 31, 2014, PNM experienced a decrease in weather normalized retail load of 2.9% compared to the same period in 2013.  New Mexico’s economy still lags the nation in post-recession recovery. In the three months ended March 31, 2014, TNMP’s weather normalized retail load increased 8.1% compared to the same period in 2013. In recent years, New Mexico and Texas have fared better than the national average in unemployment although the unemployment rate in New Mexico exceeded the national average in March 2013. However, employment growth is a stronger predictor of load. Texas’ employment growth rates are well above the national rate, while New Mexico’s employment remains relatively flat.

Results of Operations

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

	Three Months Ended March 31,
	2014		2013		Change
	(In millions, except per share amounts)
Net earnings attributable to PNMR	$	12.5	$	10.6	$	1.9
Average diluted common and common equivalent shares	80.4		80.6		(0.2		)
Net earnings attributable to PNMR per diluted share	$	0.16	$	0.13	$	0.03

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

	Three Months Ended
	March 31, 2014
	(In millions)
PNM	$	(3.9	)
TNMP	3.1
Corporate and Other	2.6
Net change	$	1.9

PNMR’s operational results were affected by the following:

• Lower retail load at PNM partially offset by higher retail load in at TNMP

• Rate increases for PNM and TNMP - additional information about these rate increases is provided in Note 17 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K and Note 12

• Milder weather in PNM’s service territory in 2014 than 2013

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• Net unrealized gains and losses on mark-to-market economic hedges for sales and fuel costs not recoverable under PNM’s FPPAC

• Higher prices for sales of power from PVNGS Unit 3

• Increased income tax expense in 2013 due to impairments of state tax credits that did not recur in 2014 (Note 13)

• Other factors impacting results of operation for each segment are discussed under Results of Operations below

Liquidity and Capital Resources

The Company has revolving credit facilities that provide capacities for short-term borrowing and letters of credit of $300.0 million for PNMR and $400.0 million for PNM, both of which expire in October 2018. In addition, PNM has a $50.0 million revolving credit facility, which expires in January 2018, with banks having a significant presence in New Mexico and TNMP has a $75.0 million revolving credit facility, which expires in September 2018. Total availability for PNMR on a consolidated basis was $806.9 million at April 25, 2014. The Company utilizes these credit facilities and cash flows from operations to provide funds for both construction and operational expenditures. PNMR also has intercompany loan agreements with each of its subsidiaries.

The Company projects that its total capital requirements, consisting of construction expenditures and dividends, will total $2,564.5 million for 2014-2018, including amounts expended through March 31, 2014. The construction expenditures include estimated amounts related to environmental upgrades at SJGS to address regional haze and the identified sources of replacement capacity under the revised plan for compliance described in Note 11. The construction expenditures also include additional renewable resources anticipated to be required to meet the RPS, additional peaking resources needed to meet needs outlined in PNM’s current IRP, and environmental upgrades at Four Corners. In addition to internal cash generation, the Company anticipates that it will be necessary to obtain additional long-term financing in the form of debt refinancing, new debt issuances, and/or new equity in order to fund its capital requirements during the 2014-2018 period. The Company currently believes that its internal cash generation, existing credit arrangements, and access to public and private capital markets will provide sufficient resources to meet the Company’s capital requirements.

RESULTS OF OPERATIONS

Segment Information

The following discussion is based on the segment methodology that PNMR’s management uses for making operating decisions and assessing performance of its various business activities. See Note 3 for more information on PNMR’s operating segments.

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

PNM

The following table summarizes the operating results for PNM:

	Three Months Ended March 31,
	2014			2013			Change
	(In millions)
Electric operating revenues	$	262.7		$	257.9		$	4.8
Cost of energy	96.6			91.7			4.9
Margin	166.1			166.2			(0.1		)
Operating expenses	107.7			103.2			4.5
Depreciation and amortization	27.1			25.8			1.3
Operating income	31.3			37.2			(5.9		)
Other income (deductions)	3.8			4.1			(0.3		)
Net interest charges	(19.8		)	(20.0		)	0.2
Segment earnings before income taxes	15.3			21.4			(6.1		)
Income (taxes)	(4.1		)	(6.6		)	2.5
Valencia non-controlling interest	(3.5		)	(3.2		)	(0.3		)
Preferred stock dividend requirements	(0.1		)	(0.1		)	—
Segment earnings	$	7.5		$	11.4		$	(3.9	)

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The following table summarizes the significant changes to electric operating revenues, cost of energy, and margin:

	2013/2014 Change
	Three Months Ended March 31,
	Electric
	Operating			Cost of
	Revenues			Energy			Margin
	(In millions)
Customer usage/load	$	(4.2	)	$	—		$	(4.2	)
Weather	(3.3		)	—			(3.3		)
Economy service	2.7			2.6			0.1
Wholesale rate increases	0.5			—			0.5
Renewable energy rider	4.5			2.2			2.3
Unregulated margin	1.5			(2.1		)	3.6
Net unrealized economic hedges	3.0			0.9			2.1
Other	0.1			1.3			(1.2		)
Net change	$	4.8		$	4.9		$	(0.1	)

The following table shows electric operating revenues by customer class and average number of customers:

	Three Months Ended March 31,
	2014			2013			Change
	(In millions, except customers)
Residential	$	97.6		$	104.3		$	(6.7	)
Commercial	89.6			88.3			1.3
Industrial	15.8			17.3			(1.5		)
Public authority	5.2			5.3			(0.1		)
Economy service	10.6			7.9			2.7
Other retail	3.6			3.4			0.2
Transmission	9.1			8.7			0.4
Firm-requirements wholesale	11.5			11.5			—
Other sales for resale	22.6			17.1			5.5
Mark-to-market activity	(2.9		)	(5.9		)	3.0
	$	262.7		$	257.9		$	4.8
Average retail customers (thousands)	510.4			507.4			3.0

The following table shows GWh sales by customer class:

	Three Months Ended March 31,
	2014	2013	Change
	(Gigawatt hours)
Residential	775.0	851.3	(76.3	)
Commercial	868.0	878.5	(10.5	)
Industrial	240.0	252.6	(12.6	)
Public authority	51.6	55.0	(3.4	)
Economy service	191.4	176.7	14.7
Firm-requirements wholesale	160.9	177.2	(16.3	)
Other sales for resale	583.9	532.8	51.1
	2,870.8	2,924.1	(53.3	)

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For the three months ended March 31, 2014, retail sales were lower compared to 2013 reflecting a continued sluggish economy in New Mexico. In particular, the Albuquerque metropolitan area continues to lag the nation in economic recovery. In spite of the economic pressures, PNM experienced year to date average retail customer growth of 0.6%. Weather negatively impacted revenues and margin $3.3 million during the three months ended March 31, 2014 as heating degree days were 13.8% lower for the three months ended March 31, 2014 compared to the same period in 2013. PNM’s weather normalized retail KWh sales were 2.9% lower for the three months ended March 31, 2014 compared to 2013, which decreased revenues and margin $4.2 million. There is no clear indication regarding the future of New Mexico’s economy, as it still lags the nation in post-recession recovery. Encouraging signs such as increased economic development activity and improved tax environment are contrasted by negative indicators such as a slip in employment growth and an increase in the unemployment rate in the first quarter of 2014. PNM continues to see some customer growth, as well as increasing peak demand levels, while at the same time, usage per customer has decreased. The growth is not yet strong enough to offset the decreased usage, which appears to be the result of economic concerns, as well as energy efficiency measures.

PNM implemented new rates for Gallup, its second largest wholesale customer, in July 2013 under a one-year agreement, which improved revenues and margins $0.5 million for the three months ended March 31, 2014 compared to 2013. PNM responded to Gallup’s request for proposals for long-term power supply.  On March 26, 2014, Gallup notified PNM that the contract for long-term power supply had been awarded to another utility.  PNM’s contract with Gallup will expire on June 29, 2014.  PNM’s 2013 revenues for power sold under the Gallup contract were $11.7 million. See Note 12. 

In August 2012, PNM implemented its renewable energy rider, which recovers renewable energy procurement costs to meet the RPS, including the 22 MW of PNM-owned solar PV facilities completed in 2011. In January 2014, PNM increased the rate charged under the rider to include the 21.5 MW of PNM-owned solar PV facilities completed in 2013. See Note 12. For the three months ended March 31, 2014, this rider increased revenues by $4.5 million and cost of energy, reflecting the purchase of RECs, by $2.2 million. These revenues include a return on investment of $1.3 million for the three months ended March 31, 2014 compared to $0.8 million for the three months ended March 31, 2013. The remaining revenues from this rider recover renewable energy operating, depreciation, and interest expenses.

For the three months ended March 31, 2014, unregulated revenue increased $1.5 million and margin increased $3.6 million. Higher market power prices for PNM’s share of PVNGS Unit 3, increased revenues and margins by $1.5 million for the three months ended March 31, 2014 compared to 2013. In addition, gas imbalance settlements lowered cost of energy $2.1 million for the three months ended March 31, 2014 compared to 2013.

Changes in unrealized mark-to-market gains and losses result from economic hedges for sales and fuel costs not covered under the FPPAC, primarily associated with PVNGS Unit 3. Unrealized losses of $2.8 million for the three months ended March 31, 2014 compared to unrealized losses of $4.9 million for the three months ended March 31, 2013, increased margin by $2.1 million.

PNM provides economy energy services to a major customer. In spite of the increase in KWh sales to this customer for the three months ended March 31, 2014 compared to 2013, there is only a minor impact in margin resulting from providing ancillary services. Other changes in revenues and cost of energy for this customer are a pass through with no impact to margin. Other drivers of changes in revenue, cost of energy, and margin include lower consumption by firm-requirements wholesale customers and off-system sales and purchases not included in PNM’s FPPAC.

For the three months ended March 31, 2014, operating expenses increased $4.5 million compared to 2013. In the three months ended March 31, 2014, higher maintenance expenses for outages at San Juan, Four Corners, and PNM’s natural gas-fired plants of $1.0 million, $0.7 million, and $1.0 million were partially offset by lower maintenance expenses of $0.5 million at PVNGS. Higher Arizona property taxes increased operating expenses of $0.9 million for the three months ended March 31, 2014 compared to 2013. Bad debt expense increased $0.6 million in the three months ended March 31, 2014 compared to 2013. Higher renewable rider expenses of $0.4 million, which is offset in revenue, increased operating expenses for the three months ended March 31, 2014 compared to 2013. In addition, higher pension and retiree medical expense of $0.2 million increased operating expenses for the three months ended March 31, 2014 compared to 2013.

Depreciation and amortization expense increased $1.3 million in the three months ended March 31, 2014 compared to 2013 due to additions to utility plant in service, including 21.5 MW of PNM-owned solar PV facilities. Depreciation on the PNM-owned solar PV facilities is recovered through the renewable energy rider discussed above.

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Other income (deductions) decreased $0.3 million for the three months ended March 31, 2014 compared to 2013. Higher income from investments held by the NDT of $0.8 million were offset by retirements of PVNGS Unit 3 plant in service of $0.7 million and lower interest income on PVNGS lessor notes of $0.5 million due to lower outstanding balances.

For the three months ended March 31, 2014, interest expense decreased $0.2 million compared to 2013, primarily due to lower short-term borrowings expense partially offset by interest expense on new long-term borrowings under the $175.0 million PNM 2014 Term Loan Agreement. See Note 9.

TNMP

The following table summarizes the operating results for TNMP:

	Three Months Ended March 31,
	2014			2013			Change
	(In millions)
Electric operating revenues	$	66.2		$	59.8		$	6.4
Cost of energy	16.0			13.0			3.0
Margin	50.2			46.7			3.4
Operating expenses	21.1			22.0			(0.9		)
Depreciation and amortization	11.8			11.7			0.1
Operating income	17.3			13.1			4.2
Other income (deductions)	0.2			0.2			—
Net interest charges	(6.6		)	(7.2		)	0.6
Segment earnings before income taxes	10.9			6.0			4.9
Income (taxes)	(4.1		)	(2.3		)	(1.8		)
Segment earnings	$	6.8		$	3.7		$	3.1

The following table summarizes the significant changes to total electric operating revenues, cost of energy, and margin:

	2013/2014 Change
	Three Months Ended March 31,
	Electric
	Operating			Cost of
	Revenues			Energy		Margin
	(In millions)
Rate increases	$	1.5		$	—	$	1.5
Demand based customers	0.7			—		0.7
Customer usage/load	0.5			—		0.5
Customer growth	0.3			—		0.3
Weather	0.5			—		0.5
Recovery of third-party transmission costs	3.0			3.0		—
AMS surcharge	0.9			—		0.9
CTC surcharge	0.4			—		0.4
Other	(1.4		)	—		(1.4		)
Net change	$	6.4		$	3.0	$	3.4

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The following table shows total electric operating revenues by retail tariff consumer class, including intersegment revenues, and average number of consumers:

	Three Months Ended March 31,
	2014		2013		Change
	(In millions, except consumers)
Residential	$	26.8	$	22.9	$	3.9
Commercial	23.2		20.9		2.3
Industrial	3.5		3.0		0.5
Other	12.7		13.0		(0.3		)
	$	66.2	$	59.8	$	6.4
Average consumers (thousands) (1)	236.7		234.1		2.6

⁽¹⁾  TNMP provides transmission and distribution services to REPs that provide electric service to consumers in TNMP’s service territories. The number of consumers above represents the customers of these REPs. Under TECA, consumers in Texas have the ability to choose any REP to provide energy.

The following table shows GWh sales by retail tariff consumer class:

	Three Months Ended March 31,
	2014	2013	Change
	(Gigawatt hours)
Residential	642.1	561.4	80.7
Commercial	540.1	478.3	61.8
Industrial	648.1	552.5	95.6
Other	23.5	21.5	2.0
	1,853.8	1,613.7	240.1

For the three months ended March 31, 2014, revenues and margin increased by $1.5 million compared to 2013 due to transmission rate increases in March 2013, September 2013, and March 2014. See Note 12. TNMP experienced customer growth of 1.1%, increasing revenues and margin by $0.3 million for the three months ended March 31, 2014 compared to 2013. Higher weather normalized usage per customer increased revenues and margin by $0.5 million for the three months ended March 31, 2014 compared to 2013. TNMP’s weather normalized retail KWh sales increased 8.1% for the three months ended March 31, 2014 compared to 2013. Colder temperatures in the three months ended March 31, 2014 compared to 2013, resulted in increased revenues and margin of $0.5 million. For the three months ended March 31, 2014 compared to 2013, heating degree days were 30.1% higher, which was partially offset by cooling degree days being 36.8% lower.

Demand based revenues and margin for the three months ended March 31, 2014 increased by $0.7 million compared to 2013. This primarily results from TNMP, under a PUCT approved tariff, lowering the power factor billing threshold from 700 KW to 300 KW.

Differences between revenues and costs charged by third party transmission providers are deferred and recovered through a transmission cost recovery factor resulting in no impact on margin. Higher transmission cost of energy resulting from rate increases from other transmission service providers within ERCOT increased cost of energy $3.0 million for the three months ended March 31, 2014 compared to 2013. These increases in cost of energy resulted in TNMP rate increases for the recovery of third party transmission costs increasing revenue $3.0 million for the three months ended March 31, 2014 compared to 2013.

The AMS surcharge increased revenues and margin by $0.9 million for the three months ended March 31, 2014 compared to 2013, which amounts are offset by increases in operating expenses and depreciation. The CTC surcharge increased revenues and margin by $0.4 million for the three months ended March 31, 2014 compared to 2013, which amounts are also offset by increases depreciation and amortization expense. Other revenues, which include recovery of the Hurricane Ike, rate case expenses, and energy efficiency programs, were lower for the three months ended March 31, 2014 compared to 2013. These lower revenues were offset by decreases in operating expenses and depreciation and amortization. The Hurricane Ike surcharge was terminated in November of 2013 due to full recovery of costs associated with this hurricane.

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Operating expenses decreased $0.9 million for the three months ended March 31, 2014 compared to 2013. Lower employee healthcare claims of $0.5 million and lower property and casualty claims of $0.1 million decreased operating expense for the three months ended March 31, 2014 compared to 2013. Lower vegetation management of $0.2 million and lower labor costs of $0.2 million decreased operating expenses in the three months ended March 31, 2014 compared to 2013. In addition, lower energy efficiency program costs of $0.2 million decreased operating expense in the three months ended 2014, which is offset in revenue under TNMP’s energy efficiency cost recovery factor. These decreases were offset by an increase of $0.3 million for operating expenses associated with the installation of additional meters under the AMS deployment, which is recovered through the AMS surcharge.

Depreciation and amortization increased $0.1 million for the three months ended March 31, 2014 compared to 2013. Depreciation expense associated with the AMS deployment, which is recovered through the AMS surcharge, increased $0.5 million for the three months ended March 31, 2014 compared to 2013. Depreciation expense associated with the CTC, which is recovered through the CTC surcharge, increased $0.4 million for the three months ended March 31, 2014 compared to 2013. In addition, an increase in utility plant in service increased depreciation by $0.4 million for the three months ended March 31, 2014 compared to 2013. These increases are offset by lower amortization of the Hurricane Ike costs of $1.1 million for the three months ended March 31, 2014 compared to 2013.

Interest expense decreased $0.6 million for the three months ended March 31, 2014 compared to 2013. The decrease primarily results from the April 2013 exchange of $93.2 million of TNMP’s 9.5% First Mortgage Bonds for an equal amount of a new series of 6.95% First Mortgage Bonds.

Corporate and Other

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

	Three Months Ended March 31,
	2014			2013			Change
	(In millions)
Total revenues	$	—		$	—		$	—
Cost of energy	—			—			—
Margin	—			—			—
Operating expenses	(3.2		)	(3.7		)	0.5
Depreciation and amortization	3.0			3.3			(0.3		)
Operating income	0.2			0.4			(0.2		)
Other income (deductions)	(0.7		)	(1.8		)	1.1
Net interest charges	(3.1		)	(4.1		)	1.0
Segment earnings (loss) before income taxes	(3.6		)	(5.4		)	1.8
Income (taxes) benefit	1.7			0.9			0.8
Segment earnings (loss)	$	(1.9	)	$	(4.5	)	$	2.6

Operating expenses for Corporate and Other are net of amounts allocated to PNM and TNMP under shared service agreements. Changes in depreciation and amortization are offset in operating expenses as a result of allocation of these costs to other business segments. The change in operating expense is the result of lower depreciation and amortization for the three months ended March 31, 2014 compared to 2013 related to certain items of computer software that were fully depreciated in 2013 and changes in the allocation of certain items to PNM and TNMP.

The decrease in other income (deductions) during the three months ended March 31, 2014 compared to 2013 is due to losses related to corporate investments in 2013 that did not recur in 2014. Net interest charges decreased primarily due to lower interest charges resulting from the 2013 repurchase of $23.8 million principal amount of PNMR’s 9.25% Senior Unsecured Notes, Series A, due 2015. The remaining decrease in net interest charges is the result of lower borrowings and lower interest rates on short-term borrowings.

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During the three months ended March 31, 2013, income (taxes) benefit for Corporate and Other included the impairment of New Mexico wind energy production tax credits of $1.5 million, after federal income tax benefits. No such impairment was incurred in 2014. See Note 13.

LIQUIDITY AND CAPITAL RESOURCES

Statements of Cash Flows

The changes in PNMR’s cash flows for the three months ended March 31, 2014 compared to March 31, 2013 are summarized as follows:

	Three Months Ended March 31,
	2014			2013			Change
	(In millions)
Net cash flows from:
Operating activities	$	76.4		$	(1.4	)	$	77.8
Investing activities	(74.4		)	(62.2		)	(12.2		)
Financing activities	22.6			59.7			(37.1		)
Net change in cash and cash equivalents	$	24.6		$	(3.9	)	$	28.5

The increase in PNMR’s cash flow from operating activities relate to $60.7 million lower contributions to the PNM and TNMP pension and other postretirement benefit plans in 2014 than in 2013. In addition, refunds of $15.2 million made to customers related to the settlement of PNM’s transmission rate in 2013 did not recur in 2014. Higher retail load at TNMP and other changes in assets and liabilities resulting from normal operations increased operating cash flows. These increases were partially offset by lower retail load at PNM.

The changes in PNMR’s cash flows from investing activities relate primarily to an increase of $10.3 million in utility plant additions in the three months ended March 31, 2014 compared to 2013. Utility plant additions at PNM were $7.2 million higher in the three months ended March 31, 2014 compared to 2013, including increases in transmission and distribution additions of $19.9 million, renewable energy additions of $0.4 million, and higher nuclear fuel purchases of $1.5 million. These increases were offset by lower generation additions of $14.6 million. TNMP utility plant additions increased $2.8 million in the three months ended March 31, 2014 compared to 2013, including increases in transmission and distribution additions of $2.4 million and AMS additions of $0.2 million. Corporate plant additions increased $0.3 million in 2014, primarily related to computer hardware and software.

The changes in PNMR’s cash flows from financing activities are primarily due to $33.8 million lower cash inflows from borrowings during the three months ended March 31, 2014 compared to the same period in 2013. Proceeds from long-term borrowings of $175.0 million under the PNM 2014 Term Loan Agreement were used to repay the existing $75.0 million PNM Term Loan Agreement and reduce short-term debt.

Financing Activities

See Note 6 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K and Note 9 for additional information concerning the Company’s financing activities. PNM must obtain NMPRC approval for any financing transaction having a maturity of more than 18 months. In addition, PNM files its annual short-term financing plan with the NMPRC. The Company’s ability to access the credit and capital markets at a reasonable cost is largely dependent upon its:

• Ability to earn a fair return on equity

• Results of operations

• Ability to obtain required regulatory approvals

• Conditions in the financial markets

• Credit ratings

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On March 5, 2014, PNM entered into the $175.0 million PNM 2014 Term Loan Agreement and used a portion of the funds borrowed there under to repay all amounts outstanding under the existing $75.0 million PNM Term Loan Agreement. The funds were also used to repay other short-term amounts outstanding. There were no prepayment penalties paid in connection with the termination of the PNM Term Loan Agreement. The PNM 2014 Term Loan Agreement includes customary covenants and conditions. The PNM 2014 Term Loan Agreement bears interest at a variable rate, which was 1.11% at March 31, 2014, and must be repaid on or before September 4, 2015. At March 31, 2014, the weighted average interest rate was 1.01% for borrowings outstanding under the twelve-month PNMR Term Loan Agreement, which matures in December 2014.

The PNM 2014 Term Loan Agreement, as well as the PNMR Term Loan Agreement, each contain one financial covenant, which requires the maintenance of debt-to-capital ratios of less than or equal to 65%.  These ratios for PNMR and PNM include the present value of payments under the PVNGS and EIP leases as debt.

Capital Requirements

Total capital requirements consist of construction expenditures and cash dividend requirements for PNMR common stock and PNM preferred stock. Key activities in PNMR’s current construction program include:

• Upgrading generation resources, including expenditures for compliance with environmental requirements and for renewable energy resources

• Expanding the electric transmission and distribution systems

• Purchasing nuclear fuel

Projected capital requirements, including amounts expended through March 31, 2014, are:

	2014		2015-2018		Total
	(In millions)
Construction expenditures	$	509.0	$	1,758.2	$	2,267.2
Dividends on PNMR common stock	58.9		235.8		294.7
Dividends on PNM preferred stock	0.5		2.1		2.6
Total capital requirements	$	568.4	$	1,996.1	$	2,564.5

The construction expenditure estimates are under continuing review and subject to ongoing adjustment, as well as to Board review and approval. The construction expenditures above include estimated amounts of $80.0 million related to environmental upgrades at SJGS to address regional haze and $276.3 million related to the identified sources of replacement capacity under the revised plan for compliance described in Note 11. The above construction expenditures also include additional renewable resources anticipated to be required to meet the RPS, additional peaking resources to meet needs outlined in PNM’s current IRP, environmental upgrades at Four Corners of $80.3 million, the purchase of the leased portion of the EIP and the assets underlying three of the PVNGS Unit 2 leases at the expiration of those leases, and the anticipated purchase of Delta. Expenditures for the SJGS and Four Corners environmental upgrades are estimated to be $10.0 million in 2014. See Note 11 and Commitments and Contractual Obligations below. The ability of PNMR to pay dividends on its common stock is dependent upon the ability of PNM and TNMP to be able to pay dividends to PNMR. Note 5 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K describes regulatory and contractual restrictions on the payment of dividends by PNM and TNMP.

During the three months ended March 31, 2014, PNMR met its capital requirements and construction expenditures through cash generated from operations, as well as its liquidity arrangements and the PNM 2014 Term Loan Agreement.

In addition to the capital requirements for construction expenditures and dividends, the Company has long-term debt that must be paid or refinanced at maturity. Note 6 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K contains information about the maturities of long-term debt. The Company has from time to time refinanced or repurchased portions of its outstanding debt before scheduled maturity. Depending on market conditions, the Company may refinance other debt issuances, make additional debt repurchases, or enter into other liquidity arrangements in the future.

Liquidity

PNMR’s liquidity arrangements include the PNMR Revolving Credit Facility and the PNM Revolving Credit Facility that both expire in October 2018 and the TNMP Revolving Credit Facility that expires in September 2018. The PNMR Revolving

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Credit Facility has a financing capacity of $300.0 million, the PNM Revolving Credit Facility has a financing capacity of $400.0 million, and the TNMP Revolving Credit Facility has a financing capacity of $75.0 million. On January 8, 2014, PNM entered into the $50.0 million PNM New Mexico Credit Facility, which expires on January 8, 2018. The Company believes the terms and conditions of its facilities are consistent with those of other investment grade revolving credit facilities in the utility industry.  Each of the credit facilities contains one financial covenant that requires the maintenance of debt-to-capital ratios of less than or equal to 65%.  For PNMR and PNM, these ratios reflect the present value of payments under the PVNGS and EIP leases as debt.

The revolving credit facilities and the PNM New Mexico Credit Facility provide short-term borrowing capacity. The revolving credit facilities also allow letters of credit to be issued. Letters of credit reduce the available capacity under the facilities. The Company utilizes these credit facilities and cash flows from operations to provide funds for both construction and operational expenditures. The Company’s business is seasonal with more revenues and cash flows from operations being generated in the summer months. In general, the Company relies on the credit facilities to be the initial funding source for construction expenditures. Accordingly, borrowings under the facilities may increase over time. Depending on market and other conditions, the Company will periodically sell long-term debt and use the proceeds to reduce the borrowings under the credit facilities. Borrowings under the PNMR Revolving Credit Facility ranged from zero to $21.1 million during the three months ended March 31, 2014 and from $21.5 million to $54.2 million during the three months ended March 31, 2013. Borrowings under the PNM Revolving Credit Facility ranged from zero to $82.0 million during the three months ended March 31, 2014 and from $9.8 million to $130.8 million during the three months ended March 31, 2013. Borrowings under the PNM New Mexico Credit Facility during the three months ended March 31, 2014 ranged from zero to $25.0 million. TNMP had no borrowings under the TNMP Revolving Credit Facility during the three months ended March 31, 2014 and borrowings ranged from zero to $25.0 million during the three months ended March 31, 2013.

The Company currently believes that its capital requirements can be met through internal cash generation, existing or new credit arrangements, and access to public and private capital markets. To cover the difference in the amounts and timing of internal cash generation and cash requirements, the Company intends to use short-term borrowings under its current and future liquidity arrangements. However, if difficult market conditions experienced during the recent recession return, the Company may not be able to access the capital markets or renew credit facilities when they expire. Should that occur, the Company would seek to improve cash flows by reducing capital expenditures and exploring other available alternatives. Also, PNM may consider seeking authorization for the issuance of first mortgage bonds to improve access to the capital markets.

In addition to its internal cash generation, the Company anticipates that it will be necessary to obtain additional long-term financing to fund its capital requirements during the 2014-2018 period. This could include debt refinancing, new debt issuances, and/or new equity.

The credit ratings for PNMR, PNM, and TNMP were set forth under the heading Liquidity in the MD&A contained in the 2013 Annual Reports on Form 10-K. On January 30, 2014, Moody’s raised the senior unsecured rating for PNMR, the senior unsecured and issuer ratings for PNM, and the senior secured and issuer ratings for TNMP. Moody’s continued to maintain the ratings outlook for PNMR, PNM, and TNMP as positive. On April 30, 2014, S&P changed the outlook for PNMR, PNM, and TNMP to positive from stable. As of April 25, 2014, ratings on the Company’s securities were as follows:

	PNMR	PNM	TNMP
S&P
Senior secured debt	*	*	A-
Senior unsecured debt	BBB-	BBB	*
Preferred stock	*	BB+	*
Moody’s
Senior secured debt	*	*	A2
Senior unsecured debt	Baa3	Baa2	*
Preferred stock	*	Ba2	*

* Not applicable

Investors are cautioned that a security rating is not a recommendation to buy, sell, or hold securities, that it is subject to revision or withdrawal at any time by the assigning rating organization, and that each rating should be evaluated independently of any other rating.

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A summary of liquidity arrangements, which do not include the PNMR Term Loan Agreement or the PNM 2014 Term Loan Agreement, as of April 25, 2014 is as follows:

	PNMR Separate		PNM Separate		TNMP Separate		PNMR Consolidated
	(In millions)
Financing capacity:
Revolving credit facility	$	300.0	$	400.0	$	75.0	$	775.0
PNM New Mexico Credit Facility	—		50.0		—		50.0
Total financing capacity	$	300.0	$	450.0	$	75.0	$	825.0
Amounts outstanding as of April 25, 2014:
Revolving credit facility	$	—	$	—	$	6.0	$	6.0
PNM New Mexico Credit Facility	—		—		—		—
Letters of credit	8.6		3.2		0.3		12.1
Total short–term debt and letters of credit	8.6		3.2		6.3		18.1
Remaining availability as of April 25, 2014	$	291.4	$	446.8	$	68.7	$	806.9
Invested cash as of April 25, 2014	$	2.0	$	9.3	$	—	$	11.3

The above table excludes intercompany debt. As of April 25, 2014, TNMP had $41.2 million in borrowings from PNMR under their intercompany loan agreement. The remaining availability under the revolving credit facilities at any point in time varies based on a number of factors, including the timing of collections of accounts receivables and payments for construction and operating expenditures.

PNMR can offer new shares of common stock through the PNM Resources Direct Plan under a SEC shelf registration statement that expires in August 2015. PNM has a shelf registration statement for up to $440.0 million of senior unsecured notes that will expire in May 2014.

Off-Balance Sheet Arrangements

PNMR’s off-balance sheet arrangements include PNM’s operating lease obligations for PVNGS Units 1 and 2, the EIP transmission line, and Delta. These arrangements help ensure PNM the availability of lower-cost generation needed to serve customers. See MD&A - Off-Balance Sheet Arrangements and Notes 7 and 9 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K. See Note 5 and Note 6 for additional information concerning the PVNGS Leases and Delta.

Commitments and Contractual Obligations

PNMR, PNM, and TNMP have contractual obligations for long-term debt, operating leases, construction expenditures, purchase obligations, and certain other long-term obligations. See MD&A - Commitments and Contractual Obligations in the 2013 Annual Reports on Form 10-K.

Contingent Provisions of Certain Obligations

As discussed in the 2013 Annual Reports on Form 10-K,PNMR, PNM, and TNMP have a number of debt obligations and other contractual commitments that contain contingent provisions. Some of these, if triggered, could affect the liquidity of the Company. In the unlikely event that the contingent requirements were to be triggered, PNMR, PNM, or TNMP could be required to provide security, immediately pay outstanding obligations, or be prevented from drawing on unused capacity under certain credit agreements. The contingent provisions also include contractual increases in the interest rate charged on certain of the Company’s short-term debt obligations in the event of a downgrade in credit ratings. The Company believes its financing arrangements are sufficient to meet the requirements of the contingent provisions. No conditions have occurred that would result in any of the above contingent provisions being implemented.

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Capital Structure

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

	March 31, 2014		December 31, 2013
PNMR
PNMR common equity	47.3	%	48.8	%
Preferred stock of subsidiary	0.3	%	0.3	%
Long-term debt	52.4	%	50.9	%
Total capitalization	100.0	%	100.0	%
PNM
PNM common equity	46.5	%	48.2	%
Preferred stock	0.4	%	0.4	%
Long-term debt	53.1	%	51.4	%
Total capitalization	100.0	%	100.0	%
TNMP
Common equity	60.3	%	59.9	%
Long-term debt	39.7	%	40.1	%
Total capitalization	100.0	%	100.0	%

OTHER ISSUES FACING THE COMPANY

Climate Change Issues

Background

According to EPA, gases that trap heat in the atmosphere are called greenhouse gases. The four primary greenhouse gases are CO₂, methane, nitrous oxide, and fluorinated gases, including chlorofluorocarbons such as Freon. In 2013, GHG associated with PNM’s interests in its generating plants were approximately 7.0 million metric tons of CO₂, which comprises the vast majority of PNM’s GHG.  By comparison, the total GHG in the United States in 2012, the latest year for which EPA has published this data, were approximately 6.5 billion metric tons, of which approximately 5.4 billion metric tons were CO₂. 

PNM has several programs underway to reduce or offset GHG from its resource portfolio, thereby reducing its exposure to climate change regulation. See Note 12. In 2011, PNM completed construction of 22 MW of utility-scale solar generation located at five sites on PNM’s system throughout New Mexico. In 2013, PNM expanded its renewable energy portfolio by constructing 21.5 MW of utility-scale solar generation. On December 18, 2013, the NMPRC approved PNM’s 2014 renewable energy procurement plan that includes construction of an additional 23 MW of utility-scale solar generation. This additional generation is anticipated to be online by the end of 2014. Since 2003 PNM has purchased the entire output of New Mexico Wind, which has an aggregate capacity of 204 MW, and will purchase the full output of Red Mesa Wind, which has an aggregate capacity of 102 MW, beginning in January 2015. PNM has signed a 20-year PPA for the output of Lightning Dock Geothermal, which began providing power to PNM in January 2014. The current output of the facility is 4 MW and future expansion may result in up to 10 MW of generation capacity. Additionally, PNM has a customer distributed solar generation program that represented 31 MW at the end of 2013 and is expected to grow to over 36 MW by the end of 2014. Once fully subscribed, the distributed solar programs will reduce PNM’s production from fossil-fueled electricity generation by 117 GWh per year. PNM offers its customers a comprehensive portfolio of energy efficiency and load management programs, with a 2013 budget of over $17 million, that PNM estimates saved approximately 76 GWh of electricity in 2013. Over the next 20 years, PNM projects the expanded energy efficiency and load management programs will provide the equivalent of approximately 13,565 GWh of electricity, which will avoid at least 6.8 million metric tons of CO₂ based upon projected emissions from PNM’s system-wide resources. These estimates are subject to change because of the high uncertainty of many of the underlying variables, including changes in demand for electricity, and complex interrelationships between those variables.

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Management periodically updates the Board on implementation of the corporate environmental policy and the Company’s environmental management systems, promotion of energy efficiency, and use of renewable resources.  The Board is also advised of the Company’s practices and procedures to assess the sustainability impacts of operations on the environment.  The Board considers associated issues around climate change, the Company’s GHG exposures, and financial consequences that might result from potential federal and/or state regulation of GHG.

As of December 31, 2013, approximately 74.7% of PNM’s generating capacity, including resources owned, leased, and under PPAs, all of which is located within the United States, consisted of coal or gas-fired generation that produces GHG. Based on current forecasts, the Company does not expect its output of GHG from existing sources to increase significantly in the near-term. Many factors affect the amount of GHG emitted. For example, if new natural gas-fired generation resources are added to meet increased load as anticipated in PNM’s current IRP, GHG would be incrementally increased. In addition, plant performance could impact the amount of GHG emitted. If PVNGS experienced prolonged outages, PNM might be required to utilize other power supply resources such as gas-fired generation, which could increase GHG. As described in Note 11, on February 15, 2013, PNM, NMED, and EPA agreed to pursue a strategy to address the regional haze requirements of the CAA at the coal-fired SJGS, which would include the shutdown of SJGS Units 2 and 3. The shutdown of Units 2 and 3 would result in a reduction of GHG of approximately 50 percent at SJGS. That agreement also contemplates that gas-fired generation would be built to partially replace the retired capacity. Although replacement power strategies have not been finalized, the reduction in GHG from the retirement of the coal-fired generation would be far greater than the increase in GHG from replacement with gas-fired generation. On September 5, 2013, the EIB unanimously approved a revised SIP submitted by NMED that encompassed the February 15, 2013 agreement and the revised SIP was submitted to EPA for approval on October 18, 2013. On April 30, 2014, EPA issued an advance copy of the proposed approval of the revised SIP. Final EPA action on the revised SIP is expected by about the end of September 2014.

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

Given the geographic location of its facilities and customers, PNM generally has not been exposed to the extreme weather events and other physical impacts commonly attributed to climate change, with the exception of periodic drought conditions. PNM’s service areas also experience high winds, forest fires, and severe thunderstorms periodically. Climate changes are generally not expected to have material consequences in the near-term. Drought conditions in northwestern New Mexico could impact the availability of water for cooling coal-fired generating plants. Water shortage sharing agreements have been in place since 2004, although no shortage has been declared due to sufficient precipitation in the San Juan River basin. PNM also has a supplemental water contract in place with the Jicarilla Apache Nation to help address any water shortages from primary sources. The contract expires on December 31, 2016.  TNMP has operations in the Gulf Coast area of Texas, which experiences periodic hurricanes and drought conditions. In addition to potentially causing physical damage to TNMP-owned facilities, which disrupt the ability to transmit and/or distribute energy, hurricanes can temporarily reduce customers’ usage and demand for energy.

EPA Regulation

In April 2007, the United States Supreme Court held that EPA has the authority to regulate GHG under the CAA.  This decision heightened the importance of this issue for the energy industry.  In December 2009, EPA released its endangerment finding stating that the atmospheric concentrations of six key greenhouse gases (CO₂, methane, nitrous oxides, hydrofluorocarbons, perfluorocarbons, and sulfur hexafluoride) endanger the public health and welfare of current and future generations. In May 2010, EPA released the final PSD and Title V Greenhouse Gas Tailoring Rule (the “Tailoring Rule”) to address GHG from stationary sources under the CAA permitting programs. The purpose of the rule is to “tailor” the applicability of two programs, PSD and Title V operating permit programs, to avoid impacting millions of small GHG emitters. The rule focuses on the largest sources of GHG, including fossil-fueled electric generating units. This program currently covers new construction projects that emit GHG of at least 100,000 tons per year (even if PSD is not triggered for other pollutants). In addition, modifications at existing facilities that increase GHG by at least 75,000 tons per year will be subject to PSD permitting requirements, even if they do not significantly increase emissions of any other pollutant. PNM’s fossil-fueled generating plants are potentially subject to the Tailoring Rule because of the magnitude of GHG and other emissions. PNM’s existing plants other than Four Corners do not have any currently planned projects that would trigger PSD permitting for GHG. Four Corners may be subject to PSD review as a result of the SCR

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installation planned for Regional Haze compliance. Any newly constructed fossil-fired power plant would likely be subject to the Tailoring Rule.

On June 26, 2012, the D.C. Circuit rejected challenges to EPA’s 2009 GHG endangerment finding, GHG standards for light-duty vehicles, PSD Interpretive Memorandum (EPA’s so-called GHG “Timing Rule”), and the Tailoring Rule. The Court found that EPA’s endangerment finding and its light-duty vehicle rule “are neither arbitrary nor capricious,” that “EPA’s interpretation of the governing CAA provisions is unambiguously correct,” and that “no petitioner has standing to challenge the Timing and Tailoring Rules.” On October 15, 2013, the United States Supreme Court granted a petition for a Writ of Certiorari regarding the permitting of stationary sources that emit GHG. The Supreme Court limited the question that it will be reviewing to: “Whether EPA permissibly determined that its regulation of greenhouse gas emissions from new motor vehicles triggered permitting requirements under the Clean Air Act for stationary sources that emit greenhouse gases.” Specifically, the case deals with whether EPA’s determination that regulation of GHG from motor vehicles required EPA to regulate stationary sources under the PSD and Title V permitting programs. The petitioners argued that EPA’s determination that it was required to regulate GHG under the PSD and Title V Programs was unlawful as it violates Congressional intent.

On March 27, 2012, EPA issued its proposed carbon pollution standards, under Section 111(b) of the CAA, for GHG from new fossil-fueled EGU. The proposed NSPS set a limit of 1,000 lb of CO₂/MWh and would cover newly constructed fossil-fueled EGUs larger than 25 MW. The proposed limit was based on the performance of natural gas combined cycle technology. Therefore, coal-fired power plants would only be able to comply with the standard by using carbon capture and sequestration technology. The proposed rule included an exemption for new simple cycle EGUs. EPA accepted comment on the proposed rule through June 25, 2012, during which EPA received over 2.5 million comments. As a result of the comments, EPA reproposed the EGU NSPS as discussed below.

On June 25, 2013, President Obama announced the President’s Climate Action Plan which outlines how his administration plans to cut GHG in the United States, prepare the country for the impacts of climate change, and lead international efforts to combat and prepare for global warming. The plan proposes actions that would lead to the reduction of GHG by 17% below 2005 levels by 2020. The President also issued a Presidential Memorandum to EPA to continue development of the GHG NSPS regulations for electric generators. The Presidential Memorandum establishes a timeline for the reproposal and issuance of a GHG NSPS for new sources and a timeline for the proposal and final rule for developing carbon pollution standards, regulations, or guidelines for GHG reductions from existing sources under Section 111(d) of the CAA. EPA met the President’s timeline for the reproposal of the GHG NSPS for new sources (under Section 111(b) of the CAA) by releasing the draft rule on September 20, 2013. In accordance with the Presidential Memorandum, EPA will issue a final rule in “a timely fashion thereafter.” EPA is also directed to issue the proposed GHG NSPS for modified and existing EGUs by June 1, 2014 and issue the final rule by June 1, 2015. Each state then must submit a SIP that addresses how the state will comply with the new regulation no later than June 30, 2016.

The Presidential Memorandum further directs EPA to allow the use of “market-based instruments” and “other regulatory flexibilities” to ensure standards will allow for continued reliance on a range of energy sources and technologies and that they are developed and implemented in a manner that provides for reliable and affordable energy and to undertake the rulemaking through direct engagement with states, “as they will play a central role in establishing and implementing standards for existing power plants,” and with utility leaders, labor leaders, non-governmental organizations, tribal officials and other stakeholders.

EPA’s reproposed GHG NSPS for new sources published on September 20, 2013 apply only to new fossil-fired EGUs. The reproposed standard would revise requirements for new fossil-fired utility boilers, integrated gasification combined cycle units, combined and simple cycle turbines, and new sources meeting certain other criteria. New fossil fuel-fired utility boilers including coal-fired and integrated gasification combined cycle units would be required to meet an emissions limit of 1,100 pounds of CO₂ per MWh on a 12-operating month rolling average basis or an alternative limit of 1,000 to 1,050 pounds of CO₂ per MWh based on an 84-operating month average. New coal-fired facilities would only be able to meet the standard by using partial carbon capture and sequestration technology. New combined or simple cycle gas turbines would be subject to an emission limit of either 1,000 or 1,100 pounds of CO₂ per MWh based on whether the rated capacity of the unit is above or below 850 million BTUs per hour. The reproposed GHG NSPS removed the blanket exemption for simple-cycle turbines and instead provided an exemption for units that sell to the transmission grid less than one-third of their potential electric output over a three-year rolling average.

EPA regulation of GHG from large stationary sources will impact PNM’s fossil-fueled EGUs. Impacts could involve investments in efficiency improvements and/or control technologies at the fossil-fueled EGUs. In setting existing source standards, EPA has historically used technology-based performance standards on emission rates. The only end-of-pipe emission control technology for coal and gas fired power plants available for GHG reduction is carbon capture and sequestration, which is not yet

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a commercially demonstrated technology. There are limited efficiency enhancement measures that may be available to a subset of the existing EGUs; however, such measures would provide only marginal GHG improvements. It is also possible EPA may allow states to consider a broader range of emission reduction measures, such as fuel switching, end use energy efficiency, or renewable energy deployment. Additional GHG control technologies for existing EGUs may become viable in the future. The costs of such improvements or technologies could impact the economic viability of some plants.

The ultimate impact of EPA’s regulation of GHG to PNM is unknown because the regulatory requirements, including BACT implications and NSPS requirements, are in draft form or are still developing. PNM estimates that implementation of the revised SIP for BART at SJGS, which requires the installation of SNCRs on Units 1 and 4 by the later of January 2016 or 15 months after EPA approval of a revised SIP and the retirement of SJGS Units 2 and 3 by the end of 2017, will allow PNM on a system-wide basis to meet or exceed the President’s GHG reduction goal of 17% below 2005 levels by 2020. The reduction in CO₂ emissions that will result from implementation of the revised SIP may allow PNM to meet future GHG regulations; however, until such regulations are finalized, PNM is uncertain of the requirements for compliance.

Federal Legislation

Prospects for enactment of legislation imposing a new or enhanced regulatory program to address climate change in Congress are unlikely in 2014, although there is growing interest among some policymakers in addressing climate change and there may be legislation in the future.  Instead, EPA is the primary venue for GHG regulation in the near future, especially for coal-fired units. PNM has assessed, and continues to assess, the impacts of potential climate change legislation or regulation on its business.  This assessment is preliminary and future changes arising out of the legislative or regulatory process could impact the assessment significantly.  PNM’s assessment includes assumptions regarding the specific GHG limits, the timing of implementation of these limits, the possibility of a cap and trade program including the associated costs and the availability of offsets, the development of technologies for renewable energy and to reduce emissions, and provisions for cost containment. Moreover, the assessment assumes various market reactions such as the price of coal and gas and regional plant economics.  These assumptions, at best, are preliminary and speculative. However, based upon these assumptions, the enactment of climate change legislation could, among other things, result in significant compliance costs, including large capital expenditures by PNM, and could jeopardize the economic viability of certain generating facilities. See Note 11.  In turn, these consequences could lead to increased costs to customers and affect results of operations, cash flows, and financial condition if the incurred costs are not fully recovered through regulated rates. Higher rates could also contribute to reduced usage of electricity.  PNM’s assessment process is ongoing, but too preliminary and speculative at this time for the meaningful prediction of financial impact.

State and Regional Activity

Pursuant to New Mexico law, each utility must submit an IRP to the NMPRC every three years to evaluate renewable energy, energy efficiency, load management, distributed generation, and conventional supply-side resources on a consistent and comparable basis.  The IRP is required to take into consideration risk and uncertainty of fuel supply, price volatility, and costs of anticipated environmental regulations when evaluating resource options to meet supply needs of the utility’s customers.  The NMPRC requires that New Mexico utilities factor a standardized cost of carbon emissions into their IRPs using prices ranging between $8 and $40 per metric ton of CO₂ emitted and escalating these costs by 2.5% per year.  Under the NMPRC order, each utility must analyze these standardized prices as projected operating costs.  Reflecting the developing nature of this issue, the NMPRC order states that these prices may be changed in the future to account for additional information or changed circumstances.  However, PNM is required to use these prices for purposes of its IRP, and the prices may not reflect the costs that it ultimately will incur.  PNM’s IRP filed with the NMPRC on July 18, 2011 showed that while consideration of the NMPRC required carbon emissions costs did not significantly change the resource decisions regarding future facilities over the next 20 years, it did slightly impact the projected in-service dates of some of the identified resources.  Largely because future resource options are low-GHG emitting resources much higher GHG costs than assumed in the NMPRC analysis are necessary to impact future resource decisions. The primary consequence of the standardized cost of carbon emissions was an increase to generation portfolio costs.

In recent years, New Mexico adopted regulations, which have since been repealed, that would directly limit GHG from larger sources, including EGUs, through a regional GHG cap and trade program and that would cap GHG from larger sources such as EGUs. Although these rules have been repealed, PNM cannot rule out future state legislative or regulatory initiatives to regulate GHG.

On August 2, 2012, thirty-three New Mexico organizations representing public health, business, environmental, consumers, Native American, and other interested parties filed a petition for rulemaking with the NMPRC. The petition asked the NMPRC to issue a NOPR regarding the implementation of an Optional Clean Energy Standard for electric utilities located in New Mexico.

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The proposed standard would have utilities that elect to participate reduce their CO₂ emissions by 3% per year. Utilities that opt into the program would be assured recovery of their reasonable compliance costs. On October 4, 2012, the NMPRC held a workshop to discuss the proposed standard and whether it has authority to proceed with the NOPR. On August 23, 2013, the petitioners amended the August 2, 2012 petition and requested that the NMPRC issue a NOPR to implement a “Carbon Risk Reduction Rule” for electric utilities in New Mexico. The proposed rule would require affected utilities to demonstrate a 3% per year CO₂ emission reduction from a three-year average baseline period between 2005 and 2012. The proposed rule would use a credit system that provides credits for electricity production based on how much less than one metric ton of CO₂ per MWh the utility emits. Credits would be retired such that 3% per year reductions are achieved from the baseline year until 2035 unless a participating utility elects to terminate the program at the end of 2023. Credits would not expire and could be banked. An advisory committee of interested stakeholders would monitor the program. In addition, utilities would be allowed to satisfy their obligations by funding NMPRC approved energy efficiency programs. There has been no further action on this matter at the NMPRC.

International Accords

The Company monitors international treaties and accords such as the Kyoto Protocol and the EU Emissions Trading System to determine potential impacts to their business activities.  The Company does not anticipate any direct impact near-term from international accords.

Transmission Issues

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

On November 24, 2009, FERC issued Order 729 approving two Modeling, Data, and Analysis Reliability Standards (“Reliability Standards”) submitted by NERC - MOD-001-1 (Available Transmission System Capability) and MOD-029-1 (Rated System Path Methodology). Both MOD-001-1 and MOD-029-1 require a consistent approach, provided for in the Reliability Standards, to measuring the total transmission capability (“TTC”) of a transmission path. The TTC level established using the two Reliability Standards could result in a reduction in the available transmission capacity currently used by PNM to deliver generation resources necessary for its jurisdictional load and for fulfilling its obligations to third-party users of the PNM transmission system.

During the first quarter of 2011, at the request of PNM and other southwestern utilities, NERC advised all transmission owners and transmission service providers that the implementation of portions of the MOD-029 methodology for “Flow Limited” paths has been delayed until such time as a modification to the standard can be developed that will mitigate the technical concerns identified by the transmission owners and transmission service providers. PNM and other western utilities filed a Standards Action Request with NERC in the second quarter of 2012.

NERC initiated an informal development process to address directives in Order No. 729 to modify certain aspects of the MOD standards, including MOD-001 and MOD-029. The modifications to this standard would retire MOD-029 and require each transmission operator to determine and develop methodology for TTC values for MOD-001.

A final ballot for MOD-001-2 concluded on December 20, 2013 and received sufficient affirmative votes for approval. On February 10, 2014, NERC filed with FERC a petition for approval of MOD-001-2 and retirement of reliability standards MOD-001-1a, MOD-004-1, MOD-008-1, MOD-028-2, MOD-029-1a, and MOD-030-2. The MOD-001-2 standard will become effective on the first day of the calendar quarter that is 18 months after the date the standard is approved by FERC. The retirement and changes to these MOD standards will remove the risk of reduced TTC for PNM and other southwestern utilities.

In July 2011, FERC issued Order 1000 adopting new requirements for transmission planning, cost allocation, and development.  Order 1000 calls for significant changes to the transmission process of WestConnect, an organization of utility companies providing transmission of electricity in the western region that includes PNM.  On October 11, 2012, PNM and other WestConnect participants filed modified versions of Attachment K to their transmission tariffs to meet Order 1000 regional compliance requirements. Thirteen intervention motions were filed, with several objecting to and/or protesting various provisions

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of the filings submitted by the WestConnect participants. On December 17, 2012, the WestConnect participants filed responses to the issues raised by the intervenors. On March 22, 2013, FERC issued its order regarding PNM’s and six other WestConnect FERC jurisdictional utilities compliance filings. FERC partially accepted many aspects of the filings including the governance structure that gives the transmission owners a veto authority over the regional plan and cost allocations. A major change directed by FERC is the requirement that the cost allocations be binding on identified beneficiaries and that a process be created that will result in a qualified developer being selected. PNM and the other WestConnect FERC jurisdictional entities submitted compliance filings on September 20, 2013 to address and comply with the March 22, 2013 FERC order. On July 11, 2013, the WestConnect participants submitted an additional compliance filing to address the planning and cost allocation between WestConnect and other regions.

Financial Reform Legislation

The Dodd-Frank Wall Street Reform and Consumer Protection Act (“Dodd-Frank Reform Act”), enacted in July 2010, includes provisions that will require certain over-the-counter derivatives, or swaps, to be centrally cleared and executed through an exchange or other approved trading facility. It also includes provisions related to swap transaction reporting and recordkeeping and may impose margin requirements on swaps that are not centrally cleared. The United States Commodity Futures Trading Commission (“CFTC”) has published final rules defining several key terms related to the act and has set compliance dates for various types of market participants. The Dodd-Frank Reform Act provides exemptions from certain requirements, including an exception to the mandatory clearing and swap facility execution requirements for commercial end-users that use swaps to hedge or mitigate commercial risk.  PNM expects to qualify for this exception. PNM also expects to be able to comply with its requirements under the Dodd-Frank Reform Act and related rules within the time frames required by the CFTC. However, as a result of the Dodd-Frank Reform Act and related rules, PNM’s swap activities could be subject to increased costs, including from higher margin requirements. In addition, implementation of, and compliance with, the swaps provisions of the Dodd-Frank Reform Act and related rules by PNM’s swap counterparties could result in increased costs. At this time, PNM cannot predict the ultimate impact the Dodd-Frank Reform Act may have on PNM’s financial condition, results of operations, cash flows, or liquidity.

Other Matters

On March 25, 2013, a petition was filed by IBEW Local 66 with the National Labor Relations Board seeking to certify a union at TNMP for utility workers. On April 12, 2013, a second petition was filed by IBEW Local 66 with the National Labor Relations Board seeking to certify a union at TNMP for meter technicians, who were not included in the original petition. Approximately 200 employees were covered by the petitions. Elections to determine whether the IBEW would represent the employees were held in May 2013.  The employees voted to unionize through both petitions and contract negotiations have begun. Subsequently, on June 25, 2013, a third petition was filed by IBEW Local 66 with the National Labor Relations Board seeking to include a group of three relay technicians, who were not included in the original petition. In August 2013, the relay technicians voted to unionize and contract negotiations have begun. As of December 31, 2013, TNMP had 192 employees represented by IBEW Local 66. The parties are still in negotiations on a collective bargaining agreement.

See Notes 11 and 12 herein and Notes 16 and 17 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K for a discussion of commitments and contingencies and rate and regulatory matters.

CRITICAL ACCOUNTING POLICIES AND ESTIMATES

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

As of March 31, 2014, there have been no significant changes with regard to the critical accounting policies disclosed in PNMR’s, PNM’s, and TNMP’s 2013 Annual Reports on Forms 10-K. The policies disclosed included unbilled revenues, regulatory accounting, impairments, decommissioning and reclamation costs, derivatives, pension and other postretirement benefits, accounting for contingencies, income taxes, and market risk.

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MD&A FOR PNM

RESULTS OF OPERATIONS

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

MD&A FOR TNMP

RESULTS OF OPERATIONS

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

DISCLOSURE REGARDING FORWARD LOOKING STATEMENTS

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

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

• The ability of PNM and TNMP to recover costs and earn allowed returns in regulated jurisdictions, including recovery of the net book value of SJGS Units 2 and 3 at the date of their proposed early retirement as contemplated in the revised SIP to comply with the regional haze provisions of the CAA

• The ability of the Company to successfully forecast and manage its operating and capital expenditures

• State and federal regulation or legislation relating to environmental matters, including the approval of the revised SIP for SJGS’s compliance with the CAA, the resultant costs of compliance, and other impacts on the operations and economic viability of PNM’s generating plants

• The impacts on the electricity usage of the Company’s customers due to performance of state, regional, and national economies and mandatory energy efficiency measures, weather, seasonality, and other changes in supply and demand

• State and federal regulatory, legislative, and judicial decisions and actions on ratemaking, tax, and other matters

• Uncertainty surrounding the status of PNM’s participation in jointly-owned generation projects resulting from the scheduled expiration of the operational agreements for SJGS and Four Corners, as well as the fuel supply agreement for SJGS, including potential restructuring and approval issues at SJGS and Four Corners necessary for operational and environmental compliance matters

• Uncertainty regarding the requirements and related costs of decommissioning power plants and coal mines supplying certain power plants, as well as the ability to recover decommissioning costs from customers

• The performance of generating units, transmission systems, and distribution systems, which could be negatively affected by operational issues, extreme weather conditions, terrorism, and cybersecurity breaches

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

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

• The risks associated with completion of generation, transmission, distribution, and other projects

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

• The risk that reliability standards regarding available transmission capacity and other FERC rulemakings may negatively impact the operation of PNM’s transmission system

• The Company’s ability to access the financial markets, including disruptions in the credit markets, actions by ratings agencies, and fluctuations in interest rates

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

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• The impacts of decreases in the values of marketable equity securities maintained to provide for decommissioning, reclamation, pension benefits, and other post employment benefits

• Commodity and counterparty credit risk transactions and the effectiveness of risk management

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

• Changes in applicable accounting principles

Any material changes to risk factors occurring after the filing of PNMR’s, PNM’s, and TNMP’s 2013 Annual Reports on Form 10-K are disclosed in Item 1A, Risk Factors, in Part II of this Form 10-Q.

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

SECURITIES ACT DISCLAIMER

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

WEBSITES

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

Our Internet addresses are:

• PNMR: www.pnmresources.com

• PNM: www.pnm.com

• TNMP: www.tnmp.com

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

Also available on the Company’s website at www.pnmresources.com/investors/governance.cfm and in print upon request from any shareholder are our:

• Corporate Governance Principles

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

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

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

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

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

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

• Approving the types of derivatives entered into for hedging

• Reviewing and approving hedging risk activities

• Establishing policies regarding counterparty exposure and limits

• Authorizing and delegating transaction limits

• Reviewing and approving controls and procedures for derivative activities

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

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

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

To the extent an open position exists, fluctuating commodity prices, interest rates, equity prices, and economic conditions can impact financial results and financial position, either favorably or unfavorably. As a result, the Company cannot predict with

certainty the impact that its risk management decisions may have on its businesses, operating results, or financial position.

Commodity Risk

Information concerning accounting for derivatives and the risks associated with commodity contracts is set forth in Note 7, including a summary of the fair values of mark-to-market energy related derivative contracts included in the Condensed Consolidated Balance Sheets. During the three months ended March 31, 2014 and the year ended December 31, 2013, PNMR and PNM had no commodity derivative instruments designated as cash flow hedging instruments.

Commodity contracts, other than those that do not meet the definition of a derivative under GAAP, and those derivatives designated as normal purchases and normal sales, are recorded at fair value on the Condensed Consolidated Balance Sheets. The following table details the changes in PNMR’s net asset or liability balance sheet position for mark-to-market energy transactions.

	Three Months Ended
	March 31,
	2014			2013
Economic Hedges	(In thousands)
Sources of fair value gain (loss):
Net fair value at beginning of period	$	3,273		$	1,204
Amount realized on contracts delivered during period	1,201			(1,055		)
Changes in fair value	(3,962		)	(3,847		)
Net mark-to-market change recorded in earnings	(2,761		)	(4,902		)
Net change recorded as regulatory assets and liabilities	(388		)	(105		)
Net fair value at end of period	$	124		$	(3,803	)

The following table provides the maturity of PNMR's net assets (liabilities), giving an indication of when these mark-to-market amounts will settle and generate (use) cash.

Fair Value of Mark-to-Market Instruments at March 31, 2014

	Settlement Dates
	2014			2015		2016
	(In thousands)
Economic hedges
Prices actively quoted	$	—		$	—	$	—
Prices provided by other external sources	(1,853		)	2,337		(360		)
Prices based on models and other valuations	—			—		—
Total	$	(1,853	)	$	2,337	$	(360	)

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PNM measures the market risk of its long-term contracts and wholesale activities using a Monte Carlo VaR simulation model to report the possible loss in value from price movements. VaR is not a measure of the potential accounting mark-to-market loss. The quantitative risk information is limited by the parameters established in creating the model. The Monte Carlo VaR methodology employs the following critical parameters: historical volatility estimates, market values of all contractual commitments, a three-day holding period, seasonally adjusted and cross-commodity correlation estimates, and a 95% confidence level. The instruments being evaluated may trigger a potential loss in excess of calculated amounts if changes in commodity prices exceed the confidence level of the model used.

PNM measures VaR for the positions in its wholesale portfolio (not covered by the FPPAC). For the three months ended March 31, 2014, the high, low, and average VaR amounts were $0.9 million, $0.6 million, and $0.7 million. For the year ended December 31, 2013, the high, low, and average VaR amounts were $1.4 million, $0.6 million, and $0.9 million. At March 31, 2014 and December 31, 2013, the VaR amounts for the PNM wholesale portfolio were $0.7 million and $0.6 million.

The VaR limits, which were not exceeded during the three months ended March 31, 2014 or the year ended December 31, 2013, represent an estimate of the potential gains or losses that could be recognized on the Company’s portfolios, subject to market risk, given current volatility in the market, and are not necessarily indicative of actual results that may occur, since actual future gains and losses will differ from those estimated. Actual gains and losses may differ due to actual fluctuations in market prices, operating exposures, and the timing thereof, as well as changes to the underlying portfolios during the year.

Credit Risk

The Company is exposed to credit risk from its retail and wholesale customers, as well as the counterparties to derivative instruments. The Company conducts counterparty risk analysis across business segments and uses a credit management process to assess the financial conditions of counterparties. The following table provides information related to PNMR’s credit exposure by the credit worthiness (credit rating) and concentration of credit risk for counterparties to derivative transactions. All credit exposures at March 31, 2014 will mature in less than two years.

Schedule of Credit Risk Exposure

March 31, 2014

Rating(1)	Credit Risk Exposure(2)		Number of Counter-parties >10%	Net Exposure of Counter-parties >10%
	(Dollars in thousands)
External ratings:
Investment grade	$	9,815	1	$	8,426
Non-investment grade	—		—	—
Internal ratings:
Investment grade	905		—	—
Non-investment grade	345		—	—
Total	$	11,065		$	8,426

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

⁽²⁾  The Credit Risk Exposure is the gross credit exposure, including long-term contracts (other than firm-requirements wholesale customers), forward sales, and short-term sales. The exposure captures the amounts from receivables/payables for realized transactions, delivered and unbilled revenues, and mark-to-market gains/losses. Gross exposures can be offset according to legally enforceable netting arrangements but are not reduced by posted credit collateral. At March 31, 2014, PNMR held $0.1 million of cash collateral to offset its credit exposure.

Net credit risk for the Company’s largest counterparty as of March 31, 2014 was $8.4 million.

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The PVNGS lessor notes are not exposed to credit risk, since the notes are repaid as PNM makes payments on the underlying leases. Other investments have no significant counterparty credit risk.

Interest Rate Risk

The majority of the Company’s long-term debt is fixed-rate debt and does not expose earnings to a major risk of loss due to adverse changes in market interest rates. However, the fair value of PNMR’s consolidated long-term debt instruments would increase by 2.1%, or $43.1 million, if interest rates were to decline by 50 basis points from their levels at March 31, 2014. In general, an increase in fair value would impact earnings and cash flows to the extent not recoverable in rates if all or a portion of debt instruments were acquired in the open market prior to their maturity. As described in Note 6 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K, TNMP has long-term debt of $50.0 million that bears interest at a variable rate. However, TNMP has also entered into a hedging arrangement that effectively results in this debt bearing interest at a fixed rate, thereby eliminating interest rate risk. At April 25, 2014, PNMR, PNM, and TNMP had zero, zero, and $6.0 million of short term debt outstanding under their revolving credit facilities, which allow for a maximum aggregate borrowing capacity of $300.0 million for PNMR, $400.0 million for PNM, and $75.0 million for TNMP. PNM had no borrowings under its $50.0 million PNM New Mexico Credit Facility at April 25, 2014. The revolving credit facilities, the PNM New Mexico Credit Facility, the $175.0 million PNM 2014 Term Loan Agreement, and the $100.0 million PNMR Term Loan Agreement bear interest at variable rates, which averaged 1.15% for the TNMP Revolving Credit Facility, 1.01% for the PNMR Term Loan Agreement, and 1.10% for the PNM 2014 Term Loan Agreement on April 25, 2014, and the Company is exposed to interest rate risk to the extent of future increases in variable interest rates.

The investments held by PNM in trusts for decommissioning and reclamation had an estimated fair value of $230.3 million at March 31, 2014, of which 40.5% were fixed-rate debt securities that subject PNM to risk of loss of fair value with movements in market interest rates. If interest rates were to increase by 50 basis points from their levels at March 31, 2014, the decrease in the fair value of the fixed-rate securities would be 3.3%, or $3.1 million.

PNM does not directly recover or return through rates any losses or gains on the securities, including equity investments discussed below, in the trusts for decommissioning and reclamation. However, the overall performance of these trusts does enter into the periodic determinations of expense and funding levels, which are factored into the rate making process to the extent applicable to regulated operations. PNM is at risk for shortfalls in funding of obligations due to investment losses, including those from the equity market risks discussed below to the extent not ultimately recovered through rates charged to customers.

Equity Market Risk

The investments held by PNM in trusts for decommissioning and reclamation include certain equity securities at March 31, 2014. These equity securities expose PNM to losses in fair value should the market values of the underlying securities decline. Equity securities comprised 57.7% of the securities held by various trusts as of March 31, 2014. A hypothetical 10% decrease in equity prices would reduce the fair values of these funds by $13.3 million.

ITEM 4. CONTROLS AND PROCEDURES

Evaluation of disclosure controls and procedures

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

Changes in internal controls

There have been no changes in each of PNMR’s, PNM’s, and TNMP’s internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934) during the quarter ended March 31, 2014 that have materially affected, or are reasonably likely to materially affect, each of PNMR’s, PNM’s, and TNMP’s internal control over financial reporting.

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PART II – OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

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

Note 11

• The Clean Air Act - Regional Haze - SJGS

• The Clean Air Act - Regional Haze - Four Corners

• The Clean Air Act - Four Corners BART FIP Challenge

• The Clean Air Act - Regional Haze Challenges

• The Clean Air Act - Citizen Suit Under the Clean Air Act

• The Clean Air Act - Four Corners Clean Air Act Lawsuit

• WEG v. OSM NEPA Lawsuit

• Navajo Nation Environmental Issues

• Santa Fe Generating Station

• Continuous Highwall Mining Royalty Rate

• SJCC Arbitration

• Four Corners Severance Tax Assessment

• PVNGS Water Supply Litigation

• San Juan River Adjudication

• Rights-of-Way Matter

• Complaint Against Southwestern Public Service Company

• Navajo Nation Allottee Matters

Note 12

• PNM - FPPAC Continuation Application

• PNM - Applications for Approvals to Purchase Delta

• PNM - Application for Approval of La Luz Generating Station

• PNM - San Juan Generating Station Units 2 and 3 Retirement

• PNM - Formula Transmission Rate Case

• TNMP - Advanced Meter System Deployment

• TNMP - Transmission Cost of Service Rates

See also Climate Change Issues under Other Issues Facing the Company in MD&A. The third paragraph under State and Regional Activity is incorporated in this item by reference.

ITEM 1A. RISK FACTORS

As of the date of this report, there have been no material changes with regard to the Risk Factors disclosed in PNMR’s, PNM’s, and TNMP’s Annual Reports on Form 10-K for the year ended December 31, 2013.

ITEM 5. OTHER INFORMATION

Amendment to PVNGS Participation Agreement

PNM, along with APS, SCE, Salt River Project Agricultural Improvement and Power District, El Paso Electric Company, Southern California Public Power Authority, and Department of Water and Power of the City of Los Angeles, are parties to a certain agreement entitled Arizona Nuclear Power Project Participation Agreement, dated as of August 23, 1973, as amended by fifteen amendments (as so amended, the “Participation Agreement”). The Arizona Nuclear Power Project is also known as PVNGS.

The Participation Agreement was further amended by Amendment Number 16, which was signed by the last of the parties on April 28, 2014. The purpose of Amendment Number 16 is to extend the expiration date of the Participation Agreement to align with the license extensions granted by the NRC on April 21, 2011 for each of the three units at PVNGS. The latest expiration date

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of the original operating licenses had been November 25, 2027, which was extended by the NRC to November 25, 2047.  Also, in accordance with Amendment Number 16, the term of the Participation Agreement would be automatically extended in the event of future extensions of the NRC operating licenses.

Leases of Interests in PVNGS Unit 2

See Note 6 for a discussion of PNM’s PVNGS Unit 2 leases. On May 1, 2014, PNM and PNMR Development, a wholly owned subsidiary of PNMR, entered into a letter agreement (the “Cypress Letter Agreement”) with Cypress Verde LLC and Cypress Second PV Partnership (together, the “Cypress Entities”). The Cypress Entities are the respective lessors under two (the “Cypress Leases”) of the three Unit 2 leases for which notices were given on January 13, 2014 that PNM would exercise its fair market value purchase option. Consistent with the Cypress Leases and such notices, the Cypress Letter Agreement specifies the fair market value of the 32.76 MW of generating capacity subject to both of the Cypress Leases as of the end of the original lease term, January 15, 2016. The agreed fair market value in total for both of the Cypress Leases as of January 15, 2016 is $85.2 million. The agreement with respect to such fair market value is binding on PNM and the Cypress Entities.

The Cypress Letter Agreement also constitutes a letter of intent containing non-binding terms relating to the possible purchase of the entities that own the leased assets by PNMR Development prior to the expiration of the leases on January 15, 2016. The prices for the early purchase of the interests would depend on the actual date of the purchase and range from $79.9 million if the purchase were to take place on June 1, 2014 up to $85.2 million if the purchase were to take place on January 14, 2016. In addition, an amount equal to the lessors’ equity return portion of the future lease payments discounted to the early purchase date would be due upon an early purchase. Such amount would be $5.8 million on June 1, 2014 and would decline to $1.2 million on January 14, 2016. Any obligation of PNMR Development to purchase such interests is subject to appropriate approvals by the Board and the board of PNMR Development and the negotiation of acceptable definitive agreements. PNMR and PNM are unable to predict whether or not the early purchase of the Cypress Leases by PNMR Development will take place prior to the expiration of the leases, at which time PNM is otherwise obligated to purchase the leased assets in accordance with its January 13, 2014 notices.

ITEM 6. EXHIBITS

3.1	PNMR	Articles of Incorporation of PNMR, as amended to date (incorporated by reference to Exhibit 3.1 to PNMR’s Current Report on Form 8-K filed November 21, 2008)
3.2	PNM	Restated Articles of Incorporation of PNM, as amended through May 31, 2002 (incorporated by reference to Exhibit 3.1.1 to PNM’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2002)
3.3	TNMP	Articles of Incorporation of TNMP, as amended through July 7, 2005 (incorporated by reference to Exhibit 3.1.2 to TNMP’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2005)
3.4	PNMR	Bylaws of PNMR, with all amendments to and including December 8, 2009 (incorporated by reference to Exhibit 3.1 to PNMR’s Current Report on Form 8-K filed December 11, 2009)
3.5	PNM	Bylaws of PNM, with all amendments to and including May 31, 2002 (incorporated by reference to Exhibit 3.1.2 to PNM’s Report on Form 10-Q for the fiscal quarter ended June 30, 2002)
3.6	TNMP	Bylaws of TNMP, with all amendments to and including June 18, 2013 (incorporated by reference to Exhibit 3.6 to TNMP’s Current Report on Form 8-K filed June 20, 2013)
10.1	PNMR	PNM Resources, Inc. 2014 Officer Annual Incentive Plan dated March 20, 2014
10.2	PNMR	PNM Resources, Inc. 2014 Long-Term Incentive Plan dated March 20, 2014
10.3	PNM	Amendment Number 16, effective as of April 28, 2014, to the Arizona Nuclear Power Project Participation Agreement, dated August 23, 1973, among Arizona Public Service Company, Salt River Project Agricultural Improvement and Power District, Southern California Edison Company, Public Service Company of New Mexico, El Paso Electric Company, Southern California Public Power Authority, and Department of Water and Power of the City of Los Angeles.
10.4	PNM	Letter Agreement dated May 1, 2014, among PNM, PNMR Development and Management Corporation, Cypress Verde LLC, and Cypress Second PV Partnership.
12.1	PNMR	Ratio of Earnings to Fixed Charges

94

12.2	PNM	Ratio of Earnings to Fixed Charges
12.3	TNMP	Ratio of Earnings to Fixed Charges
31.1	PNMR	Chief Executive Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.2	PNMR	Chief Financial Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.3	PNM	Chief Executive Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.4	PNM	Chief Financial Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.5	TNMP	Chief Executive Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.6	TNMP	Chief Financial Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
32.1	PNMR	Chief Executive Officer and Chief Financial Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.2	PNM	Chief Executive Officer and Chief Financial Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.3	TNMP	Chief Executive Officer and Chief Financial Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
101.INS	PNMR, PNM, and TNMP	XBRL Instance Document
101.SCH	PNMR, PNM, and TNMP	XBRL Taxonomy Extension Schema Document
101.CAL	PNMR, PNM, and TNMP	XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF	PNMR, PNM, and TNMP	XBRL Taxonomy Extension Definition Linkbase Document
101.LAB	PNMR, PNM, and TNMP	XBRL Taxonomy Extension Label Linkbase Document
101.PRE	PNMR, PNM, and TNMP	XBRL Taxonomy Extension Presentation Linkbase Document

95

SIGNATURE

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

		PNM RESOURCES, INC. PUBLIC SERVICE COMPANY OF NEW MEXICO TEXAS-NEW MEXICO POWER COMPANY
		(Registrants)
Date:	May 2, 2014	/s/ Thomas G. Sategna
		Thomas G. Sategna
		Vice President and Corporate Controller
		(Officer duly authorized to sign this report)

96

EX-10.1

Exhibit 10.1

PNM RESOURCES, INC.

2014 OFFICER ANNUAL INCENTIVE PLAN

Introduction

PNM Resources, Inc. (the “Company” or “PNMR”) has adopted this 2014 Officer Annual Incentive Plan (the “Plan”) for the purpose of providing annual cash-based incentive awards (each an “Award”) to eligible Officers (as defined below). The Awards payable to Officers under the Plan are intended to qualify as Performance Cash Awards granted pursuant to Section 9.4 of the PNM Resources, Inc. Second Amended and Restated Omnibus Performance Equity Plan (the “PEP”). In the case of Officers who are Covered Employees as defined in the PEP, the Awards also are intended to qualify as Performance-Based Awards granted pursuant to Section 12 of the PEP.

Capitalized terms used in the PEP and not otherwise defined in this Plan document have the meanings given to them in the PEP.

Eligibility

All Officers of the Company and its Affiliates are eligible to participate in the Plan. For purposes of the Plan, the term “Officer” means any employee who has the title of Chief Executive Officer, Chief Operating Officer, Executive Vice President, Senior Vice President or Vice President and who is in salary grade H18 or higher.

Award Determinations in General

Awards are based on the Incentive Earnings Per Share (“Incentive EPS”) levels for the Performance Period as set forth in Table 1 of Attachment A, the weighting between Corporate and Business Area goals as described in Table 2 of Attachment A and Award levels achieved during the Performance Period as described in Table 3 of Attachment A. The Performance Period began on January 1, 2014 and will end on December 31, 2014.

An Officer’s Award will equal the Officer’s share of the Incentive EPS Award Pool described below. If the Officer’s share of the appropriate Performance Award Pool described below is less than the Officer’s share of the Incentive EPS Award Pool, however, the Officer will receive the smaller amount.

An Officer’s share of the Incentive EPS Award Pool or the Performance Award Pool (individually, an “Award Pool”), as applicable, will be based upon the amount potentially payable to the Officer for the attained level of performance (Threshold, Target or Maximum), as determined in accordance with Table 3 of Attachment A, as compared to the aggregate amounts potentially payable for the attained level of performance to all of the Officers who are entitled to share in that Award Pool. In determining the amount potentially payable to an Officer, the base salaries will be determined as of January 1, 2014. In no event will the amount payable to an Officer exceed the indicated percentage of the Officer’s base salary for the attained performance

level as set forth in Table 3 of Attachment A. In addition, in no event will the amount payable to one Officer be increased due to a decrease in the amount payable to any other Officer.

Incentive EPS Award Pool

In order for any Awards to be payable to eligible Officers, the Company must achieve the Threshold Incentive EPS level set forth in Table 1 of Attachment A. If the Company does not achieve the Threshold Incentive EPS level (calculated before any charges for amounts due pursuant to this Plan), no Awards are payable under the Plan to any Officer. If the Company achieves the Threshold Incentive EPS level (calculated before any charges for amounts due pursuant to this Plan), but the charges for amounts due pursuant to this Plan reduce the Incentive EPS to an amount below the Threshold Incentive EPS level, the Threshold level Incentive EPS Award Pool shall be reduced by the amount necessary to assure that the Incentive EPS is equal to the Threshold Incentive EPS level, unless the Committee, in the exercise of its discretion concludes that no Awards should be payable.

If the Threshold, Target or Maximum Incentive EPS levels, as listed in Table 1, are achieved, the aggregate potential Awards payable to the Officers at that level of performance (e.g., the aggregate level of Awards payable at Threshold, Target or Maximum as shown in Table 3 of Attachment A) will make up the “Incentive EPS Award Pool.” If the actual Incentive EPS exceeds the minimum level for a performance level by at least $0.01, but is less than the maximum level for that performance level (e.g., if the actual Incentive EPS exceeds $1.42 but is less than $1.47), the Incentive EPS Award Pool will be increased by using straight-line interpolation between the size of the Incentive EPS Award Pool based on the attained level (e.g., Threshold) and the size of the Incentive EPS Award Pool at the next higher level (e.g., Target). The Committee has the discretion to increase the Incentive EPS Award Pool by an amount less than the amount determined by using straight-line interpolation. The Incentive EPS Award Pool is capped by the aggregate Maximum Awards shown in Table 3 for all eligible Officers.

Performance Award Pools

A Corporate Goals Scorecard and Business Area Scorecards listing each performance measure established by the Committee will be maintained by the PNM Resources, Inc. Management Systems Group. As set forth in Table 2 of Attachment A, the performance of the Chief Executive Officer and the Senior Officers (the Chief Operating Officer, the Executive Vice President and the Senior Vice Presidents) are measured 100% on the Corporate Goals Scorecard. Vice Presidents are measured 60% on the Corporate Goals Scorecard and 40% on the Business Area Goals Scorecard.

The “Performance Award Pool” for each Business Area is the amount that could be paid in the aggregate to the Vice Presidents assigned to that Business Area based on performance alone, determined by using the following multi-step process:

a) Select the Scorecard results from the appropriate Corporate Goal and Business Area Scorecards;

b) Then multiply each result by the appropriate weighting for the Scorecard as set forth in Table 2 of Attachment A;

2

c) Then multiply the total Vice President salaries for that Business Area by the Target Award Level as set forth in Table 3 of Attachment A;

d) Then multiply the result of each Scorecard (Step b), expressed as a percentage of Target, by the aggregate base salaries of the Vice Presidents included in that Business Area (Step c); and

e) Sum the results for the Vice President participants.

The Performance Award Pool for the Chief Executive Officer and the Senior Officers will be constructed by using the same process but will be based solely upon the Corporate Goals Scorecard.

Award Approval and Payout Timing

In February 2015, the Committee will determine and certify the level of Awards, if any, payable for the Performance Period in the manner described above. The final Awards calculation and recommendation to the Committee by management will be reviewed and certified by the Vice-President, Human Resources; Director, Audit Services; Director, Management Systems group; and Corporate Controller, respectively. The independent directors of the Board then will approve the Chief Executive Officer’s Award and the Committee will approve the Awards for all other Officers. To the extent Awards are payable under the Plan, the Company will make the payment on or before March 15, 2015 in a single lump sum cash payment subject to applicable withholding.

The Committee shall retain the authority to adjust the Incentive EPS Award Pool and the Performance Award Pool, to adjust the level of attainment of the Incentive EPS or Corporate Goal and Business Area Scorecards or to otherwise increase or decrease the amount payable with respect to any Award made pursuant to this Plan. Notwithstanding the foregoing, the Committee’s authority to increase Awards made pursuant to this Plan does not apply to Covered Employees.

Provisions for a Change in Control

If a Change in Control occurs during the Performance Period and the Officer remains employed by the Company or an Affiliate at the end of the Performance Period, the Officer may be entitled to receive an Award for the Performance Period as determined in accordance with the provisions of this Plan. If the Plan is modified after the occurrence of a Change in Control in a manner that has the effect of reducing the amounts otherwise payable under the Plan, an Officer who remains employed by the Company or an Affiliate at the end of the Performance Period will receive, at a minimum, an Award equal to 50% of the Maximum Award available under this Plan for the Performance Period.

If an Officer terminates employment with the Company or an Affiliate during the Performance Period due to a Qualifying Change in Control Termination, the Officer may be entitled to receive a special payment pursuant to the PNM Resources, Inc. Officer Retention Plan in lieu of any payments under this Plan.

3

Pro-rata Awards for Partial Service Periods

In certain circumstances (as set forth below) Officers may or may not be eligible for a Pro-rata Award under the Plan.

The following Officers may be eligible for a Pro-rata Award:

- Officers who are newly hired during the Performance Period and are employed by the Company or an Affiliate on the day on which Awards are distributed for the Performance Period.

- Employees or Officers who are promoted, transferred or demoted during the Performance Period and are employed by the Company or an Affiliate on the day on which Awards are distributed for the Performance Period.

- Officers who are on leave of absence for any full month(s) during the Performance Period and are employed by the Company or an Affiliate on the day on which Awards are distributed for the Performance Period.

- Officers who terminate employment with the Company or an Affiliate during the Performance Period due to Impaction (as defined in the PNM Resources, Inc. Non-Union Severance Pay Plan), Retirement, or Disability.

- Officers who die during the Performance Period, in which case the Award will be paid to the spouse of a married Officer, including a same sex spouse, or the estate of an unmarried Officer.

The following Officers are not eligible for any Award, including a Pro-rata Award:

• Officers who terminate employment with the Company or an Affiliate on or before the date on which Awards are distributed for the Performance Period for any reason other than death, Impaction (as defined in the PNM Resources, Inc. Non-Union Severance Pay Plan), Retirement, or Disability. As noted above, Officers who terminate employment with the Company or an Affiliate during the Performance Period due to a Qualifying Change in Control Termination may be entitled to receive a special payment pursuant to the PNM Resources, Inc. Officer Retention Plan in lieu of any payments under this Plan.

• Officers who elect voluntary separation or Retirement in lieu of termination for performance or misconduct.

If an Officer is eligible for a Pro-rata Award, it will be calculated based on the number of full month(s) that the Officer was actively employed at each eligibility level during the Performance Period compared to the number of full months included in the Performance Period. (Note: Only months in which the Officer is actively employed on the payroll on the first and last day of the month will count as a full month.) Any Pro-rata Award to which an Officer becomes eligible pursuant to this paragraph will be paid to the Officer in a single lump sum cash payment subject to applicable withholding on or before March 15, 2015.

4

Ethics

The purpose of the Plan is to fairly reward performance achievement. Any Officer who manipulates or attempts to manipulate the Plan for personal gain at the expense of customers, shareholders, other employees, or the Company or its Affiliates will be subject to disciplinary action, up to and including termination of employment, and will forfeit and be ineligible to receive any Award under the Plan.

Continuation of Employment

This Plan does not confer upon any Officer any right to continue in the employment of the Company or any Affiliate and does not limit the right of the Company or any Affiliate, in its sole discretion, to terminate the employment of any Officer at any time. This Plan also does not limit any right that the Company or any Affiliate has to terminate the employment of any Officer in accordance with any written employment agreement the Company and Officer may have.

Clawbacks

Any Award granted pursuant to the Plan is subject to recovery by the Company pursuant to Section 21.5 of the PEP.

Amendments

The Committee, in its sole discretion, reserves the right to adjust, amend or suspend the Plan during the Performance Period.

/s/ Patrick V. Apodaca            

Patrick V. Apodaca

SVP and General Counsel

Dated:     March     20 , 2014

5

ATTACHMENT A

Incentive EPS Table

(Table 1)

	Incentive EPS1
No Award	Less than $1.42
Threshold	Greater than or equal to $1.42 and less than $1.47
Target	Greater than or equal to $1.47 and less than $1.58
Maximum	Greater than or equal to $1.58

Scorecard Weighting Table

(Table 2)

Scorecard Results
Scorecard Level	Corporate Weighting	Business Area Weighting
CEO & Senior Officers	100%	0%
Vice Presidents	60%	40%

^{_______________________________________} 

¹Equals PNMR’s diluted EPS for the fiscal year ending December 31, 2014 calculated in accordance with Generally Accepted Accounting Principles and reported in the Company’s Form 10-K for PNM Resources adjusted to exclude the following items: (1) mark-to-market impact of economic hedges, (2) regulatory disallowances, (3) net change in unrealized impairments of nuclear decommissioning trust securities, (4) gains or losses on reacquired debt, (5) goodwill or other intangible impairments, (6) impacts of acquisition and disposition activities, (7) adoption of a new accounting pronouncement or a change in the interpretation of an existing accounting standard, (8) the loss, impairment, or write-up of any deferred tax asset or liability that was earned and recognized in prior tax year, but that must be revalued in the current year due to a current year change in state or federal tax law and (9) judgments entered or settlements reached in litigation or other regulatory proceedings related to prior periods fuel issues. Diluted EPS expands on basic EPS by including the dilutive effect of common stock equivalents such as stock options and restricted stock awards.

A-1

Award Levels Table

(Table 3)

Award Levels	Threshold	Target	Maximum
CEO	47.5%	95%	190%
EVP	35%	70%	140%
SVP (other than SVP for Public Policy)	27.5%	55%	110%
SVP for Public Policy	25%	50%	100%
Vice-Presidents	17.5%	35%	70%

A-2

EX-10.2

Exhibit 10.2

PNM RESOURCES, INC.
2014 LONG-TERM INCENTIVE PLAN

Introduction

• The 2014 Long-Term Incentive Plan (the “Plan” or the “2014 Plan”) provides eligible officers of PNM Resources, Inc. (the “Company” or “PNMR”) with the opportunity to earn Performance Share Awards (70% of the total opportunity) and time-vested Restricted Stock Rights Awards (30% of the total opportunity). For purposes of the Plan, “officer” means any employee who has the title of Chief Executive Officer, Chief Operating Officer, Executive Vice President, Senior Vice President or Vice President and who is in salary grade H18 or higher.

• The number of Performance Shares earned by an officer for the Performance Period (as described below) will depend on the officer’s position (e.g., Chief Executive Officer, Chief Operating Officer, Executive Vice President, Senior Vice President or Vice President) and base salary and the Company’s level of attainment of a Relative TSR Goal and an FFO/Debt Ratio Goal, as described below.

• The number of time-vested Restricted Stock Rights granted to an officer at the end of each Performance Period will depend on the officer’s position, the officer’s base salary and the discretion of the Company’s Compensation and Human Resources Committee (the “Committee”).

Performance Periods

• The Performance Period began on January 1, 2014 and will end on December 31, 2016.

Performance Goals

• The number of Performance Shares that an officer will receive for the Performance Period will depend on the Company’s level of attainment of a Relative TSR Goal and a FFO/Debt Ratio Goal.

• These Goals and the corresponding Awards are described in the Performance Goal Table (Attachment A).

Performance Share Award Opportunities

• The Company’s level of attainment (Threshold, Target or Maximum) of the Relative TSR and FFO/Debt Ratio Goals determines the level (Threshold, Target or Maximum) of the officer’s Performance Share Awards.

• An officer’s Performance Share Award opportunities also will vary depending on the officer’s position and the officer’s base salary, all as determined in accordance with the Performance Share Award Opportunity Table (Attachment B).

• For purposes of determining the number of Performance Shares to which an officer is entitled at any particular Award Level, the value of one Performance Share shall be equal to the Fair Market Value of one share of the Company’s Stock on the relevant Grant Date and the officer’s base salary shall equal the officer’s base salary as of the first day of the Performance Period.

Time-Vested Restricted Stock Rights Award Opportunities

• After the Performance Period (generally between the next following January 1 and March 15), the Committee will consider whether to grant time-vested Restricted Stock Rights Awards to the participating officers.

• If the Committee, with the approval of the Company’s Board of Directors (the “Board”), decides to make a time-vested Restricted Stock Rights Award to a particular officer, it must adopt a written resolution to that effect. In the resolution, the Committee will establish the Grant Date for the time-vested Restricted Stock Rights Award.

• An officer’s time-vested Restricted Stock Rights Award opportunity will vary depending on the officer’s position and the officer’s base salary, all as determined in accordance with the attached time-vested Restricted Stock Rights Award Opportunity Table (Attachment C). The Committee reserves the discretion to grant an Award that is less than the opportunity set forth in the Table or to grant no time-vested Restricted Stock Rights Award to a particular officer.

• For purposes of determining the number of time-vested Restricted Stock Rights to which an officer will be entitled, the value of one time-vested Restricted Stock Right shall be equal to the Fair Market Value of one share of the Company’s Stock on the Grant Date specified in the Committee’s resolution and the officer’s base salary shall equal the officer’s base salary on the Grant Date.

Other Provisions

• All of the Awards will be made pursuant to the PNM Resources, Inc. Second Amended and Restated Omnibus Performance Equity Plan (the “PEP”) or any successor to the PEP. Any references in the Plan to the PEP shall be deemed to be a reference to the corresponding provisions of any successor to the PEP.

• All of the Awards will be subject to the standard Terms and Conditions attached hereto as Attachment D.

• The Grant Date for the Performance Share Awards is March 5, 2014 (the first trading day after expiration of the current black-out period, as determined in accordance with the Company’s Equity Compensation Awards Policy).

• A prorated Performance Share Award will be provided to an officer who Separates from Service in the second half of the Performance Period (in other words, between July 1, 2015 and December 31, 2016) due to death, Disability, Retirement or Impaction. A pro- rated Award will not be paid to an officer who Separates from Service for any of these reasons during the first half of the Performance Period or to an officer who Separates from Service for any other reason prior to the last day of the Performance Period.

• The prorated Award will be calculated at the end of the Performance Period based on actual performance during the Performance Period. The proration will be made based on the number of full months of service completed by the officer during the Performance Period, using the proration rules described in Section 13.1(a)(iv)(2) of the PEP. The prorated Award then will be paid at the same time as Awards are paid to other participants in the Plan.

2

• If an individual ceases to be an officer during a Performance Period but remains employed by the Company or its Affiliates, the Committee may grant a pro-rata Performance Share Award to the former officer on such terms and conditions as the Committee deems to be appropriate as long as the individual was an officer for at least half of the Performance Period.

• If an individual becomes an officer during a Performance Period, the Committee may grant a pro-rata Award to the new officer on such terms and conditions as the Committee deems to be appropriate.

• All Performance Share Awards payable to officers who are Covered Employees for the Company’s tax year that coincides with the end of the Performance Period are intended to qualify as Performance-Based Awards granted pursuant to Section 12 of the PEP. As a result, all such Awards are subject to the requirements of Section 12 of the PEP.

• Any Award granted pursuant to the Plan is subject to recovery by the Company pursuant to Section 21.5 of the PEP.

By signing below, the undersigned officer of PNM Resources, Inc. hereby certifies that the PNM Resources, Inc. 2014 Long-Term Incentive Plan, as set forth above, was approved by the Compensation and Human Resources Committee of the Board of Directors of PNM Resources, Inc. at its meeting on February 26, 2014.

/s/ Patrick V. Apodaca            

Patrick V. Apodaca

SVP and General Counsel

Dated:     March     20 , 2014

3

ATTACHMENT A

Performance Goal Table

Goal	Threshold Level	Target Level1	Maximum Level2
Relative TSR3 If the Company’s Relative TSR for the Performance Period places it in the Threshold, Target or Maximum Level range shown to the right, the officer will be entitled to receive 60% of the Threshold, Target or Maximum Award as determined in accordance with the Award Opportunity Table.	Greater than the 35th percentile but not greater than the 50th percentile.	Greater than the 50th percentile but not greater than the 95th percentile.	Greater than the 95th percentile.
FFO/Debt Ratio4 If the Company’s FFO/Debt Ratio on the last day of the Performance Period places it in the Threshold, Target or Maximum Level range for the Performance Period, the officer will be entitled to receive 40% of the Threshold, Target or Maximum Award as determined in accordance with the Award Opportunity Table.	At least 17.5% but less than 19.0%	At least 19.0% but less than 21.0%	At least 21.0%

^{___________________________________________} 

¹ If the Company’s Relative TSR or FFO/Debt Ratio falls between two Award levels (e.g., the Threshold Level and the Target Level shown in the Performance Goal Table), the number of Performance Shares to which an officer is entitled will be interpolated between the two Award levels in accordance with uniform procedures prescribed by the Committee.

² In no event will an officer receive more than the Maximum Award for an officer of his or her level as listed in the Award Opportunity Table.

³ The “Relative TSR” Goal refers to the Company’s “Total Shareholder Return” for the Performance Period (expressed as a percentage of the “Beginning Stock Price,” as defined below) as compared to the “Total Shareholder Return” of the other utilities included in the S & P 400 Mid-Cap Utility Index. For this purpose, the Total Shareholder Return of the Company and the other utilities included in the Index will be determined by adding any dividends paid by the Company (or such other utilities) to the appreciation in the value of the Company’s Stock (or the other utilities’ common stock). The appreciation shall be measured by comparing the “Beginning Stock Price” and “Ending Stock Price.” The “Beginning Stock Price” is the average closing price of the Company’s Stock (or the common stock of the other utilities) on the 20 trading days immediately preceding the first day of the Performance Period. The “Ending Stock Price” is the average closing price of the Company’s Stock (or the common stock of the other utilities) on the last 20 trading days of the Performance Period.

⁴ Equals PNMR’s funds from operations for the fiscal year ending December 31, 2016, divided by PNMR’s total debt outstanding (including any long-term leases and unfunded pension plan obligations) as of December 31, 2016. Funds from operations are equal to the amount of PNMR’s net cash flow from operating activities (as reflected on the Consolidated Statement of Cash Flows) as reported in the Company’s Form 10-K for PNM Resources adjusted by the following items: (1) adding amounts received by PNMR as principal payments on the Palo Verde lessor notes, (2) including amounts attributable to principal payments on imputed debt from long-term leases, (3) excluding changes in PNMR’s working capital, including bad debt expense, (4) excluding the impacts of the Valencia Energy Facility consolidation, (5) subtracting the amount of capitalized interest, and (6) excluding any contributions to the PNMR or TNMP qualified pension plans. The calculation is consistent with Moody’s calculation of FFO/Debt.

A-1

ATTACHMENT B

Performance Share Award Opportunity Table

Officer Level	Threshold Award	Target Award	Maximum Award
CEO	Performance Shares = 73.5% of base salary	Performance Shares = 147% of base salary	Performance Shares = 294% of base salary
EVP	Performance Shares = 38.5% of base salary	Performance Shares = 77% of base salary	Performance Shares = 154% of base salary
SVP, COO	Performance Shares = 31.5% of base salary	Performance Shares = 63% of base salary	Performance Shares = 126% of base salary
SVP,	Performance Shares = 29.75% of base salary	Performance Shares = 59.5% of base salary	Performance Shares = 119% of base salary
SVP for Public Policy	Performance Shares = 26.25% of base salary	Performance Shares = 52.5% of base salary	Performance Shares = 105% of base salary
VP	Performance Shares = 15.75% of base salary	Performance Shares = 31.5% of base salary	Performance Shares = 63% of base salary

B-1

ATTACHMENT C

Time-Vested Restricted Stock Rights Award Opportunity Table

Officer Level	Award
CEO	Restricted Stock Rights = 63% of base salary
EVP	Restricted Stock Rights = 33% of base salary
SVP, COO	Restricted Stock Rights = 27% of base salary
SVP	Restricted Stock Rights = 25.5% of base salary
SVP for Public Policy	Restricted Stock Rights = 22.5% of base salary
VP	Restricted Stock Rights = 13.5% of base salary

C-1

ATTACHMENT D

2014 LONG-TERM INCENTIVE PLAN

TERMS AND CONDITIONS

PNM Resources, Inc. (the “Company” or “PNMR”) has adopted the PNM Resources, Inc. Second Amended and Restated Omnibus Performance Equity Plan (the “PEP”) or any successor to the PEP. Pursuant to the PEP, the Company’s Compensation and Human Resources Committee (the “Committee”) has developed the PNM Resources, Inc. 2014 Long-Term Incentive Plan (the “Plan” or the “2014 Plan”) pursuant to which eligible officers may receive Performance Share Awards and time-vested Restricted Stock Rights Awards.

All of the Awards granted under the 2014 Plan are made pursuant to the PEP and are subject to the provisions of the PEP. In addition, all of the Awards under the 2014 Plan are made subject to these Terms and Conditions. All of the terms of the PEP are incorporated into this document by reference. Capitalized terms used in but not otherwise defined in this document shall have the meanings given to them in the PEP. Any references in the Plan to the PEP shall be deemed to be a reference to the corresponding provisions of any successor to the PEP.

1.    Performance Share Awards.

(a)    Determination of Relative TSR and FFO/Debt Ratio. The Committee will determine the Relative TSR and FFO/Debt Ratio for the Performance Period and the officer’s corresponding Performance Share Award, if any, within 60 days following the end of the Performance Period. The Committee then will certify and submit its determinations with respect to the Relative TSR and FFO/Debt Ratio and the number of Performance Shares to which an officer is entitled to the Board of Directors for review and approval. The Performance Shares to which an officer is entitled shall become payable at the times described below.

(b)    Separation from Service; Forfeiture. Unless an officer qualifies for a pro- rated Award, as described in the Plan, as a result of the officer’s Separation from Service during the second half of the Performance Period due to death, Disability, Retirement, or Impaction, the officer’s Award will be forfeited upon the officer’s Separation from Service prior to the end of the Performance Period. If the Company terminates an officer’s employment for Cause during or following the expiration of the Performance Period, all vested and unvested Performance Shares shall be canceled and forfeited immediately, regardless of whether the officer elects Retirement.

(c)    Form and Timing of Delivery of Stock. All of the Performance Shares awarded and vested pursuant to the Plan will be paid in Stock within the first 90 days of the calendar year following the end of the Performance Period. The Performance Shares granted under this Plan are subject to the requirements of Section 409A of the Code. Accordingly, the restrictions described in Section 20.3 of the PEP apply to the Performance Shares.

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2.    Time-Vested Restricted Stock Rights Awards.

(a)    Vesting.

(1)    Except as set forth below, the time-vested Restricted Stock Rights shall vest in the following manner: (i) 33% of the time-vested Restricted Stock Rights will vest on March 7, 2018; (ii) an additional 34% of the time-vested Restricted Stock Rights will vest on March 7, 2019; and (iii) the final 33% of the time-vested Restricted Stock Rights will vest on March 7, 2020.

(2)    Upon an officer’s involuntary or voluntary Separation from Service for any reason other than those set forth in Section 2(a)(3), the time-vested Restricted Stock Rights, if not previously vested, shall be canceled and forfeited immediately.

(3)    Upon an officer’s Separation from Service due to death, Disability, Retirement, Impaction or a Qualifying Change in Control Termination, any unvested time-vested Restricted Stock Rights shall become 100% vested in accordance with the applicable provisions of the PEP.

(b)    Form and Timing of Delivery of Certificate. All of the time-vested Restricted Stock Rights awarded pursuant to this Plan will be paid in Stock in accordance with the following provisions:

(1)    If any time-vested Restricted Stock Rights vest in accordance with Section 2(a)(1), the officer will receive the Stock payable with respect to such vested time-vested Restricted Stock Rights within 90 days following the dates on which the time-vested Restricted Stock Rights vest.

(2)    If any time-vested Restricted Stock Rights vest in accordance with Section 2(a)(3), the officer will receive the Stock payable with respect to such time-vested Restricted Stock Rights within 90 days following the date of the officer’s Separation from Service.

(3)    If the 90‑day period during which payments may be made pursuant to Section 2(a)(1) or (3) begins in one calendar year and ends in another, the officer will receive the Stock in the second calendar year.

(4)    All Stock will be awarded in accordance with the requirements of Section 409A of the Code and Section 20.3 of the PEP.

3.    Adjustments. Neither the existence of the Plan nor the Awards shall affect, in any way, the right or power of the Company to make or authorize: any or all adjustments, recapitalizations, reorganizations, or other changes in the Company’s capital structure or its business; or any merger or consolidation of the Company; or any corporate act or proceeding, whether of a similar character or otherwise; all of which, and the resulting adjustments in, or impact on, the Awards are more fully described in Section 5.3 of the PEP.

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4.    Dividend Equivalents. An officer will not be entitled to receive a dividend equivalent for any of the Performance Shares or time-vested Restricted Stock Rights granted under the Plan.

5.    Withholding. Pursuant to Section 18.1 of the PEP, the Company has concluded that an officer shall be required to satisfy federal, state, and local income tax withholding and employment tax requirements on any Award made pursuant to the Plan by directing the sale of a sufficient number of the shares acquired upon payment of the Award to cover the minimum withholding requirements, by means of the mandatory withholding of a number of shares sufficient to satisfy such requirements, or by such other means as the Company may direct from time to time.

6.    Status of Plan and Administration. The Plan and these Terms and Conditions shall at all times be subject to the terms and conditions of the PEP and shall in all respects be administered by the Committee in accordance with the terms of and as provided in the PEP. The Committee shall have the sole and complete discretion with respect to the interpretation of the Plan, these Terms and Conditions and the PEP, and all matters reserved to it by the PEP. The decisions of the majority of the Committee shall be final and binding upon an officer and the Company. In the event of any conflict between the terms and conditions of the Plan or these Terms and Conditions and the PEP, the provisions of the PEP shall control.

6.    Waiver and Modification. The provisions of the Plan and these Terms and Conditions may not be waived or modified unless such waiver or modification is in writing signed by an authorized representative of the Committee.

7.    Amendment or Suspension. The Committee, in its sole discretion, reserves the right to adjust, amend or suspend the Plan and these Terms and Conditions during the Performance Period except as otherwise provided in the PEP.

8.    Ethics. The purpose of the Plan is to fairly reward performance achievement. Any officer who manipulates or attempts to manipulate the Plan for personal gain at the expense of customers, shareholders, other employees, or the Company or its Affiliates will be subject to disciplinary action, up to and including termination of employment, and will forfeit and be ineligible to receive any Award under the Plan.

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EX-10.3

Exhibit 10.3

AMENDMENT NUMBER 16

TO THE ARIZONA NUCLEAR POWER PROJECT

PARTICIPATION AGREEMENT

1.    PARTIES:

The Parties to this Amendment Number 16 to the Arizona Nuclear Power Project Participation Agreement, hereinafter referred to as “Amendment Number 16,” are: ARIZONA PUBLIC SERVICE COMPANY, a corporation organized and existing under and by virtue of the laws of the State of Arizona, hereinafter referred to as “Arizona”; SALT RIVER PROJECT AGRICULTURAL IMPROVEMENT AND POWER DISTRICT, an agricultural improvement district organized and existing under and by virtue of the laws of the State of Arizona, hereinafter referred to as “Salt River Project”; SOUTHERN CALIFORNIA EDISON COMPANY, a corporation organized and existing under and by virtue of the laws of the State of California, hereinafter referred to as “Edison”; PUBLIC SERVICE COMPANY OF NEW MEXICO, a corporation organized and existing under and by virtue of the laws of the State of New Mexico, hereinafter referred to as “PNM”; EL PASO ELECTRIC COMPANY, a corporation organized and existing under and by virtue of the laws of the State of Texas, hereinafter referred to as “El Paso”; SOUTHERN CALIFORNIA PUBLIC POWER AUTHORITY, a joint powers agency organized and existing under and by virtue of the laws of the State of California, doing business in the State of Arizona as SOUTHERN CALIFORNIA PUBLIC POWER AUTHORITY ASSOCIATION, hereinafter referred to as “SCPPA”; and DEPARTMENT OF WATER AND POWER OF THE CITY OF LOS ANGELES, a municipal corporation organized and existing under and by virtue of the laws of the State of California, hereinafter referred to as “LADWP”; all hereinafter individually referred to as “Party” and collectively as “Parties.”

2.     RECITALS:

2.1. Arizona, Salt River Project, Edison, PNM, El Paso, SCPPA and LADWP are parties to a certain agreement entitled Arizona Nuclear Power Project Participation Agreement, dated as of August 23, 1973, as amended by: Amendment Number 1, dated as of January 1, 1974; Amendment Number 2, dated as of August 28,1975; Amendment Number 3, dated as of July 22, 1976; Amendment Number 4, dated as of December 15, 1977; Amendment Number 5, dated as of December 5, 1979; Amendment Number 6, effective as of October 16, 1981; Amendment Number 7, effective as of April 1, 1982; Amendment Number 8, executed as of September 12, 1983; Amendment Number 9, executed as of June 12, 1984 Amendment Number 10, executed as of November 21, 1985; Amendment Number 11, effective January 10, 1987; Amendment Number 12, effective August 5, 1988; Amendment Number 13, effective June 15, 1991; Amendment Number 14, effective June 20, 2000, retroactive to January 1, 1993; and Amendment Number 15, effective January 13, 2011, hereinafter, as so amended, collectively referred to as the “Participation Agreement.”

2.2. On April 21, 2011, the NRC, by letter to Arizona, confirmed the issuance of Renewed Facility Operating License Nos. NPF-41 (Unit 1), NPF-51 (Unit 2), and NPF -74 (Unit 3) for Palo Verde Station (collectively, the “License Extensions”).

2.3. Pursuant to the License Extensions, (i) Renewed Facility Operating License No. NPF-41 (Unit 1) expires at midnight on June 1, 2045; (ii) Renewed Facility Operating License No. NPF-51 (Unit 2) expires at midnight on April 24, 2046; and (iii) Renewed Facility Operating License No. NPF-74 (Unit 3) expires at midnight on November 25, 2047

(collectively, the “Extended License”). The latest expiration date of the original licenses previously had been November 25, 2027.

2.4. Pursuant to Section 35.7 of the Participation Agreement, the latest termination date of the Participation Agreement currently is December 31, 2027, which does not include the License Extensions.

2.5 Section 8A.4.4 of the Participation Agreement currently requires each Participant to accumulate Termination Funds over “the remaining license term (as specified in the original license issued for each Generating Unit . . . .” (emphasis added)

2.6. Arizona, PNM and El Paso (in Texas, not New Mexico) have already included in their cost of service the amounts for contributions to their decommissioning trust that reflect the Extended License (“60 Year Termination Funding Curves”), rather than the Original License (“40 Year Termination Funding Curves”), and collect from their respective ratepayers on that basis.

2.7 The Termination Funding Committee currently uses the 40 Year Termination Funding Curves to measure compliance of the Participants with the termination funding requirements set forth in the Participation Agreement and the Termination Funding Committee Manual. Therefore, the ability of Arizona, PNM and El Paso to meet their termination funding obligations is adversely impacted by the reduced recovery from their ratepayers under the 60 Year Termination Funding Curves, and their continuing obligation to maintain their Termination Funds at the higher levels required by the 40 Year Termination Funding Curves.

2.8 On June 18, 2012, the Termination Funding Committee held its annual meeting to submit its Annual Funding Status Reports and to resolve the foregoing termination funding curve issues. At the meeting, the Termination Funding Committee resolved, upon proper motion, that the 60 Year Termination Funding Curves were technically correct, and conditionally adopted the 60 Year Termination Funding Curves subject to the Administrative Committee’s extension of the Participation Agreement term.

2.9 On October 19, 2012, the Administrative Committee unanimously voted to adopt this Amendment Number 16.

3.     AGREEMENT:

For and in consideration of the premises and the mutual obligations of and undertakings by the Parties as hereinafter provided in this Amendment Number 16 to the Participation Agreement, the Parties agree as set forth below.

4.     EFFECTIVE DATE:

This Amendment Number 16 shall become effective on the date that the Party which last in time executes this Amendment Number 16. The amended termination funding curves that are associated with this Amendment Number 16 shall be applied retroactively to January 1, 2012.

5.     DEFINED TERMS:

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5.1. The Capitalized and italicized words and phrases used in this Amendment Number 16 shall have the meanings ascribed to them in the Participation Agreement as amended by this Amendment Number 16.

5.2. All references to a “Section” or “Sections” in this Amendment Number 16 shall mean a Section or Sections of the Participation Agreement unless the text expressly states otherwise.

6. AMENDMENTS TO THE ARIZONA NUCLEAR POWER PROJECT MADE BY THIS AMENDMENT NUMBER 16:

6.1. Amend Section 8A.4.4, by deleting the strikethrough text and substituting therefore the underlined text:

“Within six months after the date on which Amendment No. 13 shall become effective or such other date established by the Administrative Committee, the Termination Funding Committee shall establish criteria and standards, consistent with applicable law, including the rules and regulations of the NRC [including without limitation such discount factors, allowances for inflation, bases for estimating future net earnings on accumulations in the Termination Fund(s)

of the Participants and other elements as may be appropriate to provide reasonable assurance that each Participant will accumulate in its Termination Fund(s) over the then-applicable remaining license term for each Generating Unit(as specified in the original license issued for each Generating Unit authorizing fuel load and low power operation of such unit)sufficient funds to pay such Participant's share of the most current estimate of the Termination Costs of such unit)] that will be used by the committee to determine whether or not the periodic deposits made by each Participant in its Termination Fund(s) have been adequate and the accumulations in its Termination Funds will be adequate to meet the requirements of Section 8A.7.2.3 hereof and to comply with applicable laws. At least once every three years the Termination Funding Committee shall review such criteria and standards and make such adjustments thereto as are warranted by the circumstances then existing or as may be required by applicable law. Additionally, the Termination Funding Committee shall establish the format, content and time for submission of the funding status reports and certificates that Participants are required to submit pursuant to Section 8A.7.2.4 hereof.”

6.2. Amend Section 35.7, by deleting the strikethrough text and substituting therefore the underlined text:

“This Participation Agreement shall terminate on the earlier of: (i) the expiration date of the longest operating license period authorized by the NRC (or any governmental agency that is a successor to the NRC) for Palo Verde StationDecember 31, 2027, or (ii) the date on which all Generating Units shall have been permanently removed from service and all Termination Work in respect of all Generating/Terminated Units has been completed; provided, however, that . . .”

6.3.     Except as amended by this Amendment Number 16, the remaining terms of the Participation Agreement shall remain in full force and effect.

7.     EXECUTION BY COUNTERPARTS:

This Amendment Number 16 may be executed in any number of counterparts, whether by facsimile, electronic signature or otherwise, and upon execution by all Participants, each executed counterpart shall have the same force and effect as an original instrument and as if all Participants had signed the same instrument. Any signature page of this Amendment Number 16 may be detached from any

3

counterpart of the Amendment Number 16 without impairing the legal effect of any signature thereon, and may be attached to another counterpart of this Amendment Number 16 identical in form hereto but having attached to it one or more signature pages.

8.     SIGNATURE CLAUSE:

Each of the signatories below represents that he/she is appropriately authorized to enter into this Amendment Number 16 on behalf of the Party for which he/she signs.

ARIZONA PUBLIC SERVICE COMPANY

By:     /s/ Randall K. Edington            

Its:     Ex VP/CNO                

Date:     4/28/14                    

STATE OF ARIZONA    )

) ss.

County of Maricopa     )

On this 28^th day of April, 20124, before me, the undersigned Notary Public, personally appeared Randall K. Edington, who acknowledged him/herself to be the Ex VP / CNO         of ARIZONA PUBLIC SERVICE COMPANY, an Arizona corporation, and that he/she as such officer, being authorized to do, executed the foregoing instrument for the purposes therein contained by signing the name of the company by him/herself as such Executive Vice President/Chief Nuclear Officer.    

IN WITNESS WHEREOF, I hereunto set my hand and official seal.

/s/ Jennifer R. Stokic            

Notary Public

My Commission Expires:

1-17-2015        

JENNIFER R. STOKIC

Notary Public – Arizona

SEAL    Maricopa County

My Commission Expires

January 17, 2015

4

8.     SIGNATURE CLAUSE:

Each of the signatories below represents that he/she is appropriately authorized to enter into this Amendment Number 16 on behalf of the Party for which he/she signs.

SALT RIVER PROJECT AGRICULTURAL

IMPROVEMENT AND POWER DISTRICT

By: _/s/ Michael Hummel________________

Its: _AGM & Chief Power System Executive __

Date: _4/10/2014________________________

ATTEST AND COUNTERSIGN:

By: _____________________________________

Its: _____________________________________

Date: ____________________________________

STATE OF ARIZONA    )

) ss.

County of Maricopa     )            

CMH

2014

On this _10_ day of _April______, 2012, before me, the undersigned Notary Public, personally appeared _Michael Hummel____ who acknowledged him/herself to be the _AGM & Chief Power System Executive________ of SALT RIVER PROJECT AGRICULTURAL IMPROVEMENT AND POWER DISTRICT, an Arizona corporation, and that he/she as such officer, being authorized to do, executed the foregoing instrument for the purposes therein contained by signing the name of the company by him/herself as such ____________________________.

IN WITNESS WHEREOF, I hereunto set my hand and official seal.

___/s/Christina M. Hallows________________

Notary Public

My Commission Expires:

_September 5, 2014__        OFFICIAL SEAL

CHRISTINA M. HALLOWS

SEAL    Notary Public – State of Arizona

Maricopa County

My Comm. Expires Sept. 5, 2014

5

8.     SIGNATURE CLAUSE:

Each of the signatories below represents that he/she is appropriately authorized to enter into this Amendment Number 16 on behalf of the Party for which he/she signs.

SOUTHERN CALIFORNIA EDISON

COMPANY

By:     /s/ Thomas J. Palmisano            

Its:     Vice President & CNO            

Date:     3/16/2014                

STATE OF CALIFORNIA    )

Orange        ) ss.

County of Los Angeles        )

On this 16 day of April, 20124, before me, the undersigned Notary Public, personally appeared Thomas J. Palmisanowho acknowledged him/herself to be the Vice President      of SOUTHERN CALIFORNIA EDISON COMPANY, a California corporation, and that he/she as such officer, being authorized to do, executed the foregoing instrument for the purposes therein contained by signing the name of the company by him/herself as such      Southern California Edison        .

IN WITNESS WHEREOF, I hereunto set my hand and official seal.

BRAD MEINDERTSMA

Commission #1962205

SEAL    Notary Public – California

Orange County

My Comm. Expires Dec 1, 2015

/s/ Brad Meindertsma            

Notary Public

My Commission Expires:

12-1-2015        

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8.     SIGNATURE CLAUSE:

Each of the signatories below represents that he/she is appropriately authorized to enter into this Amendment Number 16 on behalf of the Party for which he/she signs.

PUBLIC SERVICE COMPANY OF NEW

MEXICO

By: /s/ Ronald E. Talbot                

Its: SVP and COO                

Date: 4/16/14                    

STATE OF NEW MEXICO    )

) ss.

County of Bernalillo        )

2014 sgg

On this _16_ day of April, 2012, before me, the undersigned Notary Public, personally appeared Ronald E. Talbot      who acknowledged him/herself to be the ___SVP and COO         of PUBLIC SERVICE COMPANY OF NEW MEXICO, a New Mexico corporation, and that he/she as such officer, being authorized to do, executed the foregoing instrument for the purposes therein contained by signing the name of the company by him/herself as such _Public Service Company of New Mexico,

SVP and COO

IN WITNESS WHEREOF, I hereunto set my hand and official seal.

__/s/ Susan G. Gordon            

Notary Public

My Commission Expires:

__September 12, 2016    

(SEAL)

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8.     SIGNATURE CLAUSE:

Each of the signatories below represents that he/she is appropriately authorized to enter into this Amendment Number 16 on behalf of the Party for which he/she signs.

EL PASO ELECTRIC COMPANY

By:     /s/ T.V. Shockley            

Its:     Chief Executive Officer            

Date:     March 17, 2014                

STATE OF TEXAS    )

) ss.

County of El Paso    )

On this 17^th day of March, 201214, before me, the undersigned Notary Public, personally appeared T.V. Shockley    , who acknowledged him/herself to be the Chief Executive Officer     of EL PASO ELECTRIC COMPANY, a Texas corporation, and that he/she as such officer, being authorized to do, executed the foregoing instrument for the purposes therein contained by signing the name of the company by him/herself as such     Chief Executive Officer        .

IN WITNESS WHEREOF, I hereunto set my hand and official seal.

/s/ Hilda Vargas                

HILDA VARGAS

SEAL    My Commission Expires

July 1, 2017

Notary Public

My Commission Expires:

July 1, 2017        

APPROVED AS TO FORM

OFFICE OF GENERAL COUNSEL /s/

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8.     SIGNATURE CLAUSE:

Each of the signatories below represents that he/she is appropriately authorized to enter into this Amendment Number 16 on behalf of the Party for which he/she signs.

SOUTHERN CALIFORNIA PUBLIC POWER AUTHORITY, doing business in the State of Arizona as SOUTHERN CALIFORNIA PUBLIC POWER AUTHORITY ASSOCIATION

By: R.E. Davis                    

Its: President                    

Date: 12/20/2012                

This is attached to a

________________________

Acknowledgment or Jurat

Salpi Ortiz, Notary Public

9

State of California

County of Los Angeles            

On December 20, 2012     before me,         Salpi Ortiz, a notary public            

personally appeared         Ron Davis                                

whoproved to me on the basis of satisfactory evidence tobe the person whose name is subscribed to the within instrument and acknowledged to me that he executed the same in his authorized capacity and that by his signature on the instrument the person or the entity upon behalf of which the person acted, executed the instrument.

I certify under PENALTY OF PERJURY under the laws of the State of California that the foregoing paragraph is true and correct.

WITNESS my hand and official seal.

Signature: /s/ Salpi Ortiz            

Notary Public

SALPI ORTIZ

Commission # 1926232

SEAL    Notary Public – California

Los Angeles County

My Comm. Expires Feb 20, 2015

8.     SIGNATURE CLAUSE:

Each of the signatories below represents that he/she is appropriately authorized to enter into this Amendment Number 16 on behalf of the Party for which he/she signs.

DEPARTMENT OF WATER AND

POWER OF THE CITY OF

LOS ANGELES

By: /s/ Marcie L. Edwards            

MARCIE L. EDWARDS

General Manager

APPROVED AS TO FORM AND LEGALITY

CARMEN A. TRUTANICH, CITY ATTORNEY

AUTHORIZED BY RES. 013 311

JUN 19 2013

JUN 06 2013

By /s/ Syndi Driscoll            

SYNDI DRISCOLL

DEPUTY CITY ATTORNEY

Date:_____3/31/14________________________

And /s/ Barbara E. Moschos            

BARBARA E. MOSCHOS

Board Secretary

STATE OF CALIFORNIA    )

) ss.

County of Los Angeles        )

On this _31^ST_ day of __March___, 20124, before me, the undersigned Notary Public, personally appeared __Marcie L. Edwards who acknowledged him/herself to be the _General Manager__ of DEPARTMENT OF WATER AND POWER OF THE CITY OF LOS ANGELES, a California joint powers agency, and that he/she as such officer, being authorized to do, executed the foregoing instrument for the purposes therein contained by signing the name of the company by him/herself as such

___General Manager____.

IN WITNESS WHEREOF, I hereunto set my hand and official seal.

___/s/Reynan L. Ledesma________________

Notary Public

My Commission Expires:

July 17, 2014_______            

Reynan L. Ledesma

Comm. # 1895685

SEAL    Notary Public – California

County of Los Angeles

My Comm. Exp. July 17, 2014

10

EX-10.4

Exhibit 10.4

PNMR DEVELOPMENT AND MANAGEMENT CORPORATION

c/o PNM Resources, Inc.

414 Silver Ave. SW

Albuquerque, New Mexico 87102-3289

(505) 241-2700

May 1, 2014

Cypress Verde LLC

Cypress Second PV Partnership

c/o Cypress Financial Corporation

188 The Embarcadero, Suite 420

San Francisco, California 94105

Attention of Mr. Peter E. Metzner

Re: Purchase of Two (2) Owner Participant Interests:

(i) all of the Owner Participant Interest (“Interest 136”) owned by Cypress Verde LLC (“CVLLC”) in a 1.36% undivided ownership interest in Palo Verde Nuclear Generating Station (“PVNGS”) Unit 2 (and related interests in certain PVNGS common facilities and real property) leased to Public Service Company of New Mexico (“PNM”); and

(i) all of the Owner Participant Interest (“Interest 113”) owned by Cypress Second PV Partnership (“CSPVP”) in a 1.1333333% undivided ownership interest in PVNGS Unit 2 (and related interests in certain PVNGS common facilities and real property) leased to PNM.

Dear Mr. Metzner:

1. (a) We refer to (x) the Participation Agreement dated as of August 12, 1986, as amended, to which PNM and CVLLC (successor in interest by assignment), among others are party (“Participation Agreement 136”), with respect to Interest 136 and the lease thereof to PNM, and (y) the Participation Agreement dated as of August 12, 1986, as amended, to which PNM and CSPVP (successor in interest by assignment), among others are party (“Participation Agreement 113”), with respect to Interest 113 and the lease thereof to PNM. Generally, capitalized terms used herein without definition shall have the meanings specified in Appendix A to each of Participation Agreement 136 and Participation Agreement 113 (collectively, the “Participation Agreements”) except that,

1

Letter Agreement dated May 1, 2014

where use of a defined term is preceded by either “136” or “113”, use of such defined term will bear the meaning specified in Appendix A to Participation Agreement 136 or in Appendix A to Participation Agreement 113, as applicable. Thus, the term “136 Undivided Interest” shall mean the Undivided Interest as such term is defined in Appendix A to Participation Agreement 136, and the term “113 Transaction Documents” shall mean the Transaction Documents as such term is defined in Appendix A to Participation Agreement 113. “Development” shall mean PNMR Development and Management Corporation, a New Mexico corporation. Each of Development and the Lessee is a direct, wholly-owned subsidiary of PNM Resources, Inc., a New Mexico corporation (“Resources”).

(b) While this letter of intent (this “Letter”) is not a binding agreement (except as provided in item 13 below), it outlines the preliminary terms of the transactions contemplated herein (the “Transactions”). This Letter is intended to serve as an outline of the proposed principal terms and conditions regarding the Transactions, and is subject to (i) the execution and delivery of Purchase Documentation (as defined in item 4(a) below) among the parties to this Letter, and, (ii) in the case of Development, approval by its Board of Directors and the Board of Directors of Resources. The parties recognize that there are other terms and conditions that have yet to be addressed, but the parties agree to work together in good faith to address these issues and to complete Purchase Documentation that is acceptable to the parties as quickly as is reasonably practicable.

2. By letter dated January 13, 2014, the Lessee provided notice of its irrevocable election to purchase (the “Notice of Option Exercise”) the subject Undivided Interest and Real Property Interest (the “Option Property”) pursuant to Section 13(a) of each Facility Lease. Following delivery of each Notice of Option Exercise, Section 13(a) of each Facility Lease requires that the Lessee and the Owner Participant promptly agree upon the Fair Market Sale Value (“FMSV”) of the Option Property under such Facility Lease to be paid by the Lessee on January 15, 2016 (the “Option Exercise Date”), following the expiration of the Basic Lease Term on January 15, 2016. The equity portion of scheduled Basic Rent under such Facility Lease that would otherwise be payable for the Final Rent Payment Date has been addressed as hereinafter described.

3. This Letter serves to memorialize the binding agreement of the Lessee, on the one hand, and CVLLC and CSPVP, on the other hand (collectively, the “Cypress Parties”)with respect to the FMSV of the Option Property to be paid by the Lessee on the Option Exercise Date in connection with consummating the Lessee’s irrevocable Purchase Option contemplated by Section 13(b) of each Facility Lease (collectively, the “Option Transactions” and, individually, an “Option Transaction”) and, in accordance with the requirements of Section 13(a) of each Facility Lease, the Lessee and the applicable Owner Participant have agreed that the FMSV of:

2

Letter Agreement dated May 1, 2014

(i) the 136 Undivided Interest to be purchased on the Option Exercise Date is $46,433,631.73 and the 136 Real Property Interest to be purchased on the Option Exercise Date is $19,701.60, for a total of $46,453,333.33 (the “136 Option Purchase Price”), and

(ii) the 113 Undivided Interest to be purchased on the Option Exercise Date is $38,694,579.76 and the 113 Real Property Interest to be purchased on the Option Exercise Date is $16,417.50, for a total of $38,710,997.26 (the “113 Option Purchase Price”).

The Lessee and the Cypress Parties acknowledge and agree that the equity portion of the installment of Basic Rent otherwise payable under each Facility Lease on the Option Exercise Date has not been included in the 136 Option Purchase Price or the 113 Option Purchase Price, and such equity portion of the installment of Basic Rent (being $694,926.00 for Interest 136 and $553,708.00 for Interest 113) will be due and payable on the Option Exercise Date in accordance with the Transaction Documents in addition to the 136 Option Purchase Price and the 113 Option Purchase Price, as applicable, all of the foregoing being payable in immediately available funds on the Option Exercise Date. The purchase and sale of the Option Properties shall be consummated on the Option Exercise Date as required by the Transaction Documents if the Purchase Transactions described in item 4 below shall not have been consummated prior thereto. The obligations of the Lessee detailed in this item 3 are effective for all purposes of the Transaction Documents without need for confirmation or further action of any sort by the Board of Directors of the Lessee.

4. (a) The Cypress Parties and Development (collectively, the “Purchase Parties”) have reached a mutual intent (subject to completion of mutually satisfactory purchase documentation (the “Purchase Documentation”) as described in item 5(a)(i) below) with respect to the sale and purchase (collectively, the “Purchase Transactions” and, individually, a “Purchase Transaction”) by Development of

(i) the Interest 136 including all right title and interest of CVLLC in, to and under the 136 Transaction Documents, but excluding, however, all Excepted Payments (other than the equity portion of basic rent and payments of Supplemental Rent otherwise specifically addressed in this Letter) from CVLLC, and

(ii) the Interest 113 including all right, title and interest of CSPVP in, to and under the 113 Transaction Documents, but excluding, however, all Excepted Payments (other than the equity portion of basic rent and payments of Supplemental Rent otherwise specifically addressed in this Letter) from CSPVP

on the Business Day mutually agreeable to the Purchase Parties (the “Early Purchase Date”), provided that the Early Purchase Date shall not be earlier than June 1, 2014 nor

3

Letter Agreement dated May 1, 2014

later than January 14, 2016. The transfer by CVLLC and CSPVP, respectively, of its right, title and interest in and to Interest 136 and Interest 113 shall be:

(i) free and clear of any and all

(x) Owner Participant's Liens and

(y) Claims by any Person arising by, through or under any act or omission of CVLLC and CSPVP or any of their respective Affiliates that are Claims based in whole or in part on indebtedness (excluding the 136 Transaction Documents or the 113 Transaction Documents (as applicable), and whether secured or unsecured and recourse or non-recourse), remarketing rights, residual sharing arrangements or guarantees, options, servicing or administration rights, management contracts or other right or entitlement similar to the foregoing “Specified Claims”); and

(ii) pursuant to an assignment and assumption agreement in form satisfactory to the Purchase Parties,

but otherwise without recourse, representation or warranty.

(b) The purchase price for Interest 136 (the “136 Early Purchase Price”) shall be the amount shown in the Early Purchase Schedule attached hereto (the “Early Purchase Schedule”) under the caption “Interest 136 Purchase Price” for the Early Purchase Date. The 136 Early Purchase Price shall be allocated as follows:

(i) $19,701.60 as the purchase price for the 136 Real Property Interest (the “136 RPI Purchase Price”); and

(ii) an amount equal to excess of the 136 Purchase Price over the 136 RPI Purchase Price as the purchase price for the 136 Undivided Interest.

(c) The purchase price for Interest 113 (the “113 Early Purchase Price”) shall be the amount shown in the Early Purchase Schedule under the caption “Interest 113 Purchase Price” for the Early Purchase Date. The 113 Early Purchase Price shall be allocated as follows:

(i) $16,417.50 as the purchase price for the 113 Real Property Interest (the “113 RPI Purchase Price”); and

(ii) an amount equal to excess of the 113 Purchase Price over the 113 RPI Purchase Price as the purchase price for the 113 Undivided Interest.

4

Letter Agreement dated May 1, 2014

(d) If the Early Purchase Date shall be a Rent Payment Date, the equity portion of Basic Rent due to the Cypress Parties in respect of such interest due on such Rent Payment Date as provided in the 113 Transaction Documents and the 136 Transaction Documents, as applicable, has been included in the 113 Early Purchase Price and the 136 Early Purchase Price applicable for such Early Purchase Date. If the Early Purchase Date shall not be a Rent Payment Date, the 113 Early Purchase Price and the 136 Early Purchase Price each include an amount agreed by the Purchase Parties in lieu of the equity portion of Basic Rent otherwise due to the Cypress Parties in respect of the period following the Rent Payment Date next preceding the Early Purchase Date through the end of the Basic Lease Term. Any Basic Rent due and payable prior to an Early Purchase Date shall be paid in accordance with the Transaction Documents. The 113 Early Purchase Price and the 136 Early Purchase Price shall be payable in immediately available funds on the Early Purchase Date.

5. (a) Development, on the one hand, and the Cypress Parties, on the other hand, further acknowledge and agree in good faith to:

(i) enter into definitive Purchase Documentation (including a purchase and sale agreement, assignment and assumption agreement, bill of sale and/or such other documentation as appropriate to effectuate the Purchase Transactions) or, in lieu of consummation of the Purchase Transactions, to consummate the Option Transactions as contemplated by each Notice of Option Exercise (separate but substantially identical Purchase Documentation shall be prepared for each of the Interest 136 and the Interest 113), including without limitation an (x) assignment and assumption agreement in form satisfactory to the parties in connection with the Purchase Transactions and (y) other documents contemplated to effect a Transfer of the Option Property; and

(ii) cooperate with respect to actions to be undertaken by the Lessee with respect to regulatory matters, including seeking necessary FERC approvals with respect to consummation of the Option Transactions.

The Purchase Documentation shall contain reasonable and customary terms and conditions consistent with the provisions of the 113 Transaction Documents and the 136 Transaction Documents, as applicable. Development will provide the initial draft of the Purchase Documentation.

(b) Notwithstanding the execution and delivery of any Purchase Documentation, each Notice of Option Exercise shall remain irrevocable in accordance with its terms and the applicable Facility Lease, and the failure of the Lessee to obtain any required consent or approval shall not relieve the Lessee of its obligation to purchase each Option Property on the Option Exercise Date; provided, that, in accordance with Section 13(a) of such Facility Lease, the Lessee’s irrevocable Notice of Option Exercise shall not be binding on the Lessor (or the Owner Participant) if an Event of Default shall have

5

Letter Agreement dated May 1, 2014

occurred under such Facility Lease and be continuing or an Event of Loss or a Deemed Event of Loss shall have occurred under such Facility Lease.

6. This Letter may be executed in counterparts, each of which shall constitute an original, but all of which when taken together shall constitute a single agreement. This Letter shall be effective as of the date hereof. Delivery of an executed counterpart of a signature page to this Letter by telecopy or portable document format (“PDF”) shall be effective as delivery of a manually executed counterpart of this Letter. Except as otherwise expressly provided herein, the terms of the Transaction Documents shall continue in full force and effect and nothing herein shall be interpreted or construed to limit or otherwise waive the rights or obligations of the parties set forth therein.

7. (a) CVLLC and CSPVP shall be solely responsible for all fees and expenses incurred by them in connection with the execution and delivery of Purchase Documentation, including fees and expenses of CVLLC and CSPVP (and their respective Affiliates) and their respective counsel.

(b) Development shall be responsible for:

(i) all fees and expenses incurred by PNM or by Development in connection with the execution and delivery of the Purchase Documentation contemplated hereby, including fees and expenses of counsel to PNM and Development; and

(ii) all Taxes imposed upon or arising from the transfer to the Lessee of Interest 113 or Interest 136 (including, without limitation, any Taxes that would otherwise be excluded by Participation Agreement Section 13(b)(2)(iv) from the Lessee's General Tax Indemnity pursuant to Section 13(b) thereof).

(c) In addition, Development shall be solely responsible for:

(i) the fees and expenses relating to

(A) all filings, including fees and expenses relating to the recordation of PNM’s interest in the property being acquired pursuant to the Purchase Documentation, as advised by PNM’s counsel, and

(B) any third party consents required in connection with the Purchase Documentation; and

(ii) the fees and expenses of the Owner Trustee and Indenture Trustee (including, without limitation, their respective counsel) in connection with the Transaction Documentation and the transactions contemplated thereby.

6

Letter Agreement dated May 1, 2014

8. This Letter shall be governed by, and construed in accordance with, the laws of the State of New York.

9. If each Owner Participant is in agreement with the terms set forth herein, please acknowledge our agreement in the space provided below and return a copy of this Letter to me by facsimile transmission or in PDF. By executing this Letter, each Owner Participant hereby instructs the Lessor to agree, and the Lessor hereby agrees, in its capacity as Owner Trustee and Lessor, to the terms set forth herein and to acknowledge agreement in the space provided below and return a copy of this Letter to the Lessee and each Owner Participant by facsimile transmission or in PDF.

10. Pursuant to the Purchase Documentation,

(i) each of CVLLC and CSPVP shall provide customary evidence (including certificates, lien and judgment searches, lender releases and opinions of California counsel)

(x) of its authority to execute, deliver and perform its respective obligations under the Purchase Documentation, and

(y) that the transfer of the Option Interests, or the Interest 113 and the Interest 136, are free and clear of Owner Participant's Liens and Specified Claims; and

(ii) with respect only to a purchase of Interest 113 or Interest 136, each Cypress fund that is a recipient of a portion of any purchase price funds (including funds paid directly or indirectly paid to a fund to discharge direct or indirect indebtedness of such fund) shall

(x) participate in a several guarantee (pro rata in accordance with its share of such purchase price funds) of the obligations of the sellers under such Purchase Documentation (the obligations under such guarantees shall expire on the earlier of (A) one year after the closing date or (B) January 15, 2016 (provided that such expiration date shall not apply to a Claim where, on or prior to such expiration date, Development shall have given written notice of such Claim)), and

(y) provide customary evidence (including certificates and opinions of counsel) of its authority to execute, deliver and perform its respective obligations under the Transaction Documents.

(iii) Each of Development and PNM shall provide customary evidence (including certificates, and opinions of counsel) of its authority to execute, deliver and perform its obligations under the Transaction Documents and that all consents, approvals and

7

Letter Agreement dated May 1, 2014

filings necessary or required in connection with the transactions contemplated by the Purchase Documentation shall have been obtained and/or effected, as applicable, and remain in full force and effect.

11. This Letter is being entered into on behalf of CVLLC and CSPVP by Cypress Equipment Management Corporation V (“CEMC V”). CEMC V is:

(i) the manager of CVLLC; and

(ii) the manager of each of the two partners in CSPVP, Cypress Second PV-A LLC and Cypress Second PV-B LLC.

CEMC V represents and warrants to each of Development and PNM that CEMC V has full right, power and authority to enter into and perform this Letter so as to bind CVLLC or CSPVP, as the case may be, without necessity of notice to, or consent, approval or other action by, any partner or member thereof, or any of its or their affiliates, which shall not have been obtained and shall remain in full force and effect.

12. In consideration hereof and of the time and resources that the parties will devote to the Transactions and the Purchase Documentation, and the various investigations and reviews undertaken by the parties, between the date of execution by them of this Letter and September 1, 2014 (or as such period may be mutually extended in writing by the parties) CEMC V and its subsidiaries, affiliates, directors, officers, employees, representatives and agents will not, directly or indirectly, solicit, initiate, enter into or continue any discussions or transactions with, or encourage, or provide any information to any person or entity with respect to any proposal pursuant to which CEMC V, CVLLC or CSVPP would sell Interest 113 or Interest 136. .

13. Except for items 2, 3, 4(b) and 4(c) (each applicable only if the Cypress Parties and Development shall complete the Purchase Documentation), 5 (as to the Option Transactions only), 6, 8, 9 and 12 of this Letter (which items are legally binding upon execution of this Letter), this Letter is a statement of mutual intention; this Letter is not intended to be legally binding, and does not constitute a binding contractual commitment with respect to the transaction. Without limiting the foregoing, the failure of the parties to reach agreement on the terms and conditions to be included in the Purchase Documentation shall not be construed as a breach of this Letter by any party hereto. A legally binding obligation with respect to the Purchase Transactions will arise only upon execution and delivery of the Purchase Documentation by the parties thereto, subject to the conditions expressed therein.

[The balance of this page is intentionally blank.]

8

Letter Agreement dated May 1, 2014

Signature Pages for Letter Agreement dated May 1, 2014

Sincerely,

PNMR DEVELOPMENT AND MANAGEMENT CORPORATION

By:/s/ Terry R. Horn_________________

Name: Terry R. Horn

Title: President, Chief Executive Officer

and Treasurer

Confirmation

PNM confirms: (i) the matters concerning it and the Option Transactions expressed in the above Letter; and (ii) that, notwithstanding the above Letter, it shall remain responsible for (x) all Supplemental Rent in accordance with the provisions of the 113 Transaction Documents and the 136 Transaction Documents, as applicable (excluding items of Supplemental Rent, such as expense payment or expense reimbursement, that are otherwise specifically addressed in above Letter), and (y) all Taxes imposed upon or arising from the transfer to the Lessee of the Option Property as required by the 113 Transaction Documents or the 136 Transaction Documents, as applicable.

PUBLIC SERVICE COMPANY OF NEW MEXICO

By:/s/ Charles N. Eldred____________

Name: Charles N. Eldred

Title: Executive Vice President

and Chief Financial Officer

9

Letter Agreement dated May 1, 2014

Signature Pages for Letter Agreement dated May 1, 2014

Acknowledged and Agreed:

CYPRESS VERDE LLC

By:    Cypress Equipment Management Corporation V, its manager    

By:/s/ Peter E. Metzner __________

Name:     Peter E. Metzner

Title:     President

CYPRESS SECOND PV PARTNERSHIP

By:    Cypress Second PV-A LLC, a partner

By:    Cypress Equipment Management Corporation V, its manager

By:/s/ Peter E. Metzner__________

Name:     Peter E. Metzner

Title:     President

By:    Cypress Second PV-B LLC, a partner

By:    Cypress Equipment Management Corporation V, its manager

By: /s/ Peter E. Metzner__________

Name:     Peter E. Metzner

Title:     President

10

Letter Agreement dated May 1, 2014

Signature Pages for Letter Agreement dated May 1, 2014

Acknowledged and Agreed:

U.S. BANK NATIONAL ASSOCIATION, not in
its individual capacity but solely as Owner Trustee

under the Trust Agreement with each instructing

Owner Participant,

By:/s/Todd R. DiNezza_______________

Name: Todd R. DiNezza

Title: Assistant Vice President

11

Letter Agreement dated May 1, 2014

EARLY PURCHASE SCHEDULE

Early Purchase Date	Interest 136 Purchase Price	Interest 113 Purchase Price
6/1/2014	46,814,560.50	38,922,681.72
6/2/2014	46,819,591.18	38,926,864.35
6/3/2014	46,824,622.41	38,931,047.42
6/4/2014	46,829,654.17	38,935,230.94
6/5/2014	46,834,686.47	38,939,414.91
6/6/2014	46,839,719.32	38,943,599.33
6/7/2014	46,844,752.71	38,947,784.20
6/8/2014	46,849,786.63	38,951,969.53
6/9/2014	46,854,821.10	38,956,155.30
6/10/2014	46,859,856.11	38,960,341.52
6/11/2014	46,864,891.66	38,964,528.19
6/12/2014	46,869,927.75	38,968,715.30
6/13/2014	46,874,964.38	38,972,902.87
6/14/2014	46,880,001.56	38,977,090.89
6/15/2014	46,885,039.27	38,981,279.36
6/16/2014	46,890,077.53	38,985,468.28
6/17/2014	46,895,116.32	38,989,657.65
6/18/2014	46,900,155.66	38,993,847.47
6/19/2014	46,905,195.54	38,998,037.74
6/20/2014	46,910,235.97	39,002,228.46
6/21/2014	46,915,276.93	39,006,419.64
6/22/2014	46,920,318.43	39,010,611.26
6/23/2014	46,925,360.48	39,014,803.33
6/24/2014	46,930,403.07	39,018,995.85
6/25/2014	46,935,446.20	39,023,188.82
6/26/2014	46,940,489.87	39,027,382.25
6/27/2014	46,945,534.09	39,031,576.12
6/28/2014	46,950,578.85	39,035,770.45
6/29/2014	46,955,624.15	39,039,965.22

12

Letter Agreement dated May 1, 2014

6/30/2014	46,960,669.99	39,044,160.45
7/1/2014	46,965,716.37	39,048,356.12
7/2/2014	46,970,763.30	39,052,552.25
7/3/2014	46,975,810.76	39,056,748.83
7/4/2014	46,980,858.77	39,060,945.86
7/5/2014	46,985,907.33	39,065,143.34
7/6/2014	46,990,956.42	39,069,341.27
7/7/2014	46,996,006.06	39,073,539.66
7/8/2014	47,001,056.24	39,077,738.49
7/9/2014	47,006,106.96	39,081,937.78
7/10/2014	47,011,158.23	39,086,137.51
7/11/2014	47,016,210.04	39,090,337.70
7/12/2014	47,021,262.39	39,094,538.34
7/13/2014	47,026,315.28	39,098,739.43
7/14/2014	47,031,368.72	39,102,940.97
7/15/2014	47,036,422.70	39,107,142.96
7/16/2014	46,243,812.27	38,467,676.22
7/17/2014	46,248,781.62	38,471,809.95
7/18/2014	46,253,751.50	38,475,944.12
7/19/2014	46,258,721.92	38,480,078.74
7/20/2014	46,263,692.87	38,484,213.80
7/21/2014	46,268,664.36	38,488,349.30
7/22/2014	46,273,636.38	38,492,485.25
7/23/2014	46,278,608.94	38,496,621.65
7/24/2014	46,283,582.02	38,500,758.48
7/25/2014	46,288,555.65	38,504,895.77
7/26/2014	46,293,529.81	38,509,033.49
7/27/2014	46,298,504.50	38,513,171.67
7/28/2014	46,303,479.73	38,517,310.28
7/29/2014	46,308,455.49	38,521,449.35
7/30/2014	46,313,431.78	38,525,588.85
7/31/2014	46,318,408.62	38,529,728.80
8/1/2014	46,323,385.98	38,533,869.20
8/2/2014	46,328,363.88	38,538,010.04
8/3/2014	46,333,342.32	38,542,151.33
8/4/2014	46,338,321.29	38,546,293.06
8/5/2014	46,343,300.80	38,550,435.24
8/6/2014	46,348,280.84	38,554,577.86
8/7/2014	46,353,261.41	38,558,720.92
8/8/2014	46,358,242.52	38,562,864.43
8/9/2014	46,363,224.17	38,567,008.39
8/10/2014	46,368,206.35	38,571,152.79
8/11/2014	46,373,189.07	38,575,297.64

13

Letter Agreement dated May 1, 2014

8/12/2014	46,378,172.32	38,579,442.93
8/13/2014	46,383,156.11	38,583,588.67
8/14/2014	46,388,140.43	38,587,734.86
8/15/2014	46,393,125.29	38,591,881.49
8/16/2014	46,398,110.69	38,596,028.56
8/17/2014	46,403,096.62	38,600,176.08
8/18/2014	46,408,083.09	38,604,324.05
8/19/2014	46,413,070.09	38,608,472.46
8/20/2014	46,418,057.63	38,612,621.32
8/21/2014	46,423,045.70	38,616,770.62
8/22/2014	46,428,034.31	38,620,920.37
8/23/2014	46,433,023.46	38,625,070.57
8/24/2014	46,438,013.14	38,629,221.21
8/25/2014	46,443,003.36	38,633,372.30
8/26/2014	46,447,994.12	38,637,523.83
8/27/2014	46,452,985.41	38,641,675.81
8/28/2014	46,457,977.23	38,645,828.24
8/29/2014	46,462,969.60	38,649,981.11
8/30/2014	46,467,962.50	38,654,134.43
8/31/2014	46,472,955.94	38,658,288.19
9/1/2014	46,477,949.91	38,662,442.40
9/2/2014	46,482,944.42	38,666,597.06
9/3/2014	46,487,939.47	38,670,752.17
9/4/2014	46,492,935.05	38,674,907.72
9/5/2014	46,497,931.17	38,679,063.71
9/6/2014	46,502,927.83	38,683,220.16
9/7/2014	46,507,925.02	38,687,377.05
9/8/2014	46,512,922.76	38,691,534.39
9/9/2014	46,517,921.02	38,695,692.17
9/10/2014	46,522,919.83	38,699,850.40
9/11/2014	46,527,919.17	38,704,009.08
9/12/2014	46,532,919.05	38,708,168.20
9/13/2014	46,537,919.47	38,712,327.77
9/14/2014	46,542,920.42	38,716,487.79
9/15/2014	46,547,921.92	38,720,648.26
9/16/2014	46,552,923.95	38,724,809.17
9/17/2014	46,557,926.51	38,728,970.53
9/18/2014	46,562,929.62	38,733,132.34
9/19/2014	46,567,933.26	38,737,294.59
9/20/2014	46,572,937.44	38,741,457.29
9/21/2014	46,577,942.16	38,745,620.44
9/22/2014	46,582,947.41	38,749,784.04
9/23/2014	46,587,953.21	38,753,948.08

14

Letter Agreement dated May 1, 2014

9/24/2014	46,592,959.54	38,758,112.57
9/25/2014	46,597,966.41	38,762,277.51
9/26/2014	46,602,973.81	38,766,442.89
9/27/2014	46,607,981.76	38,770,608.73
9/28/2014	46,612,990.24	38,774,775.01
9/29/2014	46,617,999.26	38,778,941.74
9/30/2014	46,623,008.82	38,783,108.91
10/1/2014	46,628,018.92	38,787,276.54
10/2/2014	46,633,029.56	38,791,444.61
10/3/2014	46,638,040.74	38,795,613.13
10/4/2014	46,643,052.45	38,799,782.10
10/5/2014	46,648,064.70	38,803,951.52
10/6/2014	46,653,077.49	38,808,121.38
10/7/2014	46,658,090.82	38,812,291.69
10/8/2014	46,663,104.69	38,816,462.45
10/9/2014	46,668,119.10	38,820,633.66
10/10/2014	46,673,134.04	38,824,805.32
10/11/2014	46,678,149.53	38,828,977.42
10/12/2014	46,683,165.55	38,833,149.98
10/13/2014	46,688,182.11	38,837,322.98
10/14/2014	46,693,199.22	38,841,496.43
10/15/2014	46,698,216.86	38,845,670.33
10/16/2014	46,703,235.04	38,849,844.67
10/17/2014	46,708,253.76	38,854,019.47
10/18/2014	46,713,273.02	38,858,194.71
10/19/2014	46,718,292.81	38,862,370.41
10/20/2014	46,723,313.15	38,866,546.55
10/21/2014	46,728,334.03	38,870,723.14
10/22/2014	46,733,355.44	38,874,900.18
10/23/2014	46,738,377.40	38,879,077.67
10/24/2014	46,743,399.90	38,883,255.60
10/25/2014	46,748,422.93	38,887,433.99
10/26/2014	46,753,446.51	38,891,612.83
10/27/2014	46,758,470.62	38,895,792.11
10/28/2014	46,763,495.28	38,899,971.84
10/29/2014	46,768,520.47	38,904,152.03
10/30/2014	46,773,546.21	38,908,332.66
10/31/2014	46,778,572.48	38,912,513.74
11/1/2014	46,783,599.30	38,916,695.27
11/2/2014	46,788,626.65	38,920,877.25
11/3/2014	46,793,654.55	38,925,059.68
11/4/2014	46,798,682.99	38,929,242.56
11/5/2014	46,803,711.96	38,933,425.88

15

Letter Agreement dated May 1, 2014

11/6/2014	46,808,741.48	38,937,609.66
11/7/2014	46,813,771.54	38,941,793.89
11/8/2014	46,818,802.13	38,945,978.57
11/9/2014	46,823,833.27	38,950,163.69
11/10/2014	46,828,864.95	38,954,349.27
11/11/2014	46,833,897.17	38,958,535.29
11/12/2014	46,838,929.93	38,962,721.77
11/13/2014	46,843,963.23	38,966,908.69
11/14/2014	46,848,997.07	38,971,096.07
11/15/2014	46,854,031.46	38,975,283.90
11/16/2014	46,859,066.38	38,979,472.17
11/17/2014	46,864,101.85	38,983,660.90
11/18/2014	46,869,137.85	38,987,850.07
11/19/2014	46,874,174.40	38,992,039.70
11/20/2014	46,879,211.49	38,996,229.77
11/21/2014	46,884,249.12	39,000,420.30
11/22/2014	46,889,287.29	39,004,611.28
11/23/2014	46,894,326.00	39,008,802.70
11/24/2014	46,899,365.26	39,012,994.58
11/25/2014	46,904,405.05	39,017,186.91
11/26/2014	46,909,445.39	39,021,379.69
11/27/2014	46,914,486.27	39,025,572.92
11/28/2014	46,919,527.69	39,029,766.60
11/29/2014	46,924,569.65	39,033,960.73
11/30/2014	46,929,612.15	39,038,155.31
12/1/2014	46,934,655.20	39,042,350.34
12/2/2014	46,939,698.79	39,046,545.82
12/3/2014	46,944,742.92	39,050,741.76
12/4/2014	46,949,787.59	39,054,938.14
12/5/2014	46,954,832.80	39,059,134.97
12/6/2014	46,959,878.56	39,063,332.26
12/7/2014	46,964,924.86	39,067,530.00
12/8/2014	46,969,971.70	39,071,728.19
12/9/2014	46,975,019.08	39,075,926.83
12/10/2014	46,980,067.01	39,080,125.92
12/11/2014	46,985,115.47	39,084,325.46
12/12/2014	46,990,164.48	39,088,525.45
12/13/2014	46,995,214.04	39,092,725.90
12/14/2014	47,000,264.13	39,096,926.79
12/15/2014	47,005,314.77	39,101,128.14
12/16/2014	47,010,365.95	39,105,329.94
12/17/2014	47,015,417.67	39,109,532.19
12/18/2014	47,020,469.94	39,113,734.89

16

Letter Agreement dated May 1, 2014

12/19/2014	47,025,522.75	39,117,938.04
12/20/2014	47,030,576.10	39,122,141.65
12/21/2014	47,035,630.00	39,126,345.70
12/22/2014	47,040,684.44	39,130,550.21
12/23/2014	47,045,739.42	39,134,755.17
12/24/2014	47,050,794.94	39,138,960.59
12/25/2014	47,055,851.01	39,143,166.45
12/26/2014	47,060,907.62	39,147,372.77
12/27/2014	47,065,964.78	39,151,579.53
12/28/2014	47,071,022.48	39,155,786.75
12/29/2014	47,076,080.72	39,159,994.43
12/30/2014	47,081,139.50	39,164,202.55
12/31/2014	47,086,198.83	39,168,411.13
1/1/2015	47,091,258.71	39,172,620.16
1/2/2015	47,096,319.12	39,176,829.64
1/3/2015	47,101,380.08	39,181,039.57
1/4/2015	47,106,441.59	39,185,249.96
1/5/2015	47,111,503.63	39,189,460.80
1/6/2015	47,116,566.23	39,193,672.09
1/7/2015	47,121,629.36	39,197,883.83
1/8/2015	47,126,693.04	39,202,096.03
1/9/2015	47,131,757.27	39,206,308.68
1/10/2015	47,136,822.03	39,210,521.78
1/11/2015	47,141,887.35	39,214,735.33
1/12/2015	47,146,953.20	39,218,949.34
1/13/2015	47,152,019.61	39,223,163.80
1/14/2015	47,157,086.55	39,227,378.71
1/15/2015	47,162,154.04	39,231,594.08
1/16/2015	46,173,855.09	38,428,905.94
1/17/2015	46,178,816.92	38,433,035.51
1/18/2015	46,183,779.29	38,437,165.51
1/19/2015	46,188,742.19	38,441,295.96
1/20/2015	46,193,705.62	38,445,426.85
1/21/2015	46,198,669.59	38,449,558.19
1/22/2015	46,203,634.08	38,453,689.97
1/23/2015	46,208,599.12	38,457,822.20
1/24/2015	46,213,564.68	38,461,954.87
1/25/2015	46,218,530.78	38,466,087.98
1/26/2015	46,223,497.42	38,470,221.54
1/27/2015	46,228,464.58	38,474,355.54
1/28/2015	46,233,432.28	38,478,489.98
1/29/2015	46,238,400.52	38,482,624.87
1/30/2015	46,243,369.29	38,486,760.21

17

Letter Agreement dated May 1, 2014

1/31/2015	46,248,338.59	38,490,895.99
2/1/2015	46,253,308.42	38,495,032.21
2/2/2015	46,258,278.80	38,499,168.88
2/3/2015	46,263,249.70	38,503,305.99
2/4/2015	46,268,221.14	38,507,443.55
2/5/2015	46,273,193.11	38,511,581.55
2/6/2015	46,278,165.62	38,515,720.00
2/7/2015	46,283,138.66	38,519,858.89
2/8/2015	46,288,112.24	38,523,998.22
2/9/2015	46,293,086.35	38,528,138.00
2/10/2015	46,298,060.99	38,532,278.23
2/11/2015	46,303,036.17	38,536,418.90
2/12/2015	46,308,011.89	38,540,560.01
2/13/2015	46,312,988.13	38,544,701.57
2/14/2015	46,317,964.92	38,548,843.58
2/15/2015	46,322,942.24	38,552,986.03
2/16/2015	46,327,920.09	38,557,128.92
2/17/2015	46,332,898.48	38,561,272.27
2/18/2015	46,337,877.40	38,565,416.05
2/19/2015	46,342,856.86	38,569,560.28
2/20/2015	46,347,836.85	38,573,704.96
2/21/2015	46,352,817.38	38,577,850.08
2/22/2015	46,357,798.44	38,581,995.65
2/23/2015	46,362,780.04	38,586,141.66
2/24/2015	46,367,762.18	38,590,288.12
2/25/2015	46,372,744.85	38,594,435.02
2/26/2015	46,377,728.05	38,598,582.37
2/27/2015	46,382,711.79	38,602,730.17
2/28/2015	46,387,696.07	38,606,878.41
3/1/2015	46,392,680.88	38,611,027.10
3/2/2015	46,397,666.23	38,615,176.23
3/3/2015	46,402,652.11	38,619,325.81
3/4/2015	46,407,638.53	38,623,475.83
3/5/2015	46,412,625.48	38,627,626.30
3/6/2015	46,417,612.98	38,631,777.22
3/7/2015	46,422,601.00	38,635,928.58
3/8/2015	46,427,589.56	38,640,080.39
3/9/2015	46,432,578.66	38,644,232.64
3/10/2015	46,437,568.30	38,648,385.34
3/11/2015	46,442,558.47	38,652,538.49
3/12/2015	46,447,549.18	38,656,692.08
3/13/2015	46,452,540.42	38,660,846.12
3/14/2015	46,457,532.20	38,665,000.61

18

Letter Agreement dated May 1, 2014

3/15/2015	46,462,524.52	38,669,155.54
3/16/2015	46,467,517.37	38,673,310.92
3/17/2015	46,472,510.76	38,677,466.75
3/18/2015	46,477,504.68	38,681,623.02
3/19/2015	46,482,499.15	38,685,779.74
3/20/2015	46,487,494.15	38,689,936.90
3/21/2015	46,492,489.68	38,694,094.52
3/22/2015	46,497,485.75	38,698,252.58
3/23/2015	46,502,482.36	38,702,411.08
3/24/2015	46,507,479.51	38,706,570.03
3/25/2015	46,512,477.19	38,710,729.43
3/26/2015	46,517,475.41	38,714,889.28
3/27/2015	46,522,474.17	38,719,049.57
3/28/2015	46,527,473.47	38,723,210.31
3/29/2015	46,532,473.30	38,727,371.50
3/30/2015	46,537,473.67	38,731,533.14
3/31/2015	46,542,474.58	38,735,695.22
4/1/2015	46,547,476.02	38,739,857.75
4/2/2015	46,552,478.00	38,744,020.72
4/3/2015	46,557,480.52	38,748,184.15
4/4/2015	46,562,483.58	38,752,348.02
4/5/2015	46,567,487.17	38,756,512.34
4/6/2015	46,572,491.30	38,760,677.11
4/7/2015	46,577,495.97	38,764,842.32
4/8/2015	46,582,501.18	38,769,007.98
4/9/2015	46,587,506.93	38,773,174.09
4/10/2015	46,592,513.21	38,777,340.65
4/11/2015	46,597,520.03	38,781,507.65
4/12/2015	46,602,527.39	38,785,675.10
4/13/2015	46,607,535.29	38,789,843.00
4/14/2015	46,612,543.72	38,794,011.35
4/15/2015	46,617,552.70	38,798,180.15
4/16/2015	46,622,562.21	38,802,349.39
4/17/2015	46,627,572.26	38,806,519.08
4/18/2015	46,632,582.85	38,810,689.22
4/19/2015	46,637,593.98	38,814,859.81
4/20/2015	46,642,605.64	38,819,030.85
4/21/2015	46,647,617.85	38,823,202.33
4/22/2015	46,652,630.59	38,827,374.27
4/23/2015	46,657,643.87	38,831,546.65
4/24/2015	46,662,657.69	38,835,719.48
4/25/2015	46,667,672.05	38,839,892.75
4/26/2015	46,672,686.95	38,844,066.48

19

Letter Agreement dated May 1, 2014

4/27/2015	46,677,702.38	38,848,240.66
4/28/2015	46,682,718.36	38,852,415.28
4/29/2015	46,687,734.87	38,856,590.35
4/30/2015	46,692,751.93	38,860,765.87
5/1/2015	46,697,769.52	38,864,941.84
5/2/2015	46,702,787.65	38,869,118.26
5/3/2015	46,707,806.32	38,873,295.13
5/4/2015	46,712,825.54	38,877,472.44
5/5/2015	46,717,845.29	38,881,650.21
5/6/2015	46,722,865.58	38,885,828.42
5/7/2015	46,727,886.40	38,890,007.08
5/8/2015	46,732,907.77	38,894,186.20
5/9/2015	46,737,929.68	38,898,365.76
5/10/2015	46,742,952.13	38,902,545.77
5/11/2015	46,747,975.12	38,906,726.23
5/12/2015	46,752,998.64	38,910,907.13
5/13/2015	46,758,022.71	38,915,088.49
5/14/2015	46,763,047.32	38,919,270.30
5/15/2015	46,768,072.46	38,923,452.55
5/16/2015	46,773,098.15	38,927,635.26
5/17/2015	46,778,124.38	38,931,818.42
5/18/2015	46,783,151.14	38,936,002.02
5/19/2015	46,788,178.45	38,940,186.07
5/20/2015	46,793,206.30	38,944,370.58
5/21/2015	46,798,234.69	38,948,555.53
5/22/2015	46,803,263.62	38,952,740.94
5/23/2015	46,808,293.08	38,956,926.79
5/24/2015	46,813,323.09	38,961,113.09
5/25/2015	46,818,353.64	38,965,299.84
5/26/2015	46,823,384.73	38,969,487.05
5/27/2015	46,828,416.36	38,973,674.70
5/28/2015	46,833,448.53	38,977,862.80
5/29/2015	46,838,481.25	38,982,051.35
5/30/2015	46,843,514.50	38,986,240.36
5/31/2015	46,848,548.29	38,990,429.81
6/1/2015	46,853,582.63	38,994,619.71
6/2/2015	46,858,617.50	38,998,810.07
6/3/2015	46,863,652.92	39,003,000.87
6/4/2015	46,868,688.88	39,007,192.12
6/5/2015	46,873,725.38	39,011,383.83
6/6/2015	46,878,762.42	39,015,575.98
6/7/2015	46,883,800.00	39,019,768.59
6/8/2015	46,888,838.12	39,023,961.64

20

Letter Agreement dated May 1, 2014

6/9/2015	46,893,876.79	39,028,155.15
6/10/2015	46,898,915.99	39,032,349.11
6/11/2015	46,903,955.74	39,036,543.52
6/12/2015	46,908,996.03	39,040,738.37
6/13/2015	46,914,036.86	39,044,933.68
6/14/2015	46,919,078.23	39,049,129.44
6/15/2015	46,924,120.15	39,053,325.65
6/16/2015	46,929,162.60	39,057,522.32
6/17/2015	46,934,205.60	39,061,719.43
6/18/2015	46,939,249.14	39,065,916.99
6/19/2015	46,944,293.22	39,070,115.01
6/20/2015	46,949,337.84	39,074,313.47
6/21/2015	46,954,383.01	39,078,512.39
6/22/2015	46,959,428.72	39,082,711.76
6/23/2015	46,964,474.97	39,086,911.58
6/24/2015	46,969,521.76	39,091,111.85
6/25/2015	46,974,569.09	39,095,312.57
6/26/2015	46,979,616.97	39,099,513.75
6/27/2015	46,984,665.39	39,103,715.37
6/28/2015	46,989,714.35	39,107,917.45
6/29/2015	46,994,763.86	39,112,119.98
6/30/2015	46,999,813.90	39,116,322.96
7/1/2015	47,004,864.49	39,120,526.39
7/2/2015	47,009,915.63	39,124,730.27
7/3/2015	47,014,967.30	39,128,934.61
7/4/2015	47,020,019.52	39,133,139.39
7/5/2015	47,025,072.28	39,137,344.63
7/6/2015	47,030,125.58	39,141,550.32
7/7/2015	47,035,179.43	39,145,756.46
7/8/2015	47,040,233.82	39,149,963.06
7/9/2015	47,045,288.75	39,154,170.11
7/10/2015	47,050,344.23	39,158,377.60
7/11/2015	47,055,400.25	39,162,585.55
7/12/2015	47,060,456.81	39,166,793.96
7/13/2015	47,065,513.92	39,171,002.81
7/14/2015	47,070,571.57	39,175,212.12
7/15/2015	47,075,629.76	39,179,421.88
7/16/2015	46,230,188.12	38,500,142.65
7/17/2015	46,235,156.00	38,504,279.87
7/18/2015	46,240,124.42	38,508,417.53
7/19/2015	46,245,093.37	38,512,555.64
7/20/2015	46,250,062.86	38,516,694.19
7/21/2015	46,255,032.88	38,520,833.18

21

Letter Agreement dated May 1, 2014

7/22/2015	46,260,003.44	38,524,972.62
7/23/2015	46,264,974.53	38,529,112.51
7/24/2015	46,269,946.15	38,533,252.84
7/25/2015	46,274,918.31	38,537,393.61
7/26/2015	46,279,891.00	38,541,534.83
7/27/2015	46,284,864.23	38,545,676.50
7/28/2015	46,289,837.99	38,549,818.61
7/29/2015	46,294,812.29	38,553,961.16
7/30/2015	46,299,787.12	38,558,104.16
7/31/2015	46,304,762.48	38,562,247.61
8/1/2015	46,309,738.38	38,566,391.50
8/2/2015	46,314,714.82	38,570,535.84
8/3/2015	46,319,691.79	38,574,680.62
8/4/2015	46,324,669.29	38,578,825.84
8/5/2015	46,329,647.33	38,582,971.52
8/6/2015	46,334,625.90	38,587,117.63
8/7/2015	46,339,605.01	38,591,264.20
8/8/2015	46,344,584.66	38,595,411.21
8/9/2015	46,349,564.84	38,599,558.66
8/10/2015	46,354,545.55	38,603,706.56
8/11/2015	46,359,526.80	38,607,854.91
8/12/2015	46,364,508.58	38,612,003.70
8/13/2015	46,369,490.90	38,616,152.94
8/14/2015	46,374,473.76	38,620,302.62
8/15/2015	46,379,457.15	38,624,452.75
8/16/2015	46,384,441.08	38,628,603.32
8/17/2015	46,389,425.54	38,632,754.35
8/18/2015	46,394,410.54	38,636,905.81
8/19/2015	46,399,396.07	38,641,057.73
8/20/2015	46,404,382.14	38,645,210.09
8/21/2015	46,409,368.74	38,649,362.89
8/22/2015	46,414,355.88	38,653,516.14
8/23/2015	46,419,343.56	38,657,669.84
8/24/2015	46,424,331.77	38,661,823.99
8/25/2015	46,429,320.52	38,665,978.58
8/26/2015	46,434,309.81	38,670,133.62
8/27/2015	46,439,299.63	38,674,289.10
8/28/2015	46,444,289.98	38,678,445.03
8/29/2015	46,449,280.88	38,682,601.41
8/30/2015	46,454,272.31	38,686,758.23
8/31/2015	46,459,264.27	38,690,915.50
9/1/2015	46,464,256.78	38,695,073.22
9/2/2015	46,469,249.81	38,699,231.38

22

Letter Agreement dated May 1, 2014

9/3/2015	46,474,243.39	38,703,389.99
9/4/2015	46,479,237.50	38,707,549.05
9/5/2015	46,484,232.15	38,711,708.56
9/6/2015	46,489,227.34	38,715,868.51
9/7/2015	46,494,223.06	38,720,028.91
9/8/2015	46,499,219.32	38,724,189.75
9/9/2015	46,504,216.11	38,728,351.05
9/10/2015	46,509,213.45	38,732,512.79
9/11/2015	46,514,211.32	38,736,674.97
9/12/2015	46,519,209.72	38,740,837.61
9/13/2015	46,524,208.67	38,745,000.69
9/14/2015	46,529,208.15	38,749,164.22
9/15/2015	46,534,208.17	38,753,328.20
9/16/2015	46,539,208.72	38,757,492.62
9/17/2015	46,544,209.82	38,761,657.49
9/18/2015	46,549,211.45	38,765,822.81
9/19/2015	46,554,213.62	38,769,988.58
9/20/2015	46,559,216.32	38,774,154.79
9/21/2015	46,564,219.56	38,778,321.46
9/22/2015	46,569,223.34	38,782,488.57
9/23/2015	46,574,227.66	38,786,656.12
9/24/2015	46,579,232.52	38,790,824.13
9/25/2015	46,584,237.91	38,794,992.58
9/26/2015	46,589,243.85	38,799,161.48
9/27/2015	46,594,250.32	38,803,330.83
9/28/2015	46,599,257.32	38,807,500.63
9/29/2015	46,604,264.87	38,811,670.88
9/30/2015	46,609,272.95	38,815,841.57
10/1/2015	46,614,281.58	38,820,012.71
10/2/2015	46,619,290.74	38,824,184.30
10/3/2015	46,624,300.44	38,828,356.34
10/4/2015	46,629,310.67	38,832,528.83
10/5/2015	46,634,321.45	38,836,701.76
10/6/2015	46,639,332.76	38,840,875.15
10/7/2015	46,644,344.62	38,845,048.98
10/8/2015	46,649,357.01	38,849,223.26
10/9/2015	46,654,369.94	38,853,397.99
10/10/2015	46,659,383.40	38,857,573.16
10/11/2015	46,664,397.41	38,861,748.79
10/12/2015	46,669,411.96	38,865,924.87
10/13/2015	46,674,427.04	38,870,101.39
10/14/2015	46,679,442.67	38,874,278.36
10/15/2015	46,684,458.83	38,878,455.78

23

Letter Agreement dated May 1, 2014

10/16/2015	46,689,475.53	38,882,633.65
10/17/2015	46,694,492.77	38,886,811.97
10/18/2015	46,699,510.55	38,890,990.74
10/19/2015	46,704,528.87	38,895,169.96
10/20/2015	46,709,547.73	38,899,349.63
10/21/2015	46,714,567.13	38,903,529.74
10/22/2015	46,719,587.06	38,907,710.31
10/23/2015	46,724,607.54	38,911,891.32
10/24/2015	46,729,628.56	38,916,072.78
10/25/2015	46,734,650.11	38,920,254.70
10/26/2015	46,739,672.21	38,924,437.06
10/27/2015	46,744,694.84	38,928,619.87
10/28/2015	46,749,718.02	38,932,803.13
10/29/2015	46,754,741.73	38,936,986.84
10/30/2015	46,759,765.99	38,941,171.00
10/31/2015	46,764,790.78	38,945,355.61
11/1/2015	46,769,816.11	38,949,540.67
11/2/2015	46,774,841.99	38,953,726.18
11/3/2015	46,779,868.40	38,957,912.14
11/4/2015	46,784,895.36	38,962,098.55
11/5/2015	46,789,922.85	38,966,285.41
11/6/2015	46,794,950.89	38,970,472.72
11/7/2015	46,799,979.46	38,974,660.47
11/8/2015	46,805,008.58	38,978,848.68
11/9/2015	46,810,038.23	38,983,037.34
11/10/2015	46,815,068.43	38,987,226.45
11/11/2015	46,820,099.17	38,991,416.01
11/12/2015	46,825,130.45	38,995,606.02
11/13/2015	46,830,162.26	38,999,796.48
11/14/2015	46,835,194.62	39,003,987.39
11/15/2015	46,840,227.52	39,008,178.75
11/16/2015	46,845,260.96	39,012,370.56
11/17/2015	46,850,294.94	39,016,562.82
11/18/2015	46,855,329.47	39,020,755.53
11/19/2015	46,860,364.53	39,024,948.69
11/20/2015	46,865,400.14	39,029,142.30
11/21/2015	46,870,436.28	39,033,336.37
11/22/2015	46,875,472.97	39,037,530.88
11/23/2015	46,880,510.20	39,041,725.84
11/24/2015	46,885,547.97	39,045,921.26
11/25/2015	46,890,586.28	39,050,117.13
11/26/2015	46,895,625.13	39,054,313.44
11/27/2015	46,900,664.52	39,058,510.21

24

Letter Agreement dated May 1, 2014

11/28/2015	46,905,704.46	39,062,707.43
11/29/2015	46,910,744.93	39,066,905.10
11/30/2015	46,915,785.95	39,071,103.22
12/1/2015	46,920,827.51	39,075,301.79
12/2/2015	46,925,869.61	39,079,500.82
12/3/2015	46,930,912.26	39,083,700.29
12/4/2015	46,935,955.44	39,087,900.22
12/5/2015	46,940,999.17	39,092,100.59
12/6/2015	46,946,043.44	39,096,301.42
12/7/2015	46,951,088.25	39,100,502.70
12/8/2015	46,956,133.61	39,104,704.44
12/9/2015	46,961,179.50	39,108,906.62
12/10/2015	46,966,225.94	39,113,109.25
12/11/2015	46,971,272.92	39,117,312.34
12/12/2015	46,976,320.44	39,121,515.88
12/13/2015	46,981,368.51	39,125,719.87
12/14/2015	46,986,417.12	39,129,924.31
12/15/2015	46,991,466.27	39,134,129.20
12/16/2015	46,996,515.96	39,138,334.55
12/17/2015	47,001,566.19	39,142,540.34
12/18/2015	47,006,616.97	39,146,746.59
12/19/2015	47,011,668.29	39,150,953.29
12/20/2015	47,016,720.16	39,155,160.45
12/21/2015	47,021,772.56	39,159,368.05
12/22/2015	47,026,825.51	39,163,576.11
12/23/2015	47,031,879.01	39,167,784.62
12/24/2015	47,036,933.04	39,171,993.58
12/25/2015	47,041,987.62	39,176,202.99
12/26/2015	47,047,042.74	39,180,412.86
12/27/2015	47,052,098.41	39,184,623.18
12/28/2015	47,057,154.61	39,188,833.95
12/29/2015	47,062,211.37	39,193,045.17
12/30/2015	47,067,268.66	39,197,256.85
12/31/2015	47,072,326.50	39,201,468.98
1/1/2016	47,077,384.88	39,205,681.56
1/2/2016	47,082,443.81	39,209,894.59
1/3/2016	47,087,503.28	39,214,108.08
1/4/2016	47,092,563.29	39,218,322.02
1/5/2016	47,097,623.85	39,222,536.41
1/6/2016	47,102,684.95	39,226,751.26
1/7/2016	47,107,746.59	39,230,966.55
1/8/2016	47,112,808.78	39,235,182.30
1/9/2016	47,117,871.51	39,239,398.51

25

Letter Agreement dated May 1, 2014

1/10/2016	47,122,934.79	39,243,615.17
1/11/2016	47,127,998.61	39,247,832.28
1/12/2016	47,133,062.97	39,252,049.84
1/13/2016	47,138,127.88	39,256,267.86
1/14/2016	47,143,193.33	39,260,486.33

26

Letter Agreement dated May 1, 2014

EX-12.1

Exhibit 12.1
PNM RESOURCES, INC. AND SUBSIDIARIES
Ratio of Earnings to Fixed Charges
(In thousands, except ratio)
	Three Months Ended			Year Ended December 31,
	March 31, 2014			2013				2012			2011				2010				2009
Fixed charges, as defined by the Securities and Exchange Commission:
Interest expensed and capitalized	$	28,683		$	118,880			$	125,379		$	122,998			$	123,633			$	123,833
Amortization of debt premium, discount and expenses	880			3,716				4,023			3,695				4,627				5,430
Interest from discontinued operations (including capitalized interest)	—			—				—			—				—				1,027
Estimated interest factor of lease rental charges	1,481			5,847				5,585			6,665				6,888				7,034
Preferred dividend requirements of subsidiary	185			800				769			864				1,075				759
Total Fixed Charges	$	31,229		$	129,243			$	135,756		$	134,222			$	136,223			$	138,083
Earnings, as defined by the Securities and Exchange Commission:
Earnings (loss) from continuing operations before income taxes and non-controlling interest	$	22,551		$	175,069			$	175,035		$	321,469			$	(63,379	)		$	94,751
(Earnings) loss of equity investee	—			—				—			—				15,223				30,145
Earnings (loss) from continuing operations before income taxes, non-controlling interest, and investee earnings	22,551			175,069				175,035			321,469				(48,156		)		124,896
Fixed charges as above	31,229			129,243				135,756			134,222				136,223				138,083
Interest capitalized	(1,316		)	(5,209		)		(5,432		)	(2,697		)		(3,401		)		(7,743		)
Non-controlling interest in earnings of Valencia	(3,531		)	(14,521		)		(14,050		)	(14,047		)		(13,563		)		(11,890		)
Preferred dividend requirements of subsidiary	(185		)	(800		)		(769		)	(864		)		(1,075		)		(759		)
Earnings Available for Fixed Charges	$	48,748		$	283,782			$	290,540		$	438,083			$	70,028			$	242,587
Ratio of Earnings to Fixed Charges	1.56			2.20			1	2.14			3.26			2	0.51			3	1.76
1  Earnings (loss) from continuing operations before income taxes and non-controlling interest for the year ended December 31, 2013 includes a pre-tax loss of $12.2 million due to the write-off of regulatory disallowances at PNM. If those losses were excluded, the Ratio of Earnings to Fixed Charges would have been 2.29.
2  Earnings (loss) from continuing operations before income taxes and non-controlling interest for the year ended December 31, 2011 includes a pre-tax loss of $21.4 million due to the write-off of regulatory disallowances at PNM and TNMP. If those losses were excluded, the Ratio of Earnings to Fixed Charges would have been 3.42. In addition, 2011 includes a pre-tax gain on the sale of First Choice of $174.9 million. If that gain were also excluded, the Ratio of Earnings to Fixed Charges would have been 1.96.
3 The shortfall in the earnings available for fixed charges to achieve a ratio of earnings to fixed charges of 1.00 amounted to $66.2 million for the year ended December 31, 2010. Earnings (loss) from continuing operations before income taxes and non-controlling interest includes a pre-tax loss of $188.2 million due to the impairment of PNMR's investment in an equity investee. If that loss were excluded, the Ratio of Earnings to Fixed Charges would have been 1.90.

EX-12.2

Exhibit 12.2
PUBLIC SERVICE COMPANY OF NEW MEXICO
Ratio of Earnings to Fixed Charges
(In thousands, except ratio)
	Three Months Ended			Year Ended December 31,
	March 31, 2014			2013				2012			2011				2010			2009
Fixed charges, as defined by the Securities and Exchange Commission:
Interest expensed and capitalized	$	19,768		$	79,769			$	82,864		$	75,217			$	73,423		$	73,104
Amortization of debt premium, discount and expenses	465			1,879				1,818			1,325				1,274			1,336
Interest from discontinued operations (including capitalized interest)	—			—				—			—				—			1,027
Estimated interest factor of lease rental charges	882			3,732				3,743			4,139				4,103			4,517
Total Fixed Charges	$	21,115		$	85,380			$	88,425		$	80,681			$	78,800		$	79,984
Earnings, as defined by the Securities and Exchange Commission:
Earnings from continuing operations before income taxes and non-controlling interest	$	15,288		$	151,480			$	156,314		$	105,965			$	107,288		$	45,627
Fixed charges as above	21,115			85,380				88,425			80,681				78,800			79,984
Non-controlling interest in earnings of Valencia	(3,531		)	(14,521		)		(14,050		)	(14,047		)		(13,563		)	(11,890		)
Interest capitalized	(1,099		)	(4,420		)		(4,314		)	(1,761		)		(2,811		)	(6,067		)
Earnings Available for Fixed Charges	$	31,773		$	217,919			$	226,375		$	170,838			$	169,714		$	107,654
Ratio of Earnings to Fixed Charges	1.50			2.55			1	2.56			2.12			2	2.15			1.35
1 Earnings (loss) from continuing operations before income taxes and non-controlling interest for the year ended December 31, 2013 includes a pre-tax loss $12.2 million due to the write-off of regulatory disallowances. If those losses were excluded, the Ratio of Earnings to Fixed Charges would have been 2.70.
2 Earnings (loss) from continuing operations before income taxes and non-controlling interest for the year ended December 31, 2011 includes a pre-tax loss $17.5 million due to the write-off of regulatory disallowances. If that loss were excluded, the Ratio of Earnings to Fixed Charges would have been 2.33.

EX-12.3

Exhibit 12.3
TEXAS-NEW MEXICO POWER COMPANY
Ratio of Earnings to Fixed Charges
(In thousands, except ratio)
	Three Months Ended			Year Ended December 31,
	March 31, 2014			2013			2012			2011				2010			2009
Fixed charges, as defined by the Securities and Exchange Commission:
Interest expensed and capitalized	$	5,838		$	24,481		$	26,233		$	27,914			$	28,632		$	25,609
Amortization of debt premium, discount and expenses	250			1,159			1,493			1,679				2,683			3,355
Estimated interest factor of lease rental charges	323			1,241			956			1,202				1,246			831
Total Fixed Charges	$	6,411		$	26,881		$	28,682		$	30,795			$	32,561		$	29,795
Earnings, as defined by the Securities and Exchange Commission:
Earnings from continuing operations before income taxes	$	10,853		$	46,711		$	42,099		$	36,138			$	26,026		$	20,151
Fixed charges as above	6,411			26,881			28,682			30,795				32,561			29,795
Interest capitalized	(100		)	(361		)	(706		)	(593		)		(158		)	(1,144		)
Earnings Available for Fixed Charges	$	17,164		$	73,231		$	70,075		$	66,340			$	58,429		$	48,802
Ratio of Earnings to Fixed Charges	2.68			2.72			2.44			2.15			1	1.79			1.64
1 Earnings from continuing operations before income taxes for the year ended December 31, 2011 includes a pre-tax loss of $3.9 million due to the write-off of regulatory disallowances. If that loss were excluded, the Ratio of Earnings to Fixed Charges would have been 2.28.

EX-31.1

PNM Resources

414 Silver Ave. SW

Albuquerque, NM 87102-3289

EXHIBIT 31.1

CERTIFICATION

I, Patricia K. Collawn, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:	May 2, 2014	By:	/s/ Patricia K. Collawn
			Patricia K. Collawn
			President and Chief Executive Officer
			PNM Resources, Inc.

EX-31.2

PNM Resources

414 Silver Ave. SW

Albuquerque, NM 87102-3289

EXHIBIT 31.2

CERTIFICATION

I, Charles N. Eldred, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:	May 2, 2014	By:	/s/ Charles N. Eldred
			Charles N. Eldred
			Executive Vice President and
			Chief Financial Officer
			PNM Resources, Inc.

EX-31.3

Public Service Company of New Mexico

414 Silver Ave. SW

Albuquerque, NM 87102-3289

EXHIBIT 31.3

CERTIFICATION

I, Patricia K. Collawn, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:	May 2, 2014	By:	/s/ Patricia K. Collawn
			Patricia K. Collawn
			President and Chief Executive Officer
			Public Service Company of New Mexico

EX-31.4

Public Service Company of New Mexico

414 Silver Ave. SW

Albuquerque, NM 87102-3289

EXHIBIT 31.4

CERTIFICATION

I, Charles N. Eldred, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:	May 2, 2014	By:	/s/ Charles N. Eldred
			Charles N. Eldred
			Executive Vice President and
			Chief Financial Officer
			Public Service Company of New Mexico

EX-31.5

Texas-New Mexico Power Company

577 N. Garden Ridge Blvd.

Lewisville, Texas 75067

EXHIBIT 31.5

CERTIFICATION

I, Patricia K. Collawn, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:	May 2, 2014	By:	/s/ Patricia K. Collawn
			Patricia K. Collawn
			Chief Executive Officer
			Texas-New Mexico Power Company

EX-31.6

Texas-New Mexico Power Company

577 N. Garden Ridge Blvd.

Lewisville, Texas 75067

EXHIBIT 31.6

CERTIFICATION

I, Thomas G. Sategna, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:	May 2, 2014	By:	/s/ Thomas G. Sategna
			Thomas G. Sategna
			Vice President and Controller
			Texas-New Mexico Power Company

EX-32.1

PNM Resources

414 Silver Ave. SW

Albuquerque, NM 87102-3289

www.pnmresources.com

EXHIBIT 32.1

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

SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q for the period ended March 31, 2014, for PNM Resources, Inc. (“Company”), as filed with the Securities and Exchange Commission on May 2, 2014 (“Report”), each of the undersigned officers of the Company certifies, pursuant to 18 U.S.C. §1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that:

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

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

Date:	May 2, 2014	By:	/s/ Patricia K. Collawn
			Patricia K. Collawn
			President and Chief Executive Officer
			PNM Resources, Inc.
		By:	/s/ Charles N. Eldred
			Charles N. Eldred
			Executive Vice President and
			Chief Financial Officer

EX-32.2

Public Service Company of New Mexico

414 Silver Ave. SW

Albuquerque, NM 87102-3289

EXHIBIT 32.2

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

SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q for the period ended March 31, 2014, for Public Service Company of New Mexico (“Company”), as filed with the Securities and Exchange Commission on May 2, 2014 (“Report”), each of the undersigned officers of the Company certifies, pursuant to 18 U.S.C. §1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that:

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

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

Date:	May 2, 2014	By:	/s/ Patricia K. Collawn
			Patricia K. Collawn
			President and Chief Executive Officer
			Public Service Company of New Mexico
		By:	/s/ Charles N. Eldred
			Charles N. Eldred
			Executive Vice President and
			Chief Financial Officer

EX-32.3

Texas-New Mexico Power Company

577 N. Garden Ridge Blvd.

Lewisville, Texas 75067

EXHIBIT 32.3

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

SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q for the period ended March 31, 2014, for Texas-New Mexico Power Company (“Company”), as filed with the Securities and Exchange Commission on May 2, 2014 (“Report”), each of the undersigned officers of the Company certifies, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

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

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

Date:	May 2, 2014	By:	/s/ Patricia K. Collawn
			Patricia K. Collawn
			Chief Executive Officer
			Texas-New Mexico Power Company
		By:	/s/ Thomas G. Sategna
			Thomas G. Sategna
			Vice President and Controller
			Texas-New Mexico Power Company

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Fair Value of Derivative and Other Financial Instruments, Statement of Earnings Information (Details) (PNMR and PNM [Member], Commodity Contract [Member], Fair Value Hedging [Member], USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss)	$ (3,962)	$ (3,847)
Electric operating revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss)	(4,151)	(4,603)
Cost of energy [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss)	$ 189	$ 756

XML

Commitments and Contingencies (Commitments and Contingencies Related to the Environment) (Details) (USD $) In Millions, unless otherwise specified										0 Months Ended	4 Months Ended								3 Months Ended			3 Months Ended							3 Months Ended		12 Months Ended
	Dec. 21, 2011 mw	Dec. 21, 2011 San Juan Generating Station [Member]	Oct. 31, 2012 San Juan Generating Station [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 San Juan Generating Station Units 1 and 4 [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 San Juan Generating Station Units 2 and 3 [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 San Juan Generating Station Units 2 and 3 [Member] PNM Electric [Member]	Mar. 31, 2014 Palo Verde Nuclear Generating Station Unit 3 [Member] PNMR and PNM [Member] MW	Mar. 31, 2014 Clean Air Act related to Regional Haze [Member] state	Dec. 20, 2013 Clean Air Act, SNCR [Member] San Juan Generating Station [Member] Public Service Company of New Mexico [Member] MW	Dec. 20, 2013 Clean Air Act, SNCR [Member] San Juan Generating Station Units 2 and 3 [Member] Public Service Company of New Mexico [Member] MW	Apr. 30, 2014 Clean Air Act, SNCR [Member] San Juan Generating Station Units 2 and 3 [Member] Public Service Company of New Mexico [Member]	Dec. 20, 2013 Clean Air Act, SNCR [Member] Palo Verde Nuclear Generating Station Unit 3 [Member] PNMR and PNM [Member] MW	Mar. 31, 2014 Clean Air Act, SNCR [Member] San Juan Generating Station Unit 3 [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 Clean Air Act, SNCR [Member] San Juan Generating Station Unit 4 [Member] Public Service Company of New Mexico [Member] MW	Dec. 20, 2013 Clean Air Act, SNCR [Member] San Juan Generating Station Unit 4 [Member] Public Service Company of New Mexico [Member] MW	Mar. 31, 2014 Clean Air Act Related to Post Combustion Controls [Member] Four Corners [Member] Public Service Company of New Mexico [Member]	Aug. 06, 2012 Clean Air Act Related to Post Combustion Controls [Member] Four Corners [Member] Public Service Company of New Mexico [Member] compliance_alternative	Mar. 31, 2014 Clean Air Act Related to Post Combustion Controls [Member] Four Corners Units 4 and 5 (Coal) [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 Mercury Control [Member] San Juan Generating Station [Member] Public Service Company of New Mexico [Member]	Jan. 31, 2010 Minimum [Member] San Juan Generating Station And Four Corners [Member] Public Service Company of New Mexico [Member] opp	Jan. 31, 2010 Maximum [Member] San Juan Generating Station And Four Corners [Member] Public Service Company of New Mexico [Member] opp	Mar. 31, 2014 Maximum [Member] Mercury Control [Member] San Juan Generating Station [Member] Public Service Company of New Mexico [Member]	Oct. 31, 2012 Installation Costs Including Construction Management, Gross Receipts Taxes, AFUDC, and Other PNM Costs [Member] Minimum [Member] Clean Air Act, SNCR [Member] San Juan Generating Station [Member] Public Service Company of New Mexico [Member]	Oct. 31, 2012 Installation Costs Including Construction Management, Gross Receipts Taxes, AFUDC, and Other PNM Costs [Member] Minimum [Member] Clean Air Act, SCR [Member] [Member] San Juan Generating Station [Member] Public Service Company of New Mexico [Member]	Oct. 31, 2012 Installation Costs Including Construction Management, Gross Receipts Taxes, AFUDC, and Other PNM Costs [Member] Maximum [Member] Clean Air Act, SNCR [Member] San Juan Generating Station [Member] Public Service Company of New Mexico [Member]	Mar. 11, 2014 Installation Costs Including Construction Management, Gross Receipts Taxes, AFUDC, and Other PNM Costs [Member] Maximum [Member] Clean Air Act, SNCR [Member] San Juan Generating Station Units 1 and 4 [Member] Public Service Company of New Mexico [Member]	Dec. 20, 2013 Installation Costs Including Construction Management, Gross Receipts Taxes, AFUDC, and Other PNM Costs [Member] Maximum [Member] Clean Air Act, SNCR [Member] San Juan Generating Station Units 1 and 4 [Member] Public Service Company of New Mexico [Member]	Oct. 31, 2012 Installation Costs Including Construction Management, Gross Receipts Taxes, AFUDC, and Other PNM Costs [Member] Maximum [Member] Clean Air Act, SCR [Member] [Member] San Juan Generating Station [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 Environmental Protection Agency [Member] WildEarth Guardians filed an action to challenge EPA's rule in the Tenth Circuit [Member] San Juan Generating Station [Member]	Mar. 31, 2014 Environmental Protection Agency [Member] Clean Air Act Related to Post Combustion Controls [Member] Four Corners [Member] Public Service Company of New Mexico [Member]	Dec. 31, 2013 Nuclear Spent Fuel And Waste Disposal [Member] Palo Verde Nuclear Generating Station [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 Nuclear Spent Fuel And Waste Disposal [Member] Palo Verde Nuclear Generating Station [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 Nuclear Spent Fuel And Waste Disposal [Member] Other Deferred Credits [Member] Palo Verde Nuclear Generating Station [Member] Public Service Company of New Mexico [Member]	Dec. 31, 2013 Nuclear Spent Fuel And Waste Disposal [Member] Other Deferred Credits [Member] Palo Verde Nuclear Generating Station [Member] Public Service Company of New Mexico [Member]
Public Utilities, Commitments and Contingencies [Line Items]
Public Utilities, Requested Time Period to Recover Retired Units NBV										20 years
Loss Contingency, Estimate of Possible Loss																$ 80.3																$ 58.0
Public Utilities, Number of Compliance alternatives																	2
Public Utilities, Ownership Percentage													50.00%	39.00%				13.00%
Public Utilities, Plant Requirement to Meet NOx emissions Limit																0.015
Public Utilities, Number of States To Address Regional Haze								50
Public Utilities, Potential to emit tons per year of visibility impairing pollution, maximum								250
Estimated Total Capital Cost If Requirement Occurred																								824				910
Estimated Installation Capital Costs																							85.0		90.0		82.0
Estimated Portion of Total Capital Costs if Requirement Occurred																							105		110
Jointly Owned Utility Plant, Proportionate Ownership Share			46.30%	52.00%
estimated cost of replacing gas fired peaking capacity due to retirement of SJGS units						276.3
Percentage of ownership held by exiting owners													50.00%	39.00%
Net book value					286
Public Utilities, Time Period from completed application to EPA Proposed Action											135 days
Public Utilities, Government Standard Emission Limit																				0.060	0.070
Public Utilities, Plant Requirement to Meet Opacity Limit, Percentage																20.00%
Public Utilities, Rule Imposes Opacity Limitation on Certain Fugitive Dust Emissions From Coal and Material Handling Operations																20.00%
Current Annual Mercury Control Costs																			0.7
Contingent Estimated Annual Mercury Control Cost																						6.6
Minimum Megawatt Capacity from Coal and Oil-Fired Electric Generating Units under Jurisdiction of the Mercury and Air Toxics Standards	25
Mercury Removal Rate, Percentage		99.00%
Public Utilities, Proposed Seeking Shorter Compliance Period																													5 years
Public Utilities, Number of years after issuance of final determination to achieve compliance with requirements																														3 years
Loss Contingency Accrual, at Carrying Value																																	12.0	11.9
Annual Fee, Nuclear Waste Disposal																															3.0
Public Utilities, Expected NBV of Units at Retirement										205
Public Utilities, Number of Megawatts Nuclear Generation							134					134
Public Utilities, Proposed value per Kilowatt effective January 1, 2018												2,500
Public Utilities, Additional Ownership To Be Obtained, in Megawatts														78	78
Requested Expenditure, Installation Capital Costs																										$ 1.9
Public Utilities, Overall Reduction Of Ownership, in Megawatts									340
Public Utilities, Newly Identified Replacement Gas-fired Generation, in Megawatts, December2013										177
Public Utilities, Newly Identified Replacement Solar Generation, in Megawatts, December2013										40

XML

Financing, Financing Activities (Details) (USD $)												0 Months Ended			0 Months Ended
	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014 Public Service Company of New Mexico [Member]	Dec. 31, 2013 Public Service Company of New Mexico [Member]	Mar. 31, 2014 Local Lines of Credit [Member] Public Service Company of New Mexico [Member]	Oct. 02, 2013 Local Lines of Credit [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2013 Local Lines of Credit [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 PNMR Term Loan Agreement [Member]	Dec. 31, 2013 PNMR Term Loan Agreement [Member]	Mar. 31, 2014 PNM 2014 Term Loan Agreement [Member] Public Service Company of New Mexico [Member]	Mar. 05, 2014 PNM 2014 Term Loan Agreement [Member] Public Service Company of New Mexico [Member]	Sep. 30, 2011 2011 Term Loan Agreement, First Mortgage Bonds Due 2014 [Member] Texas-New Mexico Power Company [Member]	Dec. 09, 2013 Bonds [Member] First Mortgage Bonds Due 2024, Series 2014A, at 4 point 03 percent [Member] [Member] Texas-New Mexico Power Company [Member]	Mar. 06, 2013 First Mortgage Bonds [Member] First Mortgage Bonds, due 2043, Series 2013A [Member] Texas-New Mexico Power Company [Member]	Sep. 30, 2011 Notes Payable to Banks [Member] Texas-New Mexico Power Company [Member]	Apr. 22, 2013 Notes Payable to Banks [Member] PNM Term Loan Agreement [Member]
Debt Instrument [Line Items]
Long-term Debt											$ 175,000,000
Debt Instrument, Face Amount													80,000,000
Debt Instrument, Interest Rate, Stated Percentage													4.03%
Proceeds from Bank Debt												50,000,000			50,000,000
Debt Instrument, Cash for Bond Exchange Conversion														0.14
Short-term debt	100,000,000	149,200,000	0	49,200,000	0		0	100,000,000	100,000,000							75,000,000
Debt Instrument, Interest Rate at Period End										1.11%
Debt Instruments, NMPRC Approved credit facility						$ 50,000,000

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Earnings Per Share (Details) (USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2014		Mar. 31, 2013
Earnings Per Share [Abstract]
Net Earnings Attributable to PNMR	$ 12,468		$ 10,626
Average Number of Common Shares:
Outstanding during period	79,654,000		79,654,000
Vested awards of restricted stock	182,000		211,000
Average Shares - Basic	79,836,000		79,865,000
Dilutive Effect of Common Stock Equivalents:
Stock options and restricted stock	551,000	[1]	715,000	[1]
Average Shares - Diluted	80,387,000		80,580,000
Net Earnings Per Share of Common Stock
Basic (dollars per share)	$ 0.16		$ 0.13
Diluted (dollars per share)	$ 0.16		$ 0.13
Share Based Compensation Arrangement by Share Based Payment Award Options Outstanding Shares Above Entities Stock Price (in shares)	486,016

[1] Excludes the effect of out-of-the-money options for 486,016 shares of common stock at March 31, 2014.

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Segment Information (Tables)

3 Months Ended

Mar. 31, 2014

Segment Reporting [Abstract]

Schedule of Segment Reporting Information, by Segment

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

PNMR SEGMENT INFORMATION

	PNM			TNMP			Corporate and Other			Consolidated
Three Months Ended March 31, 2014	(In thousands)
Electric operating revenues	$	262,736		$	66,161		$	—		$	328,897
Cost of energy	96,626			15,988			—			112,614
Margin	166,110			50,173			—			216,283
Other operating expenses	107,724			21,069			(3,228		)	125,565
Depreciation and amortization	27,082			11,842			3,041			41,965
Operating income	31,304			17,262			187			48,753
Interest income	2,128			—			(11		)	2,117
Other income (deductions)	1,668			189			(641		)	1,216
Net interest charges	(19,812		)	(6,598		)	(3,125		)	(29,535		)
Segment earnings (loss) before income taxes	15,288			10,853			(3,590		)	22,551
Income taxes (benefit)	4,083			4,050			(1,713		)	6,420
Segment earnings (loss)	11,205			6,803			(1,877		)	16,131
Valencia non-controlling interest	(3,531		)	—			—			(3,531		)
Subsidiary preferred stock dividends	(132		)	—			—			(132		)
Segment earnings (loss) attributable to PNMR	$	7,542		$	6,803		$	(1,877	)	$	12,468
At March 31, 2014:
Total Assets	$	4,219,635		$	1,173,028		$	114,363		$	5,507,026
Goodwill	$	51,632		$	226,665		$	—		$	278,297

	PNM			TNMP			Corporate and Other			Consolidated
Three Months Ended March 31, 2013	(In thousands)
Electric operating revenues	$	257,894		$	59,771		$	—		$	317,665
Cost of energy	91,660			13,046			—			104,706
Margin	166,234			46,725			—			212,959
Other operating expenses	103,161			21,990			(3,703		)	121,448
Depreciation and amortization	25,834			11,681			3,292			40,807
Operating income	37,239			13,054			411			50,704
Interest income	2,673			—			(39		)	2,634
Other income (deductions)	1,407			208			(1,725		)	(110		)
Net interest charges	(19,957		)	(7,246		)	(4,094		)	(31,297		)
Segment earnings (loss) before income taxes	21,362			6,016			(5,447		)	21,931
Income taxes (benefit)	6,589			2,290			(910		)	7,969
Segment earnings (loss)	14,773			3,726			(4,537		)	13,962
Valencia non-controlling interest	(3,204		)	—			—			(3,204		)
Subsidiary preferred stock dividends	(132		)	—			—			(132		)
Segment earnings (loss) attributable to PNMR	$	11,437		$	3,726		$	(4,537	)	$	10,626
At March 31, 2013:
Total Assets	$	4,155,257		$	1,098,942		$	116,561		$	5,370,760
Goodwill	$	51,632		$	226,665		$	—		$	278,297

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Regulatory and Rate Matters (Details) (USD $)											3 Months Ended			0 Months Ended	3 Months Ended		12 Months Ended	3 Months Ended			3 Months Ended	1 Months Ended	3 Months Ended	0 Months Ended			12 Months Ended		1 Months Ended				0 Months Ended		1 Months Ended	3 Months Ended
	Mar. 31, 2014 Public Service Company of New Mexico [Member] La Luz Generating Station [Member] MW	Mar. 31, 2014 Public Service Company of New Mexico [Member] Renewable Portfolio Standard [Member] Maximum [Member]	Mar. 31, 2013 Public Service Company of New Mexico [Member] Renewable Portfolio Standard [Member] Maximum [Member]	Dec. 31, 2013 Public Service Company of New Mexico [Member] Renewable Portfolio Standard [Member] Wind Energy [Member] Minimum [Member]	Dec. 31, 2013 Public Service Company of New Mexico [Member] Renewable Portfolio Standard [Member] Solar Energy [Member] Minimum [Member]	Dec. 31, 2013 Public Service Company of New Mexico [Member] Renewable Portfolio Standard [Member] Renewable Technologies [Member] Minimum [Member]	Dec. 31, 2013 Public Service Company of New Mexico [Member] Renewable Portfolio Standard [Member] Distributed Generation [Member] Minimum [Member]	Mar. 31, 2014 Public Service Company of New Mexico [Member] Renewable Portfolio Standard [Member] Required Percentage by 2011 [Member]	Mar. 31, 2014 Public Service Company of New Mexico [Member] Renewable Portfolio Standard [Member] Required Percentage by 2015 [Member]	Mar. 31, 2014 Public Service Company of New Mexico [Member] Renewable Portfolio Standard [Member] Required Percentage by 2020 [Member]	Mar. 31, 2014 Public Service Company of New Mexico [Member] 2014 Wind generated Renewable Energy Credits [Member] MWh	Mar. 31, 2014 Public Service Company of New Mexico [Member] Renewable Portfolio Standard 2014 [Member] MW	Mar. 31, 2014 Public Service Company of New Mexico [Member] 2015 Wind generated Renewable Energy Credits [Member] MWh	Oct. 05, 2012 Public Service Company of New Mexico [Member] 2010 Energy Efficiency Application [Member] Disincentives / Incentives Adder [Member]	Mar. 31, 2014 Public Service Company of New Mexico [Member] 2010 Energy Efficiency Application [Member] Disincentives / Incentives Adder [Member]	Mar. 31, 2014 Public Service Company of New Mexico [Member] 2010 Electric Rate Case [Member]	Dec. 31, 2013 Public Service Company of New Mexico [Member] FPPAC Continuation Application [Member]	Mar. 31, 2014 Public Service Company of New Mexico [Member] Renewable Energy Rider [Member]	Apr. 25, 2014 Public Service Company of New Mexico [Member] Renewable Energy Rider [Member]	Jan. 02, 2014 Public Service Company of New Mexico [Member] Renewable Energy Rider [Member]	Mar. 31, 2014 Public Service Company of New Mexico [Member] Renewable Energy Rider [Member] Maximum [Member]	Jul. 31, 2011 Public Service Company of New Mexico [Member] Integrated Resource Plan, 2011 [Member]	Mar. 31, 2014 Public Service Company of New Mexico [Member] Integrated Resource Plan, 2011 [Member]	May 02, 2014 Public Service Company of New Mexico [Member] Formula Transmission Rate Case [Member]	Jun. 03, 2013 Public Service Company of New Mexico [Member] Formula Transmission Rate Case [Member]	Mar. 31, 2014 Public Service Company of New Mexico [Member] Formula Transmission Rate Case [Member]	Dec. 31, 2013 Public Service Company of New Mexico [Member] City of Gallup, New Mexico Contract [Member]	Mar. 31, 2014 Public Service Company of New Mexico [Member] City of Gallup, New Mexico Contract [Member]	Jul. 30, 2011 Texas-New Mexico Power Company [Member] Advanced Meter System Deployment and Surcharge Request [Member]	Mar. 31, 2014 Texas-New Mexico Power Company [Member] Advanced Meter System Deployment and Surcharge Request [Member]	Mar. 31, 2014 Texas-New Mexico Power Company [Member] Advanced Meter System Deployment and Surcharge Request [Member] Minimum [Member]	Mar. 31, 2014 Texas-New Mexico Power Company [Member] Advanced Meter System Deployment and Surcharge Request [Member] Maximum [Member]	Aug. 28, 2012 Texas-New Mexico Power Company [Member] Energy Efficiency [Member]	Mar. 31, 2014 Texas-New Mexico Power Company [Member] Energy Efficiency [Member]	Jan. 31, 2013 Texas-New Mexico Power Company [Member] Transmission Rate Filings [Member]	Mar. 31, 2014 Texas-New Mexico Power Company [Member] August 2013 Transmission Rate Filings [Member]	Mar. 31, 2014 Texas-New Mexico Power Company [Member] January 2014 Transmission Rate Filings [Member]	Mar. 31, 2014 Delta [Member] Public Service Company of New Mexico [Member] Applications for Approvals to Purchase Delta [Member] MW	Mar. 31, 2014 Clean Air Act, SNCR [Member] San Juan Generating Station Unit 4 [Member] Public Service Company of New Mexico [Member] MW	Dec. 20, 2013 Clean Air Act, SNCR [Member] San Juan Generating Station Unit 4 [Member] Public Service Company of New Mexico [Member] MW
Rate Matters [Line Items]
Public Utilities, Required Percentage of Renewable Energy in Portfolio to Electric Sales								10.00%	15.00%	20.00%
Public Utilities, Required Percentage of Diversification				30.00%	20.00%	5.00%	1.50%
Public Utilities, Reasonable Cost Threshold		3.00%	3.00%
Public Utilities, Number of Mega Watts of Solar PV Capacity												23
Public Utilities, Number of Mega Watts of Wind Energy Capacity												102
Public Utilities, First Year Cost of Wind Capacity Planned Purchase Agreement												$ 5,800,000.0
Public Utilities, Number of Mega Watt Hours of Wind Generation											50,000		120,000
Public Utilities, Requested Rider Rate For 2014																			0.0045959	0.0044391
Public Utilities, Annual Revenue To be Collected Under Current Rider Rate																					34,600,000
Public Utilities, Estimated Cost of Mega Watts of Solar PV Capacity												46,700,000
Public Utilities, Wind Capacity Planned Purchase Agreement Term												20 years
Public Utilities, Program Costs Related To Energy Efficiency														22,500,000
Public Utilities, Approved Profit Incentive Adder Revenues Related To Energy Efficiency Program, Percentage of Program Costs															7.60%
Public Utilities, Approved Profit Incentive Adder Revenues Related To Energy Efficiency Program															1,700,000
Percentage ownership of EIP transmission line																										60.00%
Public Utilities, Rider Condition of Earned Return on Jurisdictional Equity in 2013																					10.50%
Public Utilities, Rate Rider to be Implemented																		0.0030468
Public Utilities, Approved Rider Rate For 2013																		0.0028371
Public Utilities, Planning Period Covered of IRP																						20 years
Amount of Regulatory Costs Not yet Approved																										3,200,000
Public Utilities, Requested Rate Increase (Decrease), Amount																								500,000	1,300,000
Public Utilities, Number of Mega Watts Natural Gas Peaking Units to be Purchased																																						132
Public Utilities, Number of Mega Watts of Gas-fired Generation	40
Estimated Installation Capital Costs	63,200,000
Public Utilities, Rate Base Value	56,000,000
Public Utilities, Additional Ownership To Be Obtained, in Megawatts																																							78	78
Public Utilities, Return on Equity																										10.81%
Public Utilities, Collection of Deployment Costs Through Surcharge Period																													12 years
Public Utilities, Completion Period of Advanced Meter Deployment																													5 years
Public Utilities, Non-standard metering service cost total to be borne by opt-out customers																														0
Public Utilities, Non-standard metering service cost initial fee range																															142.84	247.48
Public Utilities, Non-standard metering ongoing expenses total to be borne by opt-out customers																														500,000
Public Utilities, Non-standard metering ongoing expenses monthly charge																														38.99
Public Utilities, Additional Revenue from Proposed Rates																																			21,900,000	18,100,000	18,200,000
Public Utilities, Total Revenue Requirement Increase																																			2,900,000	2,800,000	2,900,000
Public Utilities, Estimated Increase in Revenue over amendment term																												3,100,000
Public Utilities, Revenue For Power Sold Under Specific Contract																											11,700,000
Public Utilities, Approved Deployment Costs																													113,300,000
Public Utilities, Approved Program Implementation Costs, Bonus																																	5,200,000
Public Utilities, Unapproved 2014 Program Implementation Costs																																		5,600,000
Public Utilities, Retention Percentage of Sales Margins																10.00%
Public Utilities, Under-collected balance write-off																	$ 10,500,000
Public Utilities, Frequency of IRP filings																							3 years

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Fair Value of Derivative and Other Financial Instruments, Debt Maturities (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2014
PNM Resources [Member]
Held-to-maturity Securities, Debt Maturities, Fair Value, Fiscal Year Maturity [Abstract]
Held-to-maturity debt securities, Due within 1 year	$ 11,968
Held-to-maturity debt securities, After 1 year through 5 years	33,618
Held-to-maturity debt securities, After 5 years through 10 years	0
Held-to-maturity debt securities	45,586
Public Service Company of New Mexico [Member]
Held-to-maturity Securities, Debt Maturities, Fair Value, Fiscal Year Maturity [Abstract]
Held-to-maturity debt securities, Due within 1 year	11,968
Held-to-maturity debt securities, After 1 year through 5 years	32,903
Held-to-maturity debt securities, After 5 years through 10 years	0
Held-to-maturity debt securities	44,871
PNMR and PNM [Member]
Available-for-sale Securities, Debt Maturities, Fair Value, Fiscal Year Maturity [Abstract]
Available-for-sale debt securities, Within 1 year	2,798
Available-for-sale debt securities, After 1 year through 5 years	21,550
Available-for-sale debt securities, After 5 years through 10 years	11,895
Available-for-sale debt securities, After 10 years through 15 years	8,521
Available-for-sale debt securities, After 15 years through 20 years	10,705
Available-for-sale debt securities, After 20 years	37,699
Available-for-sale debt securities	$ 93,168

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Lease Commitments (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2014 Public Service Company of New Mexico [Member]	Mar. 31, 2014 Public Service Company of New Mexico [Member] Palo Verde Nuclear Generating Station [Member]	Feb. 25, 2014 Public Service Company of New Mexico [Member] Palo Verde Nuclear Generating Station, Unit 2 Leases 31.2494 MW [Member]	Jan. 15, 2016 Public Service Company of New Mexico [Member] Palo Verde Nuclear Generating Station, Unit 2 Leases [Member] MW	May 01, 2014 Subsequent Event [Member] Public Service Company of New Mexico [Member] Palo Verde Nuclear Generating Station, Unit 2 Leases [Member] MW	May 01, 2014 Subsequent Event [Member] Public Service Company of New Mexico [Member] Palo Verde Nuclear Generating Station, Unit 2 Leases 32.76 MW [Member]	May 01, 2014 Subsequent Event [Member] Maximum [Member] Public Service Company of New Mexico [Member] Palo Verde Nuclear Generating Station, Unit 2 Leases 32.76 MW [Member]
Operating Leased Assets [Line Items]
Rental Payments, Fixed renewal option period during original terms of leases			50.00%
Purchase Price of Leased Asset to be paid January 15, 2016				$ 78.1			$ 85.2
Leased Capacity to be Purchased					31.2494	32.7600
Early Purchase Price of Leased Asset effective June 1, 2014							79.9
Additional consideration for early purchase of leased asset effective June 1, 2014								$ 5.8
Operating Lease, Extended Term	2 years
Operating Leases, Renewal Options After Original Lease Term (in years)	6 years	2 years

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Related Party Transactions (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Service billings [Member] | TNMP to PNMR [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	$ 0	$ 2
Service billings [Member] | PNMR to PNM [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	21,066	22,652
Service billings [Member] | PNMR to TNMP [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	7,261	7,361
Service billings [Member] | PNM to TNMP [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	109	108
Interest charges [Member] | PNMR to PNM [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	53	1
Interest charges [Member] | PNMR to TNMP [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	96	96
Interest charges [Member] | PNM to PNMR [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	26	41
Income tax sharing payments [Member] | PNMR to PNM [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	0	0
Income tax sharing payments [Member] | PNMR to TNMP [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	$ 0	$ 0

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Pension and Other Postretirement Benefit Plans (Details) (USD $)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Public Service Company of New Mexico [Member] | Pension Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	$ 0	$ 0
Interest cost	7,541,000	7,035,000
Long-term return on plan assets	(9,511,000)	(10,482,000)
Amortization of net loss	3,255,000	3,710,000
Amortization of prior service cost	(241,000)	19,000
Net periodic benefit cost	1,044,000	282,000
Defined Benefit Plan, Contributions by Employer		60,000,000
Defined Benefit Plan, Estimated Future Employer Contributions After Current Fiscal Year	61,500,000
Public Service Company of New Mexico [Member] | Pension Plan [Member] | Minimum [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate (as a percent)	5.20%
Public Service Company of New Mexico [Member] | Pension Plan [Member] | Maximum [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate (as a percent)	5.50%
Public Service Company of New Mexico [Member] | OPEB [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	45,000	65,000
Interest cost	1,159,000	1,028,000
Long-term return on plan assets	(1,410,000)	(1,261,000)
Amortization of net loss	556,000	1,061,000
Amortization of prior service cost	(336,000)	(336,000)
Net periodic benefit cost	14,000	557,000
Defined Benefit Plan, Contributions by Employer	800,000	500,000
Defined Benefit Plan, Estimated Future Employer Contributions After Current Fiscal Year	14,000,000
Defined Benefit Plan Total Expected Employer Contributions for Fiscal Year	3,300,000
Public Service Company of New Mexico [Member] | Executive Retirement Program [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	0	0
Interest cost	205,000	180,000
Long-term return on plan assets	0	0
Amortization of net loss	52,000	58,000
Amortization of prior service cost	0	0
Net periodic benefit cost	257,000	238,000
Defined Benefit Plan, Contributions by Employer	400,000	400,000
Defined Benefit Plan Total Expected Employer Contributions for Fiscal Year	1,500,000
Texas-New Mexico Power Company [Member] | Pension Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	0	0
Interest cost	798,000	772,000
Long-term return on plan assets	(1,132,000)	(1,212,000)
Amortization of net loss	166,000	262,000
Amortization of prior service cost	0	0
Net periodic benefit cost	(168,000)	(178,000)
Defined Benefit Plan, Estimated Future Employer Contributions After Current Fiscal Year	0
Texas-New Mexico Power Company [Member] | Pension Plan [Member] | Minimum [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate (as a percent)	5.20%
Texas-New Mexico Power Company [Member] | Pension Plan [Member] | Maximum [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate (as a percent)	5.50%
Texas-New Mexico Power Company [Member] | OPEB [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	59,000	75,000
Interest cost	155,000	141,000
Long-term return on plan assets	(133,000)	(126,000)
Amortization of net loss	(31,000)	0
Amortization of prior service cost	8,000	14,000
Net periodic benefit cost	58,000	104,000
Defined Benefit Plan, Contributions by Employer	0	1,000,000
Defined Benefit Plan, Estimated Future Employer Contributions After Current Fiscal Year	1,400,000
Defined Benefit Plan Total Expected Employer Contributions for Fiscal Year	400,000
Texas-New Mexico Power Company [Member] | Executive Retirement Program [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	0	0
Interest cost	10,000	9,000
Long-term return on plan assets	0	0
Amortization of net loss	0	0
Amortization of prior service cost	0	0
Net periodic benefit cost	10,000	9,000
Defined Benefit Plan Total Expected Employer Contributions for Fiscal Year	100,000
Texas-New Mexico Power Company [Member] | Executive Retirement Program [Member] | Maximum [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Contributions by Employer	$ 100,000	$ 100,000

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Significant Accounting Policies and Responsibility for Financial Statements

3 Months Ended

Mar. 31, 2014

Accounting Policies [Abstract]

Significant Accounting Policies and Responsibility for Financial Statements

Significant Accounting Policies and Responsibility for Financial Statements

Financial Statement Preparation

In the opinion of management, the accompanying unaudited interim Condensed Consolidated Financial Statements reflect all normal and recurring accruals and adjustments that are necessary to present fairly the consolidated financial position at March 31, 2014 and December 31, 2013, and the consolidated results of operations, comprehensive income, and cash flows for the three months ended March 31, 2014 and 2013. The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could ultimately differ from those estimated. Weather causes the Company’s results of operations to be seasonal in nature and the results of operations presented in the accompanying Condensed Consolidated Financial Statements are not necessarily representative of operations for an entire year.

The Notes to Condensed Consolidated Financial Statements include disclosures for PNMR, PNM, and TNMP. This report uses the term “Company” when discussing matters of common applicability to PNMR, PNM, and TNMP. Discussions regarding only PNMR, PNM, or TNMP are so indicated. Certain amounts in the 2013 Condensed Consolidated Financial Statements and Notes thereto have been reclassified to conform to the 2014 financial statement presentation.

These Condensed Consolidated Financial Statements are unaudited. Certain information and note disclosures normally included in the annual Consolidated Financial Statements have been condensed or omitted, as permitted under the applicable rules and regulations. Readers of these financial statements should refer to PNMR’s, PNM’s, and TNMP’s audited Consolidated Financial Statements and Notes thereto that are included in their respective 2013 Annual Reports on Form 10-K.

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

Principles of Consolidation

The Condensed Consolidated Financial Statements of each of PNMR, PNM, and TNMP include their accounts and those of subsidiaries in which that entity owns a majority voting interest. PNM also consolidates the PVNGS Capital Trust and Valencia. 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 at cost. Other significant intercompany transactions between PNMR, PNM, and TNMP include interest and income tax sharing payments, as well as dividends paid on common stock. All intercompany transactions and balances have been eliminated. See Note 14.

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Fair Value of Derivative and Other Financial Instruments, Recurring (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013
PNMR and PNM [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	$ 230,250	$ 226,855
PNMR and PNM [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	230,250	226,855
PNMR and PNM [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	158,376	158,180
PNMR and PNM [Member] | Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	71,874	68,675
PNMR and PNM [Member] | Cash and equivalents [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	4,246	3,356
PNMR and PNM [Member] | Cash and equivalents [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	4,246	3,356
PNMR and PNM [Member] | Cash and equivalents [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	4,246	3,356
PNMR and PNM [Member] | Cash and equivalents [Member] | Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	0
PNMR and PNM [Member] | Domestic value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	41,055	39,460
PNMR and PNM [Member] | Domestic value [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	41,055	39,460
PNMR and PNM [Member] | Domestic value [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	41,055	39,460
PNMR and PNM [Member] | Domestic value [Member] | Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	0
PNMR and PNM [Member] | Domestic growth [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	74,517	76,292
PNMR and PNM [Member] | Domestic growth [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	74,517	76,292
PNMR and PNM [Member] | Domestic growth [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	74,517	76,292
PNMR and PNM [Member] | Domestic growth [Member] | Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	0
PNMR and PNM [Member] | International and other [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	17,264	16,633
PNMR and PNM [Member] | International and other [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	17,264	16,633
PNMR and PNM [Member] | International and other [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	17,264	16,633
PNMR and PNM [Member] | International and other [Member] | Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	0
PNMR and PNM [Member] | U.S. Government [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	20,662	21,941
PNMR and PNM [Member] | U.S. Government [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	20,662	21,941
PNMR and PNM [Member] | U.S. Government [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	18,909	20,194
PNMR and PNM [Member] | U.S. Government [Member] | Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	1,753	1,747
PNMR and PNM [Member] | Municipals [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	61,158	58,568
PNMR and PNM [Member] | Municipals [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	61,158	58,568
PNMR and PNM [Member] | Municipals [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	0	0
PNMR and PNM [Member] | Municipals [Member] | Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	61,158	58,568
PNMR and PNM [Member] | Corporate and other [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	11,348	10,605
PNMR and PNM [Member] | Corporate and other [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	11,348	10,605
PNMR and PNM [Member] | Corporate and other [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	2,385	2,245
PNMR and PNM [Member] | Corporate and other [Member] | Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	8,963	8,360
Public Service Company of New Mexico [Member] | Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt	1,515,097	1,382,938
Investment In PVNGS lessor notes	44,871	57,279
Other investments	436	445
Public Service Company of New Mexico [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt	0	0
Investment In PVNGS lessor notes	0	0
Other investments	436	445
Public Service Company of New Mexico [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt	1,515,097	1,382,938
Investment In PVNGS lessor notes	0	0
Other investments	0	0
Public Service Company of New Mexico [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt	0	0
Investment In PVNGS lessor notes	44,871	57,279
Other investments	0	0
PNM Resources [Member] | Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt	2,040,868	1,905,230
Investment In PVNGS lessor notes	44,871	57,279
Other investments	2,529	3,196
PNM Resources [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt	0	0
Investment In PVNGS lessor notes	0	0
Other investments	681	690
PNM Resources [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt	2,040,868	1,905,230
Investment In PVNGS lessor notes	0	0
Other investments	0	0
PNM Resources [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt	0	0
Investment In PVNGS lessor notes	44,871	57,279
Other investments	1,848	2,506
Texas-New Mexico Power Company [Member] | Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt	396,195	390,814
Other investments	245	245
Texas-New Mexico Power Company [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt	0	0
Other investments	245	245
Texas-New Mexico Power Company [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt	396,195	390,814
Other investments	0	0
Texas-New Mexico Power Company [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt	0	0
Other investments	0	0
Commodity Contract [Member] | PNMR and PNM [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity derivative instruments, Assets	6,477	7,066
Commodity derivative instruments, Liabilities	(6,353)	(3,793)
Commodity Contract [Member] | PNMR and PNM [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity derivative instruments, Assets	0	0
Commodity derivative instruments, Liabilities	0	0
Commodity Contract [Member] | PNMR and PNM [Member] | Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity derivative instruments, Assets	6,477	7,066
Commodity derivative instruments, Liabilities	(6,353)	(3,793)
Carrying Amount [Member] | Public Service Company of New Mexico [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt	1,390,627	1,290,618
Investment In PVNGS lessor notes	42,472	52,958
Other investments	436	445
Carrying Amount [Member] | PNM Resources [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt	1,845,338	1,745,420
Investment In PVNGS lessor notes	42,472	52,958
Other investments	1,813	1,835
Carrying Amount [Member] | Texas-New Mexico Power Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt	335,944	336,036
Other investments	$ 245	$ 245

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Stock-Based Compensation (Tables)

3 Months Ended

Mar. 31, 2014

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Disclosure of Share-based Compensation Arrangements by Share-based Payment Award [Table Text Block]

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

	Three Months Ended March 31,
Restricted Shares and Performance Based Shares	2014			2013
Expected quarterly dividends per share	$	0.185		$	0.165
Risk-free interest rate	0.71		%	0.38		%
Market-Based Shares
Dividend yield	2.82		%	2.86		%
Expected volatility	25.11		%	25.11		%
Risk-free interest rate	0.64		%	0.36		%

The following table summarizes activity in stock options and restricted stock awards, including performance-based and market-based shares, for the three months endedMarch 31, 2014:

	Stock Option Shares		Weighted- Average Exercise Price		Restricted Stock		Weighted- Average Grant Date Fair Value
Outstanding at beginning of period	1,343,666		$	20.63	315,305		$	17.87
Granted	—		$	—	223,348		$	20.79
Exercised	(182,407	)	$	17.86	(262,358	)	$	16.53
Forfeited	(17,151	)	$	26.43	—		$	—
Expired	(13,501	)	$	25.82	—		$	—
Outstanding at end of period	1,130,607		$	20.92	276,295		$	21.55

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

	Three Months Ended March 31,
Stock Options	2014		2013
Weighted-average grant date fair value of options granted	$	—	$	—
Total fair value of options that vested (in thousands)	$	—	$	620
Total intrinsic value of options exercised (in thousands)	$	1,469	$	1,824
Restricted Stock
Weighted-average grant date fair value	$	20.79	$	19.82
Total fair value of restricted shares that vested (in thousands)	$	4,336	$	3,871

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Fair Value of Derivative and Other Financial Instruments (Tables)

3 Months Ended

Mar. 31, 2014

Fair Value of Derivative and Other Financial Instruments [Line Items]

Fair Value, by Balance Sheet Grouping [Table Text Block]

The carrying amounts and fair values of investments in PVNGS lessor notes, other investments, and long-term debt, which are not recorded at fair value on the Condensed Consolidated Balance Sheets are presented below:

					GAAP Fair Value Hierarchy
	Carrying Amount		Fair Value		Level 1		Level 2		Level 3
March 31, 2014	(In thousands)
PNMR
Long-term debt	$	1,845,338	$	2,040,868	$	—	$	2,040,868	$	—
Investment in PVNGS lessor notes	$	42,472	$	44,871	$	—	$	—	$	44,871
Other investments	$	1,813	$	2,529	$	681	$	—	$	1,848
PNM
Long-term debt	$	1,390,627	$	1,515,097	$	—	$	1,515,097	$	—
Investment in PVNGS lessor notes	$	42,472	$	44,871	$	—	$	—	$	44,871
Other investments	$	436	$	436	$	436	$	—	$	—
TNMP
Long-term debt	$	335,944	$	396,195	$	—	$	396,195	$	—
Other investments	$	245	$	245	$	245	$	—	$	—
December 31, 2013
PNMR
Long-term debt	$	1,745,420	$	1,905,230	$	—	$	1,905,230	$	—
Investment in PVNGS lessor notes	$	52,958	$	57,279	$	—	$	—	$	57,279
Other investments	$	1,835	$	3,196	$	690	$	—	$	2,506
PNM
Long-term debt	$	1,290,618	$	1,382,938	$	—	$	1,382,938	$	—
Investment in PVNGS lessor notes	$	52,958	$	57,279	$	—	$	—	$	57,279
Other investments	$	445	$	445	$	445	$	—	$	—
TNMP
Long-term debt	$	336,036	$	390,814	$	—	$	390,814	$	—
Other investments	$	245	$	245	$	245	$	—	$	—

PNMR and PNM [Member]

Fair Value of Derivative and Other Financial Instruments [Line Items]

Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Table Text Block]

Commodity derivative instruments that are recorded at fair value, all of which are accounted for as economic hedges, are summarized as follows:

	Economic Hedges
	March 31, 2014			December 31, 2013
PNMR and PNM	(In thousands)
Current assets	$	4,003		$	4,064
Deferred charges	2,474			3,002
	6,477			7,066
Current liabilities	(5,446		)	(2,699		)
Long-term liabilities	(907		)	(1,094		)
	(6,353		)	(3,793		)
Net	$	124		$	3,273

Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance [Table Text Block]

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
	Three Months Ended
	March 31,
	2014			2013
PNMR and PNM	(In thousands)
Electric operating revenues	$	(4,151	)	$	(4,603	)
Cost of energy	189			756
Total gain (loss)	$	(3,962	)	$	(3,847	)

Schedule of Notional Amounts of Outstanding Derivative Positions [Table Text Block]

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
March 31, 2014
PNMR and PNM	775,000	(3,287,548	)
December 31, 2013
PNMR and PNM	905,000	(3,343,783	)

Schedule of Collateral Related to Derivative [Table Text Block]

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)
March 31, 2014
PNMR and PNM	$	2,981	$	—	$	1,913
December 31, 2013
PNMR and PNM	$	2,398	$	—	$	2,152

Available-for-sale Securities [Table Text Block]

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.

	Three Months Ended
	March 31,
	2014			2013
	(In thousands)
Proceeds from sales	$	22,804		$	14,284
Gross realized gains	$	3,119		$	1,391
Gross realized (losses)	$	(545	)	$	(407	)

The fair value and gross unrealized gains of investments in available-for-sale securities are presented in the following table. At March 31, 2014 and December 31, 2013, the fair value of available-for-sale securities included $225.8 million and $222.5 million for the NDT and $4.4 million and $4.4 million for the mine reclamation trust.

	March 31, 2014				December 31, 2013
	Unrealized Gains		Fair Value		Unrealized Gains		Fair Value
PNMR and PNM			(In thousands)
Cash and cash equivalents	$	—	$	4,246	$	—	$	3,356
Equity securities:
Domestic value	14,558		41,055		14,523		39,460
Domestic growth	23,002		74,517		25,656		76,292
International and other	1,671		17,264		1,040		16,633
Fixed income securities:
U.S. Government	377		20,662		158		21,941
Municipals	2,659		61,158		1,018		58,568
Corporate and other	458		11,348		207		10,605
	$	42,725	$	230,250	$	42,602	$	226,855

Investments Classified by Contractual Maturity Date [Table Text Block]

At March 31, 2014, 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		PNM
	(In thousands)
Within 1 year	$	2,798	$	11,968	$	11,968
After 1 year through 5 years	21,550		33,618		32,903
After 5 years through 10 years	11,895		—		—
After 10 years through 15 years	8,521		—		—
After 15 years through 20 years	10,705		—		—
After 20 years	37,699		—		—
	$	93,168	$	45,586	$	44,871

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Table Text Block]

Items recorded at fair value on the Condensed Consolidated Balance Sheets are presented below by level of the fair value hierarchy. There were no Level 3 fair value measurements at March 31, 2014 and December 31, 2013 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 (Level 2)
March 31, 2014	(In thousands)
PNMR and PNM
Available-for-sale securities
Cash and cash equivalents	$	4,246		$	4,246	$	—
Equity securities:
Domestic value	41,055			41,055		—
Domestic growth	74,517			74,517		—
International and other	17,264			17,264		—
Fixed income securities:
U.S. Government	20,662			18,909		1,753
Municipals	61,158			—		61,158
Corporate and other	11,348			2,385		8,963
	$	230,250		$	158,376	$	71,874
Commodity derivative assets	$	6,477		$	—	$	6,477
Commodity derivative liabilities	(6,353		)	—		(6,353		)
Net	$	124		$	—	$	124
December 31, 2013
PNMR and PNM
Available-for-sale securities
Cash and cash equivalents	$	3,356		$	3,356	$	—
Equity securities:
Domestic value	39,460			39,460		—
Domestic growth	76,292			76,292		—
International and other	16,633			16,633		—
Fixed income securities:
U.S. Government	21,941			20,194		1,747
Municipals	58,568			—		58,568
Corporate and other	10,605			2,245		8,360
	$	226,855		$	158,180	$	68,675
Commodity derivative assets	$	7,066		$	—	$	7,066
Commodity derivative liabilities	(3,793		)	—		(3,793		)
Net	$	3,273		$	—	$	3,273

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Stock-Based Compensation (Details) (USD $)	3 Months Ended			3 Months Ended					12 Months Ended				3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013	Mar. 31, 2014 Stock Options [Member]	Mar. 31, 2014 Restricted Stock [Member]	Mar. 31, 2013 Restricted Stock [Member]	Mar. 31, 2014 Market-Based Shares [Member]	Mar. 31, 2013 Market-Based Shares [Member]	Dec. 31, 2013 Executive [Member] Performance Shares [Member]	Mar. 31, 2014 Executive [Member] Performance Shares [Member]	Mar. 31, 2014 Achieves a specified improvement in total shareholder return at the end of 2016 compared to 2011 and she remains an employee [Member] Common Stock [Member] Chairman, President, and Chief Executive Officer [Member]	Mar. 31, 2014 Achieves a specified improvement in total shareholder return at the end of 2014 compared to 2011 and she remains an employee [Member] Common Stock [Member] Chairman, President, and Chief Executive Officer [Member]	Mar. 31, 2014 Performance Equity Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period													3 years
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]
Options, Outstanding at beginning of period, Shares	1,343,666
Options, Outstanding at beginning of period, Weighted-Average Exercise Price (in dollars per share)	$ 20.63
Options, Granted, Shares	0
Options, Granted, Weighted-Average Exercise Price (in dollars per share)	$ 0.00
Options, Exercised, Shares	(182,407)
Options, Exercised, Weighted-Average Exercise Price (in dollars per share)	$ 17.86
Options, Forfeited, Shares	(17,151)
Options, Forfeited, Weighted-Average Exercise Price (in dollars per share)	$ 26.43
Options, Expired, Shares	(13,501)
Options, Expired, Weighted-Average Exercise Price (in dollars per share)	$ 25.82
Options, Outstanding at end of period, Shares	1,130,607
Options, Outstanding at end of period, Weighted-Average Exercise Price (in dollars per share)	$ 20.92
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Options, Outstanding at end of period, Aggregate Intrinsic Value				$ 8,000,000
Options, Outstanding at end of period, Weighted-Average Remaining Contract Life (years)				3 years 4 months 22 days
Options, Outstanding at end of period, No intrinsic value	486,016
Weighted-average grant date fair value options granted (dollars per share)	$ 0.00	$ 0.00
Total fair value of options that vested	0	620,000
Total intrinsic value of options exercised	1,469,000	1,824,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Nonvested Restricted Stock, Nonvested at beginning of period, Shares					315,305
Nonvested Restricted Stock, Nonvested at beginning of period, Weighted-Average Grant-Date Fair Value (in dollars per share)					$ 17.87
Nonvested Restricted Stock, Granted, Shares					223,348
Nonvested Restricted Stock, Granted, Weighted-Average Grant-Date Fair Value (in dollars per share)					$ 20.79	$ 19.82
Nonvested Restricted Stock, Vested, Shares					(262,358)
Nonvested Restricted Stock, Vested, Weighted-Average Grant-Date Fair Value (in dollars per share)					$ 16.53
Nonvested Restricted Stock, Forfeited, Shares					0
Nonvested Restricted Stock, Forfeited, Weighted-Average Grant-Date Fair Value (in dollars per share)					$ 0.00
Nonvested Restricted Stock, Nonvested at end of period, Shares					276,295
Nonvested Restricted Stock, Nonvested at end of period, Weighted-Average Grant-Date Fair Value (in dollars per share)					$ 21.55
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Additional Disclosures [Abstract]
Total fair value of shares that vested					4,336,000	3,871,000
Expected quarterly dividends per share					$ 0.185	$ 0.165
Risk-free interest rate					0.71%	0.38%	0.64%	0.36%
Granted and Vested in Period									112,864
Share based Compensation, weighted percentage assigned to achieving market targets										60.00%
Share based Compensation, weighted percentage assigned to achieving performance targets										40.00%
Share-based Compensation Arrangement by Share-based Payment Award, Maximum Number of Shares in Year One										198,369
Share-based Compensation Arrangement by Share-based Payment Award, Maximum Number of Shares in Year Two										179,811
Share-based Compensation Arrangement by Share-based Payment Award, Maximum Number of Shares in Year Three										175,735
Shares received if achieves specified improvement in total shareholders return											135,000	35,000
Share-based Compensation Arrangement by Share-based Payment Award, Vesting Rate													100.00%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Dividend Rate							2.82%	2.86%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Volatility Rate							25.11%	25.11%
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized	$ 8,100,000		$ 4,600,000

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Financing (Tables)

3 Months Ended

Mar. 31, 2014

Debt Disclosure [Abstract]

Schedule of Short-term Debt [Table Text Block]

Short-term Debt

PNMR has a revolving credit financing capacity of $300.0 million under the PNMR Revolving Credit Facility. PNM has a revolving credit financing capacity of $400.0 million under the PNM Revolving Credit Facility. Both of these facilities currently expire on October 31, 2018. TNMP has a revolving credit financing capacity of $75.0 million under the TNMP Revolving Credit Facility that is secured by $75.0 million aggregate principal amount of TNMP first mortgage bonds and matures on September 18, 2018. PNM also has the PNM New Mexico Credit Facility, a $50.0 million unsecured revolving credit facility that expires on January 8, 2018. At March 31, 2014, there were no borrowings outstanding under any of these facilities and the weighted average interest rate was 1.01% for borrowings outstanding under the twelve-month PNMR Term Loan Agreement, which matures in December 2014. Short-term debt outstanding consisted of:

	March 31,		December 31,
Short-term Debt	2014		2013
	(In thousands)
PNM:
Revolving credit facility	$	—	$	49,200
PNM New Mexico Credit Facility	—		—
TNMP – Revolving credit facility	—		—
PNMR:
Revolving credit facility	—		—
PNMR Term Loan Agreement	100,000		100,000
	$	100,000	$	149,200

At April 25, 2014, PNMR, PNM, and TNMP had $291.4 million, $396.8 million, and $68.7 million of availability under their respective revolving credit facilities, including reductions of availability due to outstanding letters of credit, and PNM had $50.0 million of availability under the PNM New Mexico Credit Facility. Total availability at April 25, 2014, on a consolidated basis, was $806.9 million for PNMR. As of April 25, 2014, TNMP had $41.2 million in borrowings from PNMR under their intercompany loan agreement. At April 25, 2014, PNMR, PNM and TNMP had consolidated invested cash of $2.0 million, $9.3 million, and none.

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Pension and Other Postretirement Benefit Plans (Tables)

3 Months Ended

Mar. 31, 2014

Public Service Company of New Mexico [Member]

Defined Benefit Plan Disclosure [Line Items]

Schedule of Net Benefit Costs [Table Text Block]

The following tables present the components of the PNM Plans’ net periodic benefit cost:

	Three Months Ended March 31,
	Pension Plan						OPEB Plan						Executive Retirement Program
	2014			2013			2014			2013			2014		2013
	(In thousands)
Components of Net Periodic
Benefit Cost
Service cost	$	—		$	—		$	45		$	65		$	—	$	—
Interest cost	7,541			7,035			1,159			1,028			205		180
Expected return on plan assets	(9,511		)	(10,482		)	(1,410		)	(1,261		)	—		—
Amortization of net (gain) loss	3,255			3,710			556			1,061			52		58
Amortization of prior service cost	(241		)	19			(336		)	(336		)	—		—
Net periodic benefit cost	$	1,044		$	282		$	14		$	557		$	257	$	238

Texas-New Mexico Power Company [Member]

Defined Benefit Plan Disclosure [Line Items]

Schedule of Net Benefit Costs [Table Text Block]

The following tables present the components of the TNMP Plans’ net periodic benefit cost (income):

	Three Months Ended March 31,
	Pension Plan						OPEB Plan						Executive Retirement Program
	2014			2013			2014			2013			2014		2013
	(In thousands)
Components of Net Periodic
Benefit Cost (Income)
Service cost	$	—		$	—		$	59		$	75		$	—	$	—
Interest cost	798			772			155			141			10		9
Expected return on plan assets	(1,132		)	(1,212		)	(133		)	(126		)	—		—
Amortization of net (gain) loss	166			262			(31		)	—			—		—
Amortization of prior service cost	—			—			8			14			—		—
Net Periodic Benefit Cost (Income)	$	(168	)	$	(178	)	$	58		$	104		$	10	$	9

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Condensed Consolidated Statements of Changes in Equity (USD $) In Thousands, unless otherwise specified	Total	Common Stock [Member]	AOCI [Member]	Retained Earnings [Member]	Total Company Common 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 Company Common 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] Additional Paid-in Capital [Member]	Texas-New Mexico Power Company [Member] AOCI [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
Balance TNMP at Dec. 31, 2013	1,673,569						1,210,199						502,931	64	404,166	(263)	98,964
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Proceeds from stock option exercise	3,258	3,258	0	0	3,258	0
Awards of common stock	(11,639)	(11,639)	0	0	(11,639)	0
Excess tax (shortfall) from stock-based payment arrangements	(21)	(21)	0	0	(21)	0
Adjustments to Additional Paid in Capital, Share-based Compensation, Requisite Service Period Recognition	2,131	2,131	0	0	2,131	0
Valencia’s transactions with its owner	(4,369)	0	0	0	0	(4,369)	(4,369)	0	0	0	0	(4,369)
Net earnings	12,468						7,674						6,803	0	0	0	6,803
Net earnings before subsidiary preferred stock dividends	16,131	0	0	12,600	12,600	3,531	11,205	0	0	7,674	7,674	3,531
Subsidiary preferred stock dividends	(132)	0	0	(132)	(132)	0
Total other comprehensive income (loss)	791	0	791	0	791	0	855	0	855	0	855	0	(64)	0	0	(64)	0
Dividends declared on preferred stock							(132)	0	0	(132)	(132)	0
Dividends declared on common stock	(14,736)	0	0	(14,736)	(14,736)	0
Balance TNMP at Mar. 31, 2014	1,665,821						1,218,596						509,670	64	404,166	(327)	105,767
Balance at Mar. 31, 2014	$ 1,742,012	$ 1,172,098	$ (57,349)	$ 551,072	$ 1,665,821	$ 76,191	$ 1,294,787	$ 1,061,776	$ (57,022)	$ 213,842	$ 1,218,596	$ 76,191

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Related Party Transactions (Tables)

3 Months Ended

Mar. 31, 2014

Related Party Transactions [Abstract]

Schedule of Related Party Transactions [Table Text Block]

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

	Three Months Ended
	March 31,
	2014		2013
	(In thousands)
Services billings:
PNMR to PNM	$	21,066	$	22,652
PNMR to TNMP	7,261		7,361
PNM to TNMP	109		108
TNMP to PNMR	—		2
Interest billings:
PNMR to TNMP	96		96
PNMR to PNM	53		1
PNM to PNMR	26		41
Income tax sharing payments:
PNMR to PNM	—		—
PNMR to TNMP	—		—

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Fair Value of Derivative and Other Financial Instruments, Margin, Notional Amounts, Credit Rating (Details) (PNMR and PNM [Member], USD $) In Thousands, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013
Derivative [Line Items]
Contractual Liability	$ 2,981	$ 2,398
Existing Cash Collateral	0	0
Net Exposure	$ 1,913	$ 2,152
Commodity Contract [Member] | Fair Value Hedging [Member] | Derivative Long Position [Member]
Derivative [Line Items]
Volume positions (Decatherms / MWh)	(3,287,548)	905,000

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Condensed Consolidated Statements of Earnings (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Electric Operating Revenues	$ 328,897	$ 317,665
Operating Expenses:
Cost of energy	112,614	104,706
Administrative and general	43,859	44,691
Energy production costs	47,288	43,573
Depreciation and amortization	41,965	40,807
Transmission and distribution costs	16,906	16,295
Taxes other than income taxes	17,512	16,889
Total operating expenses	280,144	266,961
Operating income	48,753	50,704
Other Income and Deductions:
Interest income	2,117	2,634
Gains on available-for-sale securities	2,573	1,530
Other income	1,574	1,710
Other (deductions)	(2,931)	(3,350)
Net other income and deductions	3,333	2,524
Interest Charges	29,535	31,297
Earnings before Income Taxes	22,551	21,931
Income Taxes	6,420	7,969
Net Earnings	16,131	13,962
(Earnings) Attributable to Valencia Non-controlling Interest	(3,531)	(3,204)
Preferred Stock Dividend Requirements of Subsidiary	(132)	(132)
Net Earnings Attributable to PNMR	12,468	10,626
Net Earnings Attributable to PNMR per Common Share:
Basic (dollars per share)	$ 0.16	$ 0.13
Diluted (dollars per share)	$ 0.16	$ 0.13
Dividends Declared per Common Share (dollars per share)	$ 0.185	$ 0.165
Public Service Company of New Mexico [Member]
Electric Operating Revenues	262,736	257,894
Operating Expenses:
Cost of energy	96,626	91,660
Administrative and general	38,609	38,758
Energy production costs	47,288	43,566
Depreciation and amortization	27,082	25,834
Transmission and distribution costs	11,327	10,603
Taxes other than income taxes	10,500	10,234
Total operating expenses	231,432	220,655
Operating income	31,304	37,239
Other Income and Deductions:
Interest income	2,128	2,673
Gains on available-for-sale securities	2,573	1,530
Other income	1,113	1,314
Other (deductions)	(2,018)	(1,437)
Net other income and deductions	3,796	4,080
Interest Charges	19,812	19,957
Earnings before Income Taxes	15,288	21,362
Income Taxes	4,083	6,589
Net Earnings	11,205	14,773
(Earnings) Attributable to Valencia Non-controlling Interest	(3,531)	(3,204)
Net Earnings Attributable to PNMR	7,674	11,569
Preferred Stock Dividends Requirements	(132)	(132)
Net Earnings Attributable to PNMR	7,542	11,437
Texas-New Mexico Power Company [Member]
Electric Operating Revenues	66,161	59,771
Operating Expenses:
Cost of energy	15,988	13,046
Administrative and general	9,840	11,119
Depreciation and amortization	11,842	11,681
Transmission and distribution costs	5,579	5,692
Taxes other than income taxes	5,650	5,179
Total operating expenses	48,899	46,717
Operating income	17,262	13,054
Other Income and Deductions:
Other income	420	337
Other (deductions)	(231)	(129)
Net other income and deductions	189	208
Interest Charges	6,598	7,246
Earnings before Income Taxes	10,853	6,016
Income Taxes	4,050	2,290
Net Earnings Attributable to PNMR	$ 6,803	$ 3,726

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Financing, Short-term Debt (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014 Line of Credit [Member]	Dec. 31, 2013 Line of Credit [Member]	Mar. 31, 2014 PNM Resources [Member] Revolving Credit Facility [Member]	Dec. 31, 2013 PNM Resources [Member] Revolving Credit Facility [Member]	Mar. 31, 2014 Public Service Company of New Mexico [Member]	Dec. 31, 2013 Public Service Company of New Mexico [Member]	Mar. 31, 2014 Public Service Company of New Mexico [Member] Revolving Credit Facility [Member]	Dec. 31, 2013 Public Service Company of New Mexico [Member] Revolving Credit Facility [Member]	Mar. 31, 2014 Texas-New Mexico Power Company [Member]	Dec. 31, 2013 Texas-New Mexico Power Company [Member]	Mar. 31, 2014 Texas-New Mexico Power Company [Member] Revolving Credit Facility [Member]	Dec. 31, 2013 Texas-New Mexico Power Company [Member] Revolving Credit Facility [Member]	Apr. 25, 2014 Available Borrowing Capacity [Member]	Apr. 25, 2014 Available Borrowing Capacity [Member] PNM Resources [Member]	Apr. 25, 2014 Available Borrowing Capacity [Member] Public Service Company of New Mexico [Member]	Apr. 25, 2014 Available Borrowing Capacity [Member] Texas-New Mexico Power Company [Member]	Apr. 25, 2014 Subsequent Event [Member] PNM Resources [Member]	Apr. 25, 2014 Subsequent Event [Member] Public Service Company of New Mexico [Member]	Apr. 25, 2014 Subsequent Event [Member] Texas-New Mexico Power Company [Member]	Apr. 25, 2014 Affiliated Entity [Member] Intercompany loan agreements [Member] Texas-New Mexico Power Company [Member]	Mar. 31, 2014 PNMR Term Loan Agreement [Member]	Dec. 31, 2013 PNMR Term Loan Agreement [Member]	Mar. 31, 2014 First Mortgage Bonds Due 2014, Series 2009A, at 9 point 50 percent [Member] Texas-New Mexico Power Company [Member] Revolving Credit Facility [Member]	Mar. 31, 2014 Local Lines of Credit [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2013 Local Lines of Credit [Member] Public Service Company of New Mexico [Member]	Apr. 22, 2013 PNM Term Loan Agreement [Member] Notes Payable to Banks [Member]	Mar. 31, 2014 PNM 2014 Term Loan Agreement [Member] Public Service Company of New Mexico [Member]
Short-term Debt [Line Items]
Line of Credit Facility, Remaining Borrowing Capacity															$ 806,900,000	$ 291,400,000	$ 396,800,000	$ 68,700,000								$ 50,000,000
Line of Credit Facility, Maximum Borrowing Capacity					300,000,000.0				400,000,000.0				75,000,000.0
Debt Instrument, Collateral Amount																									75,000,000
Short-term Debt, Weighted Average Interest Rate	1.01%
Short-term debt	100,000,000	149,200,000	100,000,000	149,200,000	0	0	0	49,200,000	0	49,200,000			0	0									100,000,000	100,000,000		0	0	75,000,000
Short-term debt – affiliate											31,200,000	29,400,000										41,200,000
Restricted Cash and Investments																			$ 2,000,000	$ 9,300,000	$ 0
Debt Instrument, Interest Rate at Period End																													1.11%

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Condensed Consolidated Balance Sheets (USD $) In Thousands, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013
Current Assets:
Cash and cash equivalents	$ 27,167	$ 2,533
Accounts receivable, net of allowance for uncollectible accounts of $1,423 and $1,423	81,611	90,251
Unbilled revenues	49,408	58,806
Other receivables	41,476	53,909
Materials, supplies, and fuel stock	61,329	67,223
Regulatory assets	27,163	24,416
Commodity derivative instruments	4,003	4,064
Income taxes receivable	5,503	7,066
Current portion of accumulated deferred income taxes	58,681	58,681
Other current assets	44,689	34,590
Total current assets	401,030	401,539
Other Property and Investments:
Investment in PVNGS lessor notes	17,757	32,200
Available-for-sale securities	230,250	226,855
Other investments	1,813	1,835
Non-utility property, net of accumulated depreciation of $62 and $61 for PNMR	4,352	4,353
Total other property and investments	254,172	265,243
Utility Plant:
Plant in service and plant held for future use	5,602,590	5,563,061
Less accumulated depreciation and amortization	1,866,635	1,838,832
Net plant in service and plant held for future use	3,735,955	3,724,229
Construction work in progress	147,870	132,080
Nuclear fuel, net of accumulated amortization of $54,338 and $47,347 for PNMR and PNM	78,778	77,602
Net utility plant	3,962,603	3,933,911
Deferred Charges and Other Assets:
Regulatory assets	513,727	523,955
Goodwill	278,297	278,297
Commodity derivative instruments	2,474	3,002
Other deferred charges	94,723	94,263
Total deferred charges and other assets	889,221	899,517
Assets	5,507,026	5,500,210
Current Liabilities:
Short-term debt	100,000	149,200
Current installments of long-term debt	0	75,000
Accounts payable	62,198	109,666
Customer deposits	13,065	13,456
Accrued interest and taxes	73,978	49,600
Regulatory liabilities	353	1,081
Commodity derivative instruments	5,446	2,699
Dividends declared	14,864	14,864
Other current liabilities	42,184	77,105
Total current liabilities	312,088	492,671
Long-term Debt	1,845,338	1,670,420
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	833,240	801,408
Accumulated deferred investment tax credits	25,314	25,855
Regulatory liabilities	463,106	460,649
Asset retirement obligations	98,076	96,135
Accrued pension liability and postretirement benefit cost	75,745	80,046
Commodity derivative instruments	907	1,094
Other deferred credits	99,671	109,805
Total deferred credits and other liabilities	1,596,059	1,574,992
Total liabilities	3,753,485	3,738,083
Commitments and Contingencies (See [Note 10])
Cumulative preferred stock of subsidiary without mandatory redemption requirements ($100 stated value, 10,000,000 shares authorized: issued and outstanding 115,293 shares)	11,529	11,529
Company common stockholders’ equity:
Common stock outstanding	1,172,098	1,178,369
Accumulated other comprehensive income (loss), net of income taxes	(57,349)	(58,140)
Retained earnings	551,072	553,340
Total Company common stockholders' equity	1,665,821	1,673,569
Non-controlling interest in Valencia	76,191	77,029
Total equity	1,742,012	1,750,598
Total liabilities and stockholders' equity	5,507,026	5,500,210
Public Service Company of New Mexico [Member]
Current Assets:
Cash and cash equivalents	17,752	21
Accounts receivable, net of allowance for uncollectible accounts of $1,423 and $1,423	61,394	70,126
Unbilled revenues	41,874	48,992
Other receivables	40,788	52,964
Affiliate receivables	9,646	10,054
Materials, supplies, and fuel stock	58,546	64,520
Regulatory assets	23,016	19,394
Commodity derivative instruments	4,003	4,064
Income taxes receivable	3,917	4,030
Current portion of accumulated deferred income taxes	43,827	43,827
Other current assets	40,498	30,510
Total current assets	345,261	348,502
Other Property and Investments:
Investment in PVNGS lessor notes	17,757	32,200
Available-for-sale securities	230,250	226,855
Other investments	436	445
Non-utility property, net of accumulated depreciation of $62 and $61 for PNMR	976	976
Total other property and investments	249,419	260,476
Utility Plant:
Plant in service and plant held for future use	4,339,081	4,314,016
Less accumulated depreciation and amortization	1,420,194	1,402,531
Net plant in service and plant held for future use	2,918,887	2,911,485
Construction work in progress	112,093	107,344
Nuclear fuel, net of accumulated amortization of $54,338 and $47,347 for PNMR and PNM	78,778	77,602
Net utility plant	3,109,758	3,096,431
Deferred Charges and Other Assets:
Regulatory assets	377,334	384,217
Goodwill	51,632	51,632
Commodity derivative instruments	2,474	3,002
Other deferred charges	83,757	83,356
Total deferred charges and other assets	515,197	522,207
Assets	4,219,635	4,227,616
Current Liabilities:
Short-term debt	0	49,200
Short-term debt - affiliate	0	32,500
Current installments of long-term debt	0	75,000
Accounts payable	44,663	84,643
Affiliate payables	12,315	20,498
Customer deposits	13,065	13,456
Accrued interest and taxes	50,096	27,665
Regulatory liabilities	353	1,081
Commodity derivative instruments	5,446	2,699
Dividends declared	132	132
Other current liabilities	30,070	50,392
Total current liabilities	156,140	357,266
Long-term Debt	1,390,627	1,215,618
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	672,136	651,239
Accumulated deferred investment tax credits	25,314	25,855
Regulatory liabilities	415,537	414,611
Asset retirement obligations	97,147	95,225
Accrued pension liability and postretirement benefit cost	72,654	76,611
Commodity derivative instruments	907	1,094
Other deferred credits	82,857	91,340
Total deferred credits and other liabilities	1,366,552	1,355,975
Total liabilities	2,913,319	2,928,859
Commitments and Contingencies (See [Note 10])
Cumulative preferred stock of subsidiary without mandatory redemption requirements ($100 stated value, 10,000,000 shares authorized: issued and outstanding 115,293 shares)	11,529	11,529
Company common stockholders’ equity:
Common stock outstanding	1,061,776	1,061,776
Accumulated other comprehensive income (loss), net of income taxes	(57,022)	(57,877)
Retained earnings	213,842	206,300
Total Company common stockholders' equity	1,218,596	1,210,199
Non-controlling interest in Valencia	76,191	77,029
Total equity	1,294,787	1,287,228
Total liabilities and stockholders' equity	4,219,635	4,227,616
Texas-New Mexico Power Company [Member]
Current Assets:
Cash and cash equivalents	1	1
Accounts receivable, net of allowance for uncollectible accounts of $1,423 and $1,423	20,217	20,125
Unbilled revenues	7,534	9,814
Other receivables	1,057	1,246
Materials, supplies, and fuel stock	2,783	2,703
Regulatory assets	4,147	5,022
Current portion of accumulated deferred income taxes	6,501	6,501
Other current assets	752	980
Total current assets	42,992	46,392
Other Property and Investments:
Other investments	245	245
Non-utility property, net of accumulated depreciation of $62 and $61 for PNMR	2,240	2,240
Total other property and investments	2,485	2,485
Utility Plant:
Plant in service and plant held for future use	1,081,881	1,074,193
Less accumulated depreciation and amortization	359,205	352,105
Net plant in service and plant held for future use	722,676	722,088
Construction work in progress	33,377	16,790
Net utility plant	756,053	738,878
Deferred Charges and Other Assets:
Regulatory assets	136,393	139,738
Goodwill	226,665	226,665
Other deferred charges	8,440	8,273
Total deferred charges and other assets	371,498	374,676
Assets	1,173,028	1,162,431
Current Liabilities:
Short-term debt – affiliate	31,200	29,400
Accounts payable	8,878	12,543
Affiliate payables	2,209	3,181
Accrued interest and taxes	24,113	23,778
Other current liabilities	9,380	8,999
Total current liabilities	75,780	77,901
Long-term Debt	335,944	336,036
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	193,887	190,197
Regulatory liabilities	47,569	46,038
Asset retirement obligations	798	782
Accrued pension liability and postretirement benefit cost	3,091	3,435
Other deferred credits	6,289	5,111
Total deferred credits and other liabilities	251,634	245,563
Total liabilities	663,358	659,500
Commitments and Contingencies (See [Note 10])
Company common stockholders’ equity:
Common stock outstanding	64	64
Accumulated other comprehensive income (loss), net of income taxes	(327)	(263)
Paid-in-capital	404,166	404,166
Retained earnings	105,767	98,964
Total Company common stockholders' equity	509,670	502,931
Total liabilities and stockholders' equity	$ 1,173,028	$ 1,162,431

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Accumulated Other Comprehensive Income (Loss) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Equity [Abstract]
Percentage of Pension Liability Adjustment Capitalized into Construction Work In Process	23.20%	15.00%
Percentage of Pension Liability Adjustment Capitalized into Other Accounts	2.70%	2.50%
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Balance at December 31, 2012	$ (58,140)	$ (81,630)
Amounts reclassified from AOCI (pre-tax)	(1,912)	303
Income tax impact of amounts reclassified	756	(119)
Other OCI changes (pre-tax)	3,226	7,870
Income tax impact of other OCI changes	(1,279)	(3,115)
Total Other Comprehensive Income (Loss)	791	4,939
Balance at March 31, 2014	(57,349)	(76,691)
Accumulated Net Unrealized Investment Gain (Loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Balance at December 31, 2012	25,748	16,406
Amounts reclassified from AOCI (pre-tax)	(3,255)	(1,336)
Income tax impact of amounts reclassified	1,283	529
Other OCI changes (pre-tax)	3,379	7,858
Income tax impact of other OCI changes	(1,332)	(3,111)
Total Other Comprehensive Income (Loss)	75	3,940
Balance at March 31, 2014	25,823	20,346
Accumulated Defined Benefit Plans Adjustment [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Balance at December 31, 2012	(83,625)	(97,820)
Amounts reclassified from AOCI (pre-tax)	1,288	1,591
Income tax impact of amounts reclassified	(508)	(631)
Other OCI changes (pre-tax)	0	0
Income tax impact of other OCI changes	0	0
Total Other Comprehensive Income (Loss)	780	960
Balance at March 31, 2014	(82,845)	(96,860)
Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Balance at December 31, 2012	(263)	(216)
Amounts reclassified from AOCI (pre-tax)	55	48
Income tax impact of amounts reclassified	(19)	(17)
Other OCI changes (pre-tax)	(153)	12
Income tax impact of other OCI changes	53	(4)
Total Other Comprehensive Income (Loss)	(64)	39
Balance at March 31, 2014	(327)	(177)
Public Service Company of New Mexico [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Balance at December 31, 2012	(57,877)	(81,414)
Amounts reclassified from AOCI (pre-tax)	(1,967)	255
Income tax impact of amounts reclassified	775	(102)
Other OCI changes (pre-tax)	3,379	7,858
Income tax impact of other OCI changes	(1,332)	(3,111)
Total Other Comprehensive Income (Loss)	855	4,900
Balance at March 31, 2014	(57,022)	(76,514)
Public Service Company of New Mexico [Member] | Accumulated Net Unrealized Investment Gain (Loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Balance at December 31, 2012	25,748	16,406
Amounts reclassified from AOCI (pre-tax)	(3,255)	(1,336)
Income tax impact of amounts reclassified	1,283	529
Other OCI changes (pre-tax)	3,379	7,858
Income tax impact of other OCI changes	(1,332)	(3,111)
Total Other Comprehensive Income (Loss)	75	3,940
Balance at March 31, 2014	25,823	20,346
Public Service Company of New Mexico [Member] | Accumulated Defined Benefit Plans Adjustment [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Balance at December 31, 2012	(83,625)	(97,820)
Amounts reclassified from AOCI (pre-tax)	1,288	1,591
Income tax impact of amounts reclassified	(508)	(631)
Other OCI changes (pre-tax)	0	0
Income tax impact of other OCI changes	0	0
Total Other Comprehensive Income (Loss)	780	960
Balance at March 31, 2014	(82,845)	(96,860)
Public Service Company of New Mexico [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Balance at December 31, 2012	0	0
Amounts reclassified from AOCI (pre-tax)	0	0
Income tax impact of amounts reclassified	0	0
Other OCI changes (pre-tax)	0	0
Income tax impact of other OCI changes	0	0
Total Other Comprehensive Income (Loss)	0	0
Balance at March 31, 2014	0	0
Texas-New Mexico Power Company [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Balance at December 31, 2012	(263)	(216)
Amounts reclassified from AOCI (pre-tax)	55	48
Income tax impact of amounts reclassified	(19)	(17)
Other OCI changes (pre-tax)	(153)	12
Income tax impact of other OCI changes	53	(4)
Total Other Comprehensive Income (Loss)	(64)	39
Balance at March 31, 2014	(327)	(177)
Texas-New Mexico Power Company [Member] | Accumulated Net Unrealized Investment Gain (Loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Balance at December 31, 2012	0	0
Amounts reclassified from AOCI (pre-tax)	0	0
Income tax impact of amounts reclassified	0	0
Other OCI changes (pre-tax)	0	0
Income tax impact of other OCI changes	0	0
Total Other Comprehensive Income (Loss)	0	0
Balance at March 31, 2014	0	0
Texas-New Mexico Power Company [Member] | Accumulated Defined Benefit Plans Adjustment [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Balance at December 31, 2012	0	0
Amounts reclassified from AOCI (pre-tax)	0	0
Income tax impact of amounts reclassified	0	0
Other OCI changes (pre-tax)	0	0
Income tax impact of other OCI changes	0	0
Total Other Comprehensive Income (Loss)	0	0
Balance at March 31, 2014	0	0
Texas-New Mexico Power Company [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Balance at December 31, 2012	(263)	(216)
Amounts reclassified from AOCI (pre-tax)	55	48
Income tax impact of amounts reclassified	(19)	(17)
Other OCI changes (pre-tax)	(153)	12
Income tax impact of other OCI changes	53	(4)
Total Other Comprehensive Income (Loss)	(64)	39
Balance at March 31, 2014	$ (327)	$ (177)

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Related Party Transactions

3 Months Ended

Mar. 31, 2014

Related Party Transactions [Abstract]

Related Party Transactions

Related Party Transactions

PNMR, PNM, and TNMP are considered related parties as defined under GAAP. PNMR Services Company provides corporate services to PNMR and its subsidiaries in accordance with shared services agreements. The table below summarizes the nature and amount of related party transactions of PNMR, PNM, and TNMP:

	Three Months Ended
	March 31,
	2014		2013
	(In thousands)
Services billings:
PNMR to PNM	$	21,066	$	22,652
PNMR to TNMP	7,261		7,361
PNM to TNMP	109		108
TNMP to PNMR	—		2
Interest billings:
PNMR to TNMP	96		96
PNMR to PNM	53		1
PNM to PNMR	26		41
Income tax sharing payments:
PNMR to PNM	—		—
PNMR to TNMP	—		—

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Variable Interest Entities (Details) (USD $)	3 Months Ended			3 Months Ended						1 Months Ended	3 Months Ended				3 Months Ended				3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013	Mar. 31, 2014 Public Service Company of New Mexico [Member]	Mar. 31, 2013 Public Service Company of New Mexico [Member]	Dec. 31, 2013 Public Service Company of New Mexico [Member]	Mar. 31, 2014 Palo Verde Nuclear Generating Station [Member] Public Service Company of New Mexico [Member]	Dec. 31, 2013 Palo Verde Nuclear Generating Station [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 Palo Verde Nuclear Generating Station [Member] Property Lease Guarantee [Member] Maximum [Member] Public Service Company of New Mexico [Member]	Dec. 31, 2012 Delta [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 Delta [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2013 Delta [Member] Public Service Company of New Mexico [Member]	Dec. 31, 2013 Delta [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 Variable Interest Entity, Not Primary Beneficiary [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 Valencia [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2013 Valencia [Member] Public Service Company of New Mexico [Member]	Dec. 31, 2013 Valencia [Member] Public Service Company of New Mexico [Member]	May 30, 2008 Valencia [Member] Purchased Through May 30, 2028 [Member] Public Service Company of New Mexico [Member] MW	Mar. 31, 2014 Delta [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2013 Delta [Member] Public Service Company of New Mexico [Member]
Variable Interest Entity [Line Items]
Number of mega watts purchased (in megawatts)																		158
Long Term Contract For Purchase of Electric Power Fixed Costs															$ 4,800,000	$ 4,700,000			$ 1,600,000	$ 1,600,000
Long Term Contract For Purchase of Electric Power Variable Charges															200,000	100,000			200,000	200,000
Variable Interest Entity, Statement Of Operation [Abstract]
Operating revenues															4,931,000	4,775,000
Operating expenses															(1,400,000)	(1,571,000)
Earnings Attributable to non-controlling interest	3,531,000	3,204,000		3,531,000	3,204,000										3,531,000	3,204,000
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Current assets	401,030,000		401,539,000	345,261,000		348,502,000									2,780,000		2,658,000
Net property, plant and equipment															74,433,000		75,137,000
Assets	5,507,026,000	5,370,760,000	5,500,210,000	4,219,635,000		4,227,616,000									77,213,000		77,795,000
Current liabilities	312,088,000		492,671,000	156,140,000		357,266,000									1,022,000		766,000
Owners' equity - non-controlling interest	76,191,000		77,029,000	76,191,000		77,029,000									76,191,000		77,029,000
Long term contract option to purchase, ownership percentage															50.00%
Long term contract option to purchase, purchase price - percentage of adjusted NBV															50.00%
Long term contract option to purchase, purchase price - percentage of FMV															50.00%
Long term contract option to purchase, number of days to set FMV															60 days
Long term contract option to purchase, approximate approval period															15 months
Operating Leases, Renewal Options After Original Lease Term (in years)	6 years			2 years
Operating Leases, Extended Lease Term Option (in years)				6 years
Operating Leases, Future Minimum Payments Due							36,500,000
Operating leases, future minimum payments due, renewal term														145,200,000
Loss Contingency, Range of Possible Loss, Portion Not Accrued									144,700,000.0
Operating Leases, Future Minimum Payments Due, Next Six Months							11,800,000	26,000,000
Period of Long Term Contract For Purchase of Electric Power Fixed Costs																			20 years
Long Term Contract for Purchase of Electric Power Aggregate Amount of Contract Remaining																			37,700,000
Payments to Acquire Businesses, Gross										23,000,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt											15,400,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Long-term Debt											3,300,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets											23,200,000		23,700,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment											19,700,000		20,300,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities											17,400,000		18,200,000
Revenues											1,800,000	1,800,000
Net earnings	$ 12,468,000	$ 10,626,000		$ 7,674,000	$ 11,569,000						$ 300,000	$ 200,000

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Earnings Per Share (Tables)

3 Months Ended

Mar. 31, 2014

Earnings Per Share [Abstract]

Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]

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

	Three Months Ended
	March 31,
	2014		2013
	(In thousands, except per share amounts)
Net Earnings Attributable to PNMR	$	12,468	$	10,626
Average Number of Common Shares:
Outstanding during period	79,654		79,654
Vested awards of restricted stock	182		211
Average Shares - Basic	79,836		79,865
Dilutive Effect of Common Stock Equivalents (1):
Stock options and restricted stock	551		715
Average Shares - Diluted	80,387		80,580
Net Earnings Per Share of Common Stock:
Basic	$	0.16	$	0.13
Diluted	$	0.16	$	0.13

⁽¹⁾  Excludes the effect of out-of-the-money options for 486,016 shares of common stock at March 31, 2014.

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Condensed Consolidated Balance Sheets (Parenthetical) (USD $) In Thousands, except Share data, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013
Allowance for uncollectible accounts	$ 1,423	$ 1,423
Accumulated depreciation, non-utility property	62	61
Accumulated depreciation, nuclear fuel	54,338	47,347
Cumulative preferred stock of subsidiary, stated value	$ 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 authorized	115,293	115,293
Common stock, par value	$ 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	1,423	1,423
Accumulated depreciation, nuclear fuel	$ 54,338	$ 47,347
Cumulative preferred stock, stated value	$ 100	$ 100
Cumulative preferred stock, shares authorized	10,000,000	10,000,000
Cumulative preferred stock, shares issued	115,293	115,293
Cumulative preferred stock, shares outstanding	115,293	115,293
Common stock, par value	$ 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]
Common stock, par value	$ 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

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Condensed Consolidated Statements of Comprehensive Income (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Net earnings	$ 12,468	$ 10,626
Net Earnings	16,131	13,962
Unrealized Gain on Available-for-Sale Securities:
Unrealized holding gains arising during the period, net of income tax (expense) benefit	2,047	4,747
Reclassification adjustment for (gains) included in net earnings, net of income tax expense (benefit)	(1,972)	(807)
Pension Liability Adjustment:
Reclassification adjustment for amortization of experience (gain) loss recognized as net periodic benefit cost, net of income tax expense (benefit)	780	960
Fair Value Adjustment for Cash Flow Hedges:
Change in fair market value, net of income tax (expense) benefit of $53 and $(4)	(100)	8
Reclassification adjustment for (gains) losses included in net earnings, net of income tax expense (benefit) of $(19) and $(17)	36	31
Total Other Comprehensive Income (Loss)	791	4,939
Comprehensive Income	16,922	18,901
Comprehensive (Income) Attributable to Valencia Non-controlling Interest	(3,531)	(3,204)
Preferred Stock Dividend Requirements of Subsidiary	(132)	(132)
Comprehensive Income Attributable to PNMR	13,259	15,565
Public Service Company of New Mexico [Member]
Net earnings	7,674	11,569
Net Earnings	11,205	14,773
Unrealized Gain on Available-for-Sale Securities:
Unrealized holding gains arising during the period, net of income tax (expense) benefit	2,047	4,747
Reclassification adjustment for (gains) included in net earnings, net of income tax expense (benefit)	(1,972)	(807)
Pension Liability Adjustment:
Reclassification adjustment for amortization of experience (gain) loss recognized as net periodic benefit cost, net of income tax expense (benefit)	780	960
Fair Value Adjustment for Cash Flow Hedges:
Total Other Comprehensive Income (Loss)	855	4,900
Comprehensive Income	12,060	19,673
Comprehensive (Income) Attributable to Valencia Non-controlling Interest	(3,531)	(3,204)
Comprehensive Income Attributable to PNMR	8,529	16,469
Texas-New Mexico Power Company [Member]
Net earnings	6,803	3,726
Fair Value Adjustment for Cash Flow Hedges:
Change in fair market value, net of income tax (expense) benefit of $53 and $(4)	(100)	8
Reclassification adjustment for (gains) losses included in net earnings, net of income tax expense (benefit) of $(19) and $(17)	36	31
Total Other Comprehensive Income (Loss)	(64)	39
Comprehensive Income Attributable to PNMR	$ 6,739	$ 3,765

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Financing

3 Months Ended

Mar. 31, 2014

Debt Disclosure [Abstract]

Financing

Financing

Additional information concerning financing activities, including a TNMP cash-flow hedge that establishes a fixed interest rate on a variable rate loan, is contained in Note 6 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K.

Financing Activities

On January 8, 2014, PNM entered into a new $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.

On March 5, 2014, PNM entered into a new $175.0 million Term Loan Agreement (the “PNM 2014 Term Loan Agreement”) among PNM and The Bank of Tokyo-Mitsubishi UFJ, Ltd., 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 PNM’s existing $75.0 million PNM Term Loan Agreement. PNM also used the funds to repay other short-term amounts outstanding. The PNM Term Loan Agreement would otherwise have terminated on October 21, 2014. There were no prepayment penalties paid in connection with the termination of the PNM Term Loan Agreement. The PNM 2014 Term Loan Agreement bears interest at a variable rate, which was 1.11% at March 31, 2014, must be repaid on or before September 4, 2015, and is reflected as long-term debt on the Condensed Consolidated Balance Sheets. The PNM 2014 Term Loan Agreement includes customary covenants, including requirements to not exceed a maximum consolidated debt-to-consolidated capitalization ratio and customary events of default. The PNM 2014 Term Loan Agreement has a cross default provision and a change of control provision.

The existing TNMP 2011 Term Loan Agreement has an outstanding balance of $50.0 million that must be repaid by June 30, 2014. On December 9, 2013, TNMP entered into an agreement (the “TNMP 2013 Bond Purchase Agreement”), which provides that TNMP will issue $80.0 million aggregate principal amount of 4.03% first mortgage bonds, due 2024 (the “Series 2014A Bonds”). The terms of the TNMP 2013 Bond Purchase Agreement provide that, subject to satisfaction of certain conditions, TNMP will issue the Series 2014A Bonds on or about June 27, 2014. TNMP anticipates using $50.0 million of the proceeds from the issuance to repay the TNMP 2011 Term Loan Agreement at its maturity and using the remaining proceeds to reduce short-term debt under the TNMP Revolving Credit Facility and/or TNMP’s intercompany borrowings from PNMR. In accordance with GAAP, borrowings under the TNMP 2011 Term Loan Agreement, which are due on June 30, 2014, are reflected as being long-term in the Condensed Consolidated Balance Sheet since the TNMP 2013 Bond Purchase Agreement demonstrates TNMP’s ability and intent to re-finance the TNMP 2011 Term Loan Agreement on a long-term basis.

Short-term Debt

PNMR has a revolving credit financing capacity of $300.0 million under the PNMR Revolving Credit Facility. PNM has a revolving credit financing capacity of $400.0 million under the PNM Revolving Credit Facility. Both of these facilities currently expire on October 31, 2018. TNMP has a revolving credit financing capacity of $75.0 million under the TNMP Revolving Credit Facility that is secured by $75.0 million aggregate principal amount of TNMP first mortgage bonds and matures on September 18, 2018. PNM also has the PNM New Mexico Credit Facility, a $50.0 million unsecured revolving credit facility that expires on January 8, 2018. At March 31, 2014, there were no borrowings outstanding under any of these facilities and the weighted average interest rate was 1.01% for borrowings outstanding under the twelve-month PNMR Term Loan Agreement, which matures in December 2014. Short-term debt outstanding consisted of:

	March 31,		December 31,
Short-term Debt	2014		2013
	(In thousands)
PNM:
Revolving credit facility	$	—	$	49,200
PNM New Mexico Credit Facility	—		—
TNMP – Revolving credit facility	—		—
PNMR:
Revolving credit facility	—		—
PNMR Term Loan Agreement	100,000		100,000
	$	100,000	$	149,200

At April 25, 2014, PNMR, PNM, and TNMP had $291.4 million, $396.8 million, and $68.7 million of availability under their respective revolving credit facilities, including reductions of availability due to outstanding letters of credit, and PNM had $50.0 million of availability under the PNM New Mexico Credit Facility. Total availability at April 25, 2014, on a consolidated basis, was $806.9 million for PNMR. As of April 25, 2014, TNMP had $41.2 million in borrowings from PNMR under their intercompany loan agreement. At April 25, 2014, PNMR, PNM and TNMP had consolidated invested cash of $2.0 million, $9.3 million, and none.

XML

Document and Entity Information	3 Months Ended
	Mar. 31, 2014	Apr. 25, 2014
Document Information [Line Items]
Entity Registrant Name	PNM RESOURCES INC
Entity Central Index Key	0001108426
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-Q
Document Period End Date	Mar. 31, 2014
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	Q1
Amendment Flag	false
Entity Common Stock, Shares Outstanding		79,653,624
Public Service Company of New Mexico [Member]
Document Information [Line Items]
Entity Registrant Name	PUBLIC SERVICE CO OF NEW MEXICO
Entity Central Index Key	0000081023
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		39,117,799
Texas-New Mexico Power Company [Member]
Document Information [Line Items]
Entity Registrant Name	TEXAS NEW MEXICO POWER CO
Entity Central Index Key	0000022767
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		6,358

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Pension and Other Postretirement Benefit Plans

3 Months Ended

Mar. 31, 2014

Compensation and Retirement Disclosure [Abstract]

Pension and Other Postretirement Benefit Plans

Pension and Other Postretirement Benefit Plans

PNMR and its subsidiaries maintain qualified defined benefit pension plans, postretirement benefit plans providing medical and dental benefits, and executive retirement programs (“PNM Plans” and “TNMP Plans”). PNMR maintains the legal obligation for the benefits owed to participants under these plans.

Additional information concerning pension and OPEB plans is contained in Note 12 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K. Annual net periodic benefit cost (income) for the plans is actuarially determined using the methods and assumptions set forth in that note and is recognized ratably throughout the year.

PNM Plans

The following tables present the components of the PNM Plans’ net periodic benefit cost:

	Three Months Ended March 31,
	Pension Plan						OPEB Plan						Executive Retirement Program
	2014			2013			2014			2013			2014		2013
	(In thousands)
Components of Net Periodic
Benefit Cost
Service cost	$	—		$	—		$	45		$	65		$	—	$	—
Interest cost	7,541			7,035			1,159			1,028			205		180
Expected return on plan assets	(9,511		)	(10,482		)	(1,410		)	(1,261		)	—		—
Amortization of net (gain) loss	3,255			3,710			556			1,061			52		58
Amortization of prior service cost	(241		)	19			(336		)	(336		)	—		—
Net periodic benefit cost	$	1,044		$	282		$	14		$	557		$	257	$	238

PNM does not anticipate making any contributions to its pension trust in 2014 due to the current funded status of the pension plan.  PNM made contributions to its pension plan trust of $60.0 million in the three months ended March 31, 2013. Based on current law, including recent amendments to funding requirements, and estimates of portfolio performance, contributions to the PNM pension plan trust for 2015-2018 are estimated to total $61.5 million. These anticipated contributions were developed using current funding assumptions, with discount rates of 5.2% to 5.5%. Actual amounts required to be funded in the future will depend on the actuarial assumptions at that time, including the appropriate discount rate. PNM may make additional contributions at its discretion. PNM made contributions to the OPEB trust of $0.8 million and $0.5 million in the three months ended March 31, 2014 and 2013. PNM expects to make contributions to the OPEB trust totaling $3.3 million in 2014 and $14.0 million for 2015-2018.  Disbursements under the executive retirement program, which are funded by PNM and considered to be contributions to the plan, were $0.4 million and $0.4 million in the three months ended March 31, 2014 and 2013 and are expected to total $1.5 million during 2014.

TNMP Plans

The following tables present the components of the TNMP Plans’ net periodic benefit cost (income):

	Three Months Ended March 31,
	Pension Plan						OPEB Plan						Executive Retirement Program
	2014			2013			2014			2013			2014		2013
	(In thousands)
Components of Net Periodic
Benefit Cost (Income)
Service cost	$	—		$	—		$	59		$	75		$	—	$	—
Interest cost	798			772			155			141			10		9
Expected return on plan assets	(1,132		)	(1,212		)	(133		)	(126		)	—		—
Amortization of net (gain) loss	166			262			(31		)	—			—		—
Amortization of prior service cost	—			—			8			14			—		—
Net Periodic Benefit Cost (Income)	$	(168	)	$	(178	)	$	58		$	104		$	10	$	9

TNMP does not anticipate making additional contributions to its pension trust in 2014 due to the current funded status of the pension plan. TNMP made contributions to its pension plan trust of $1.0 million in the three months ended March 31, 2013. Based on current law, including recent amendments to funding requirements, and estimates of portfolio performance, TNMP estimates there would be no contributions to its pension plan trust for 2015-2018. The anticipated contributions were developed using current funding assumptions, including discount rates of 5.2% and 5.5%. Actual amounts to be funded in the future will depend on the actuarial assumptions at that time, including the appropriate discount rate. TNMP may make additional contributions at its discretion. TNMP made no contributions to the OPEB trust in the three months ended March 31, 2014 and 2013. TNMP expects to make contributions to the OPEB trust totaling $0.4 million in 2014 and $1.4 million for 2015-2018. Disbursements under the executive retirement program, which are funded by TNMP and considered to be contributions to the plan, were less than $0.1 million in the three months ended March 31, 2014 and 2013 and are expected to total $0.1 million during 2014.

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Condensed Consolidated Statements of Comprehensive Income (Parenthetical) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Unrealized holding gains (losses) arising during the period, income tax (expense)	$ (1,332)	$ (3,111)
Reclassification adjustment for (gains) included in net earnings (loss), income tax expense	1,283	529
Pension liability adjustment, income tax (expense) benefit	(508)	(631)
Change in fair market value, income tax (expense)	53	(4)
Reclassification adjustment for (gains) losses included in net earnings (loss), income tax expense (benefit)	(19)	(17)
Public Service Company of New Mexico [Member]
Unrealized holding gains (losses) arising during the period, income tax (expense)	(1,332)	(3,111)
Reclassification adjustment for (gains) included in net earnings (loss), income tax expense	1,283	529
Pension liability adjustment, income tax (expense) benefit	(508)	(631)
Texas-New Mexico Power Company [Member]
Change in fair market value, income tax (expense)	53	(4)
Reclassification adjustment for (gains) losses included in net earnings (loss), income tax expense (benefit)	$ (19)	$ (17)

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Accumulated Other Comprehensive Income (Loss)

3 Months Ended

Mar. 31, 2014

Equity [Abstract]

Accumulated Other Comprehensive Income (Loss)

Accumulated Other Comprehensive Income (Loss)

Information regarding accumulated other comprehensive income (loss) for the three months ended March 31, 2014 and 2013 is as follows:

	Accumulated Other Comprehensive Income (Loss)
	Unrealized						Fair Value
	Gain on			Pension			Adjustment
	Available-for-			Liability			for Cash Flow
	Sale Securities			Adjustment			Hedges			Total
	(In thousands)
PNMR
Balance at December 31, 2013	$	25,748		$	(83,625	)	$	(263	)	$	(58,140	)
Amounts reclassified from AOCI (pre-tax)	(3,255		)	1,288			55			(1,912		)
Income tax impact of amounts reclassified	1,283			(508		)	(19		)	756
Other OCI changes (pre-tax)	3,379			—			(153		)	3,226
Income tax impact of other OCI changes	(1,332		)	—			53			(1,279		)
Net change after income taxes	75			780			(64		)	791
Balance at March 31, 2014	$	25,823		$	(82,845	)	$	(327	)	$	(57,349	)

PNM
Balance at December 31, 2013	$	25,748		$	(83,625	)	$	—	$	(57,877	)
Amounts reclassified from AOCI (pre-tax)	(3,255		)	1,288			—		(1,967		)
Income tax impact of amounts reclassified	1,283			(508		)	—		775
Other OCI changes (pre-tax)	3,379			—			—		3,379
Income tax impact of other OCI changes	(1,332		)	—			—		(1,332		)
Net change after income taxes	75			780			—		855
Balance at March 31, 2014	$	25,823		$	(82,845	)	$	—	$	(57,022	)

TNMP
Balance at December 31, 2013	$	—	$	—	$	(263	)	$	(263	)
Amounts reclassified from AOCI (pre-tax)	—		—		55			55
Income tax impact of amounts reclassified	—		—		(19		)	(19		)
Other OCI changes (pre-tax)	—		—		(153		)	(153		)
Income tax impact of other OCI changes	—		—		53			53
Net change after income taxes	—		—		(64		)	(64		)
Balance at March 31, 2014	$	—	$	—	$	(327	)	$	(327	)

	Accumulated Other Comprehensive Income (Loss)
	Unrealized						Fair Value
	Gain on			Pension			Adjustment
	Available-for-			Liability			for Cash Flow
	Sale Securities			Adjustment			Hedges			Total
	(In thousands)
PNMR
Balance at December 31, 2012	$	16,406		$	(97,820	)	$	(216	)	$	(81,630	)
Amounts reclassified from AOCI (pre-tax)	(1,336		)	1,591			48			303
Income tax impact of amounts reclassified	529			(631		)	(17		)	(119		)
Other OCI changes (pre-tax)	7,858			—			12			7,870
Income tax impact of other OCI changes	(3,111		)	—			(4		)	(3,115		)
Net change after income taxes	3,940			960			39			4,939
Balance at March 31, 2013	$	20,346		$	(96,860	)	$	(177	)	$	(76,691	)

PNM
Balance at December 31, 2012	$	16,406		$	(97,820	)	$	—	$	(81,414	)
Amounts reclassified from AOCI (pre-tax)	(1,336		)	1,591			—		255
Income tax impact of amounts reclassified	529			(631		)	—		(102		)
Other OCI changes (pre-tax)	7,858			—			—		7,858
Income tax impact of other OCI changes	(3,111		)	—			—		(3,111		)
Net change after income taxes	3,940			960			—		4,900
Balance at March 31, 2013	$	20,346		$	(96,860	)	$	—	$	(76,514	)

TNMP
Balance at December 31, 2012	$	—	$	—	$	(216	)	$	(216	)
Amounts reclassified from AOCI (pre-tax)	—		—		48			48
Income tax impact of amounts reclassified	—		—		(17		)	(17		)
Other OCI changes (pre-tax)	—		—		12			12
Income tax impact of other OCI changes	—		—		(4		)	(4		)
Net change after income taxes	—		—		39			39
Balance at March 31, 2013	$	—	$	—	$	(177	)	$	(177	)

Pre-tax amounts reclassified from AOCI related to “Unrealized Gain on Available-for-Sale Securities” are included in “Gains on available-for-sale securities” in the Condensed 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 Condensed Consolidated Statements of Earnings. For the three months ended March 31, 2014 and 2013, approximately 23.2% and 15.0% of the amount reclassified was capitalized into construction work in process and approximately 2.7% and 2.5% was 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 Condensed Consolidated Statements of Earnings. An insignificant amount was capitalized as AFUDC. The income tax impacts of all amounts reclassified from AOCI are included in “Income Taxes” in the Condensed Consolidated Statements of Earnings.

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Segment Information

3 Months Ended

Mar. 31, 2014

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 provides generation service to firm-requirements wholesale customers and sells electricity into the wholesale market, as well as providing transmission services to third parties. The sale of electricity into the wholesale market includes the optimization of PNM’s jurisdictional capacity, as well as the capacity from PVNGS Unit 3, which is not included in retail rates. FERC has jurisdiction over wholesale and transmission rates.

TNMP

TNMP is an electric utility providing regulated transmission and distribution services in Texas under the TECA. TNMP’s operations are subject to traditional rate regulation by the PUCT.

Corporate and Other

The Corporate and Other segment includes PNMR holding company activities, primarily related to corporate level debt and PNMR Services Company.

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

PNMR SEGMENT INFORMATION

	PNM			TNMP			Corporate and Other			Consolidated
Three Months Ended March 31, 2014	(In thousands)
Electric operating revenues	$	262,736		$	66,161		$	—		$	328,897
Cost of energy	96,626			15,988			—			112,614
Margin	166,110			50,173			—			216,283
Other operating expenses	107,724			21,069			(3,228		)	125,565
Depreciation and amortization	27,082			11,842			3,041			41,965
Operating income	31,304			17,262			187			48,753
Interest income	2,128			—			(11		)	2,117
Other income (deductions)	1,668			189			(641		)	1,216
Net interest charges	(19,812		)	(6,598		)	(3,125		)	(29,535		)
Segment earnings (loss) before income taxes	15,288			10,853			(3,590		)	22,551
Income taxes (benefit)	4,083			4,050			(1,713		)	6,420
Segment earnings (loss)	11,205			6,803			(1,877		)	16,131
Valencia non-controlling interest	(3,531		)	—			—			(3,531		)
Subsidiary preferred stock dividends	(132		)	—			—			(132		)
Segment earnings (loss) attributable to PNMR	$	7,542		$	6,803		$	(1,877	)	$	12,468
At March 31, 2014:
Total Assets	$	4,219,635		$	1,173,028		$	114,363		$	5,507,026
Goodwill	$	51,632		$	226,665		$	—		$	278,297

	PNM			TNMP			Corporate and Other			Consolidated
Three Months Ended March 31, 2013	(In thousands)
Electric operating revenues	$	257,894		$	59,771		$	—		$	317,665
Cost of energy	91,660			13,046			—			104,706
Margin	166,234			46,725			—			212,959
Other operating expenses	103,161			21,990			(3,703		)	121,448
Depreciation and amortization	25,834			11,681			3,292			40,807
Operating income	37,239			13,054			411			50,704
Interest income	2,673			—			(39		)	2,634
Other income (deductions)	1,407			208			(1,725		)	(110		)
Net interest charges	(19,957		)	(7,246		)	(4,094		)	(31,297		)
Segment earnings (loss) before income taxes	21,362			6,016			(5,447		)	21,931
Income taxes (benefit)	6,589			2,290			(910		)	7,969
Segment earnings (loss)	14,773			3,726			(4,537		)	13,962
Valencia non-controlling interest	(3,204		)	—			—			(3,204		)
Subsidiary preferred stock dividends	(132		)	—			—			(132		)
Segment earnings (loss) attributable to PNMR	$	11,437		$	3,726		$	(4,537	)	$	10,626
At March 31, 2013:
Total Assets	$	4,155,257		$	1,098,942		$	116,561		$	5,370,760
Goodwill	$	51,632		$	226,665		$	—		$	278,297

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Significant Accounting Policies and Responsibility for Financial Statements (Policies)

3 Months Ended

Mar. 31, 2014

Accounting Policies [Abstract]

Principles of Consolidation

The Condensed Consolidated Financial Statements of each of PNMR, PNM, and TNMP include their accounts and those of subsidiaries in which that entity owns a majority voting interest. PNM also consolidates the PVNGS Capital Trust and Valencia. 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 at cost. Other significant intercompany transactions between PNMR, PNM, and TNMP include interest and income tax sharing payments, as well as dividends paid on common stock. All intercompany transactions and balances have been eliminated. See Note 14.

Segment Reporting

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.

Variable Interest Entity

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. GAAP also requires continual reassessment of the primary beneficiary of a variable interest entity.

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2014

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies

Overview

There are various claims and lawsuits pending against the Company. The Company is also 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 occasionally enters into financial commitments in connection with its business operations. The Company is also involved in various legal and regulatory (Note 12) 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. Notwithstanding these facts, the Company has assessed these matters based on current information and made judgments concerning their potential outcome, giving due consideration to the nature of the claim, the amount and nature of damages sought, and the probability of success. Such judgments are made with the understanding that the outcome of any litigation, investigation, and 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. The Company does not expect that any known lawsuits, environmental costs, and commitments will have a material effect on its financial condition, results of operations, or cash flows.

Additional information concerning commitments and contingencies is contained in Note 16 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K.

Commitments and Contingencies Related to the Environment

Nuclear Spent Fuel and Waste Disposal

Nuclear power plant operators are required to enter into spent fuel disposal contracts with the DOE that require the DOE to accept and dispose of all spent nuclear fuel and other high-level radioactive wastes generated by domestic power reactors. Although the Nuclear Waste Policy Act required the DOE to develop a permanent repository for the storage and disposal of spent nuclear fuel by 1998, the DOE announced that it would not be able to open the repository by 1998 and sought to excuse its performance of these requirements. In November 1997, the D.C. 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. In 2010, the court ordered an award to the PVNGS owners for their damages claim for costs incurred through December 2006. APS filed a subsequent lawsuit, on behalf of itself and the other PVNGS owners, against DOE in the Court of Federal Claims on December 19, 2012. The lawsuit alleges that from January 1, 2007 through June 30, 2011, additional damages were incurred due to DOE’s continuing failure to remove spent nuclear fuel and high level waste from PVNGS. PNM is unable to predict the outcome of this matter.

PNM estimates that it will incur approximately $58.0 million (in 2013 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 March 31, 2014 and December 31, 2013, PNM had a liability for interim storage costs of $12.0 million and $11.9 million included in other deferred credits.

On June 8, 2012, the D.C. 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. The D.C. Circuit found that the agency’s 2010 Waste Confidence Decision update constituted a major federal action, which requires either an EIS or a finding of no significant impact from the agency’s actions. The D.C. Circuit found that the NRC’s evaluation of the environmental risks from spent nuclear fuel was deficient, and therefore remanded the 2010 Waste Confidence Decision update for further action. In September 2012, the NRC issued a directive to its staff to proceed with development of a generic EIS to support an updated Waste Confidence Decision within 24 months. In September 2013, the NRC issued its draft EIS to support an updated Waste Confidence Decision. In late 2013, the NRC held a series of nationwide public meetings to receive stakeholder input on the draft EIS. NRC Commissioners have instructed the staff to issue the final generic EIS and rule by no later than September 2014. Untimely resolution by the NRC of the remand from the D.C. Circuit could have an adverse impact on certain NRC licensing actions. Currently, PVNGS does not have any licensing actions pending with the NRC. The petitioners had also sought a writ requiring the NRC to comply with the law and resume processing DOE’s pending license application for a nuclear waste site at Yucca Mountain in Nevada. In August 2013, the D.C. Circuit ordered the NRC to resume reviewing the license application. PNM is unable to predict the impact of these decisions.

In 2011, the National Association of Regulatory Utility Commissioners and the Nuclear Energy Institute challenged 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. The fee applicable to PVNGS Units 1 and 2 is recovered by PNM in its retail rates. In June 2012, the D.C. Circuit held that DOE failed to conduct a sufficient fee analysis in making the 2010 determination. The D.C. Circuit remanded the 2010 determination to the DOE with instructions to conduct a new fee adequacy determination within six months. In February 2013, upon completion of DOE’s revised one-mill fee adequacy determination, the court reopened the proceedings. On November 19, 2013, the D.C. Circuit ordered the DOE to notify Congress of the intent to suspend collecting annual fees for nuclear waste disposal from nuclear power plant operators. On January 3, 2014, the DOE notified Congress of the intention to suspend collection of the one-mill fee, subject to Congress’ disapproval. PNM anticipates challenges to this action and is unable to predict its ultimate outcome, but is continuing to accrue the one-mill fee. In 2013, the one-mill fee for PNM’s share of the output from all three units at PVNGS amounted to $3.0 million.

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 Determination Process - 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 found that BART to reduce NOx emissions from SJGS is selective non-catalytic reduction technology (“SNCR”). Nevertheless, in August 2011, EPA published its FIP, stating that it was required to do so by virtue of a consent decree it had entered into with an environmental group in litigation concerning the interstate transport requirements of the CAA. The FIP included a regional haze BART determination for SJGS that requires installation of selective catalytic reduction technology (“SCR”) with stringent NOx emission limits on all four units by September 21, 2016.

PNM, the Governor of New Mexico, and NMED petitioned the Tenth Circuit to review EPA’s decision and requested EPA to reconsider its decision. The Tenth Circuit denied petitions to stay the effective date of the rule on March 1, 2012. These parties have also formally asked EPA to stay the effective date of the rule. Several environmental groups have intervened in support of EPA. WEG also filed an action to challenge EPA’s rule in the Tenth Circuit, seeking to shorten the rule’s compliance period from five years to three years and PNM has intervened in this action. Oral arguments on the merits of the FIP challenges were held in October 2012 in the Tenth Circuit. In accordance with the court’s order, the parties have filed supplemental information.

In litigation involving several environmental groups, the United States District Court for the District of Columbia entered a consent decree, which, as amended, required EPA to issue a final rulemaking on New Mexico’s regional haze SIP by November 15, 2012. EPA approved all components of the SIP, except for the NOx BART determination for SJGS. With respect to that element of the SIP, EPA determined that with the FIP in place, it had met its obligation under the consent decree.

Because the unchanged compliance deadline of the FIP required PNM to continue to take steps to commence installation of SCRs at SJGS, PNM entered into a contract in October 2012 with an engineering, procurement, and construction contractor to install SCRs on behalf of the SJGS owners. The construction contract, which includes termination provisions in the event that SCRs are determined in the future to be unnecessary, has been suspended through November 1, 2014. At that time, PNM estimated the total cost to install SCRs on all four units of SJGS to be between approximately $824 million and $910 million, which amounts include costs for construction management, gross receipts taxes, AFUDC, and other PNM costs, although final costs were to be refined through an “open book” subcontractor bidding process. The costs for the project to install SCRs would also encompass installation of technology to comply with the NAAQS requirements described below.

Also, 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 equipment would be required to be installed to meet the NAAQS requirements described below, the cost of which had been estimated to total between approximately $105 million and $110 million for all four units of SJGS. The estimates for SNCRs and the NAAQS requirements include gross receipts taxes, AFUDC, and other PNM costs.

Based upon its current SJGS ownership interest, PNM’s share under either SCRs or SNCRs would be about 46.3%.

During 2012 and early 2013, PNM, as the operating agent for SJGS, engaged in discussions with NMED and EPA regarding an alternative to the FIP and SIP. Following approval by a majority of the other SJGS owners, PNM, NMED, and EPA agreed on February 15, 2013 to pursue a revised plan that could provide a new BART path to comply with federal visibility rules at SJGS, subject to approval by EIB and EPA. The terms of the non-binding agreement would result in 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. Certain aspects of this alternative are subject to approval by the NMPRC. At March 31, 2014, PNM’s net book value of its current ownership share of SJGS Units 2 and 3 was approximately $286 million.

Contemporaneously with the signing of the non-binding agreement, EPA indicated in writing that if the terms agreed to do not move forward due to circumstances outside of the control of PNM and NMED, EPA will work with the State of New Mexico and PNM to create a reasonable FIP compliance schedule to reflect the time used to develop the revised SIP.

This revised plan primarily focuses on how SJGS would meet the regional haze rule and also indicates that PNM would build a natural gas-fired generating plant in the “four corners” region to partially replace the capacity from the retired coal units. Detailed replacement power strategies also would be finalized.  PNM believes adequate replacement power alternatives will be available to meet its generation needs and ensure reliability.

It was contemplated that the retirement of SJGS Units 2 and 3 under the revised plan might result in shifts in ownership among SJGS owners or other changes in the contractual cost sharing arrangements, as may be agreed upon by the owners. See SJGS Ownership Restructuring Matters below. Owners of the affected units also may seek approvals of their utility commissions or governing boards.

The parties file periodic status reports with the Tenth Circuit.  To demonstrate that progress has been made toward settling the Tenth Circuit litigation, information, including the non-binding agreement and its accompanying timeline, was submitted to the Tenth Circuit. Following the parties’ submission of their status reports, on February 28, 2013, the Tenth Circuit referred the litigation to the Tenth Circuit Mediation Office, which has authority to require the parties to attend mediation conferences to informally resolve issues in the pending appeals. On October 17, 2013, the court ruled on a motion filed by PNM for abatement of the pending petitions for review and seeking deferral of briefing on a simultaneously filed motion to stay the EPA rule. The court placed the pending petitions for review in abeyance and set a schedule for the parties to file status reports. The court ruled that, if at any time the agreement in principle fails or is not implemented as was indicated in the term sheet and timeline, any party to the litigation may file a motion seeking to lift the abatement.  PNM is continuing to evaluate the impacts of these matters, but is unable to predict their ultimate outcomes.

Due to the long lead times on certain equipment purchases, PNM began taking steps to prepare for the potential installation of SNCRs on Units 1 and 4. In April 2013, PNM issued an RFP for SNCR system design and technology. In May 2013, PNM entered into an SNCR equipment and related services contract with an SNCR technology provider, but has not yet entered into a construction and procurement contract.

In accordance with the revised plan, PNM submitted a new BART analysis to NMED on April 1, 2013, reflecting the terms of the non-binding agreement, including the installation of SNCRs on Units 1 and 4 and the retirement of Units 2 and 3. NMED developed a revised SIP and submitted it to the EIB for approval in May 2013. After a public hearing, the EIB approved the revised SIP in September 2013 and the revised SIP was submitted to EPA for approval on October 18, 2013. EPA deemed the SIP application complete on December 17, 2013. It is anticipated that EPA will publish its proposed action on the revised SIP within 135 days of determining it was complete. On April 30, 2014, EPA issued an advance copy of its proposed approval of the revised SIP. It is anticipated that the notice will be published in the Federal Register in mid-May 2014, which will start the 30-day public comment period that is part of the EPA process. Final EPA action on the revised SIP is expected by about the end of September 2014.

On December 20, 2013, PNM made a filing with the NMPRC requesting certain approvals necessary to effectuate the revised SIP. In this filing, PNM requests:

• 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, currently estimated to be approximately $205 million, 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 equipment and the additional equipment to comply with NAAQS requirements on SJGS Units 1 and 4, not to exceed a total cost of $82 million

• A CCN for an exchange of capacity out of SJGS Unit 3 and into SJGS Unit 4, resulting in ownership of an additional 78 MW in Unit 4 for PNM; the net impact of this exchange and the retirement of Units 2 and 3 would be a reduction of 340 MW in PNM’s ownership of SJGS

In its filing, PNM requested the NMPRC to issue its final ruling on the application no later than December 2014. On February 11, 2014, the Hearing Examiner issued an order finding that PNM’s application is complete. The order also stated that there was not a statutory time clock for the request to retire SJGS Units 2 and 3 and the statutory time clock on the CCN requests has not yet begun. The Hearing Examiner found that the NMPRC should proceed with the review of PNM’s application and establish a schedule that would allow NMPRC action on the application by the end of 2014. A public hearing is scheduled to begin on August 19, 2014.

The above estimate of PNM’s share of the costs to install SNCRs and the additional equipment to comply with NAAQS requirements on SJGS Units 1 and 4 includes gross receipts taxes, AFUDC, and other PNM costs. This amount and the above estimate of net book value of SJGS Units 2 and 3 at December 31, 2017 reflect the requested exchange of 78 MW of capacity out of SJGS Unit 3 and into SJGS Unit 4 resulting in PNM’s ownership share of SJGS Units 1 and 4 aggregating approximately 52%. The December 20, 2013 NMPRC filing identifies a new 177 MW natural gas fired generation source and 40 MW of new utility-scale solar PV generation to replace a portion of PNM’s share of the reduction in generating capacity due to the retirement of SJGS Units 2 and 3. Specific approvals to acquire these facilities and the treatment of associated costs will be made in future filings. PNM estimates the cost of these identified resources would be approximately $276.3 million. These amounts are included in PNM’s current construction expenditure forecast although approval of the plan remains subject to numerous conditions. 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 would increase with the installation of either SCRs or SNCRs. See Note 12 for additional information concerning PNM’s filing for NMPRC approvals regarding these matters.

As discussed under SJGS Ownership Restructuring Matters below, the owners of SJGS are attempting to negotiate agreements concerning numerous matters, the resolution of which is necessary in order to facilitate the shutdown of SJGS Units 2 and 3 and comply with the revised SIP. 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. Although the negotiations among the SJGS owners are continuing, no agreements have been reached. PNM’s ultimate ownership percentage in SJGS Unit 4 will depend on the final resolution of the negotiations among the SJGS owners. Depending upon the terms and conditions agreed to as a result of the negotiations, including PNM’s share of the capacity of SJGS Unit 4, PNM may amend its December 20, 2013 filing with the NMPRC. However, PNM does not anticipate a change in the nature and capacity of replacement power required by PNM as a result of the on-going negotiations.

PNM can provide no assurance that the requirements of the plan agreed to on February 15, 2013 will be accomplished within the required timeframes or at all. If the February 15, 2013 plan is not implemented, PNM would seek to work with NMED and EPA to develop a revised timetable for implementation of the FIP. If an agreement on a revised timetable cannot be reached, PNM will likely be unable to complete the installation of SCRs on all four units at SJGS by the FIP deadline of September 21, 2016. In such event, PNM would need to rely on EPA’s pledge to work with PNM and the State of New Mexico to develop a reasonable FIP compliance plan or otherwise negotiate a solution with EPA or seek relief from the Tenth Circuit in order to continue to be able to operate the plant, including during the installation process for any alternate solution. If relief is not granted, PNM could be forced to temporarily cease operation of some or all of the SJGS units. If a shutdown was required, PNM would then have to acquire temporary replacement power through short-term or open-market purchases in order to serve the needs of its customers. There can be no assurance that sufficient replacement power will be available to serve PNM’s needs or, if available, what costs would be incurred.

PNM is unable to predict the ultimate outcome of these matters or what additional pollution control equipment will be required at SJGS.PNM will seek recovery from its ratepayers for all costs that may be incurred as a result of the CAA requirements. Although the additional equipment and other final requirements will result in additional capital and operating costs being incurred, PNM believes that its access to the capital markets is sufficient to be able to finance its share of the installation. It is possible that requirements to comply with the CAA, combined with the financial impact of possible future climate change regulation or legislation, if any, 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.

SJGS Ownership Restructuring Matters - As discussed in the 2013 Annual Report on Form 10-K, 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 and the contract with SJCC to supply the coal requirements of the plant expires on December 31, 2017. The California participants have indicated that, under California law, they may be prohibited from making significant capital improvements to SJGS. The California participants have stated they would be unable to fully fund the construction of either SCRs or SNCRs at SJGS and have expressed the intent to exit their ownership in SJGS no later than the expiration of the current SJPPA. One other participant has also expressed a similar intent to exit ownership in the plant. The participants intending to exit ownership in SJGS currently own 50.0% of SJGS Unit 3 and 38.8% of SJGS Unit 4. PNM currently owns 50.0% of SJGS Unit 3 and 38.5% of SJGS Unit 4. PNM is unable to predict the actions of the SJGS participants. Likewise, PNM cannot predict the impact of those actions on the ownership of SJGS or the operations of SJGS and PNM.

The SJGS participants have engaged in negotiations concerning the implementation of the revised SIP to address BART at SJGS. These negotiations included potential shifts in ownership among participants and between Units 3 and 4 in order to facilitate the shutdown of Units 2 and 3 to comply with the revised SIP and to accommodate the intent of the participants desiring to exit ownership in SJGS. This could have resulted in certain of the continuing participants, including PNM, acquiring additional ownership interests in Unit 4 prior to the shutdown of SJGS Units 2 and 3. Based on the status of negotiations at the time of PNM’s December 20, 2013 NMPRC filing, PNM requested NMPRC approval to exchange 78 MW of its capacity in SJGS Unit 3 for an equal amount of capacity in SJGS Unit 4. Although negotiations are continuing, no agreements have been reached. The ultimate outcome of these negotiations could result in PNM acquiring more than 78 MW of SJGS Unit 4. The discussions among the SJGS participants regarding restructuring have also included, among other matters, the treatment of plant decommissioning obligations, mine reclamation obligations, environmental matters, and certain ongoing operating costs. The SJGS participants have engaged a mediator to assist in facilitating resolution of a number of outstanding matters among the owners. PNM is unable to predict the outcome of the negotiations.

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 common property. As provided in the SJPPA, specified percentages of both the outstanding participant shares, based on MW ownership, and the number of participants in the unit or common property must be obtained in order for a capital improvement project to be approved. PNM presented the SNCR project, including NAAQS compliance requirements, to the SJGS participants in Unit 1 and Unit 4 for approval in late October 2013. The project was approved for Unit 1, but the Unit 4 project, which includes some of the California participants, did not obtain the required percentage of votes for approval. Other capital projects related to Unit 4 were also not approved by the participants. The SJPPA provides that PNM, in its capacity as operating agent of SJGS, is authorized and obligated to take reasonable and prudent actions necessary for the successful and proper operation of SJGS pending the resolution, by arbitration or otherwise, of any inability or failure to agree by the participants. PNM must evaluate its responsibilities and obligations as operating agent under the SJPPA regarding the SJGS Unit 4 capital projects that were not approved by the participants and take reasonable and prudent actions as it deems necessary. On March 11, 2014, PNM requested that the owners of Unit 4 approve the expenditure of $1.9 million of costs critical to being able to comply with the time frame in the revised SIP with respect to the Unit 4 project. The Unit 4 owners did not approve the expenditures. Thereupon, PNM issued a “Prudent Utility Practice” notice under the SJPPA indicating PNM was restarting certain critical activities to keep the Unit 4 SNCR project on schedule. PNM cannot predict the outcome of this matter, its impact on SJGS’ compliance with the CAA, or the impact on PNM’s financial position, results of operations, and cash flows.

Four Corners

On August 6, 2012, EPA issued its 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 close permanently 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 shutdown 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.

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.  The Navajo Nation approved these amendments in March 2011.  The effectiveness of the amendments also requires the approval of the DOI, as does a related federal rights-of-way grant, which the Four Corners participants are pursuing.  A federal environmental review is underway as part of the DOI review process.  In March 2014, APS received a draft of the EIS in connection with the DOI review process.  Comments on the draft EIS are due by the May 27, 2014.  APS will also require a PSD permit from EPA to install SCR control technology at Four Corners.  PNM cannot predict whether these federal approvals will be granted, and if so on a timely basis, or whether any conditions that may be attached to them will be acceptable to the Four Corners participants.

The Four Corners participants’ obligations to comply with EPA’s final BART determinations, coupled with the financial impact of possible future climate change regulation or legislation, other environmental regulations, and other business considerations, could jeopardize the economic viability of Four Corners or the ability of individual participants to continue their participation in Four Corners.

PNM is continuing to evaluate the impacts of EPA’s BART determination for Four Corners. PNM estimates its share of costs, including PNM’s AFUDC, to be up to approximately $80.3 million for post-combustion controls at Four Corners Units 4 and 5. PNM would seek recovery from its ratepayers of all costs that are ultimately incurred. PNM is unable to predict the ultimate outcome of this matter.

Four Corners BART FIP Challenge

On October 22, 2012, WEG filed a petition for review in the Ninth Circuit challenging the Four Corners BART FIP.  In its petition, WEG alleges that the final BART rule results in more air pollution being emitted into the air than allowed by law and that EPA failed to follow the requirements of the ESA.  APS intervened in this matter and filed a motion to dismiss this lawsuit for lack of jurisdiction or alternatively to transfer the lawsuit to the Tenth Circuit. On February 25, 2013, the Ninth Circuit denied APS’ motion to dismiss, but granted the request to transfer the case to the Tenth Circuit. Oral argument was presented before the Tenth Circuit on January 23, 2014. A decision is expected before the end of 2014. PNM cannot currently predict the outcome of this matter or the range of its potential impact.

Regional Haze Challenges

On December 27, 2012, WEG filed a petition for review in the Tenth Circuit challenging the SO₂ and particulate matter emissions elements of EPA’s approval of New Mexico’s Regional Haze SIP.  On February 26, 2013, HEAL Utah and other environmental groups filed petitions in the Tenth Circuit challenging EPA’s final approval of the remaining elements of New Mexico’s Regional Haze SIP, as well as EPA’s approval of the Albuquerque/Bernalillo County Air Quality Control Board SIP. PNM was granted intervention in both matters and the Tenth Circuit consolidated the two matters based on the similarity of issues. Oral argument was heard before the Tenth Circuit on March 20, 2014. PNM is continuing to evaluate the impacts of these matters, but is unable to predict their ultimate outcomes.

National Ambient Air Quality Standards (“NAAQS”)

The CAA requires EPA to set NAAQS for pollutants considered harmful to public health and the environment. EPA has set NAAQS for certain pollutants, including NOx, SO₂,ozone, and particulate matter. In 2010, EPA updated the primary NOx and SO₂ NAAQS to include a 1-hour maximum standard while retaining the annual standards for NOx and SO₂ and the 24-hour SO₂ standard. New Mexico is in attainment for the 1-hour NOx NAAQS. EPA has issued draft guidance on how to determine whether areas in a state comply with the new 1-hour SO₂ NAAQS. On May 21, 2013, EPA released draft guidance on characterizing air quality in areas with limited or no monitoring data near existing SO₂ sources. This characterization will result in these areas being designated as attainment, nonattainment, or unclassified for compliance with the 1-hour SO₂ NAAQS.  Several states and environmental groups have filed lawsuits challenging EPA’s decision to designate only a few areas as “nonattainment” within the 3-year deadline, while leaving the rest of the country to wait until the states either obtain better monitoring data or conduct computer modeling.  Although the determination process has not been finalized, PNM believes that compliance with the 1-hour SO₂ standard may require operational changes and/or equipment modifications at SJGS. On April 6, 2012, PNM filed an application for an amendment to its air permit for SJGS, which would be required for the installation of either SCRs or SNCRs described above. In addition, this application included a proposal by PNM to install equipment modifications for the purpose of reducing fugitive emissions, including NOx, SO₂, and particulate matter. These modifications would help SJGS meet the NAAQS. It is anticipated that this technology would be installed at the same time as the installation of regional haze BART controls, in order to most efficiently and cost effectively conduct construction activities at SJGS. The cost of this technology is dependent upon the type of control technology that is ultimately determined to be NOx BART at SJGS. See Regional Haze - SJGS above.

EPA finalized revisions to its NAAQS for fine particulate matter on December 14, 2012. PNM believes the equipment modifications discussed above will assist the plant in complying with the particulate matter NAAQS.

In January 2010, EPA announced it would strengthen the 8-hour ozone standard by setting a new standard in a range of 0.060-0.070 parts per million. EPA is reviewing its 2008 standard and has stated it intends to propose a new standard. Although EPA has not announced a timeline for its review, it may release new proposed standards in the second half of 2014.  Depending upon where the standard for ozone is set, San Juan County, where SJGS is situated, could be designated as not attaining the standard for ozone. If that were to occur, NMED would have responsibility for bringing the county into compliance and would look at all sources of NOx and volatile organic compounds since these are the pollutants that form ground-level ozone. As a result, SJGS could be required to install further NOx controls to meet a new ozone NAAQS. In addition, other counties in New Mexico, including Bernalillo County, may be designated as non-attainment. PNM cannot predict the outcome of this matter, the impact of other potential environmental mitigations, or if additional NOx controls would be required at any of its affected facilities as a result of ozone non-attainment designation.

Citizen Suit Under the Clean Air Act

The operations of SJGS are covered by a Consent Decree with the Grand Canyon Trust and Sierra Club and with the NMED that includes stipulated penalties for non-compliance with specified emissions limits. Stipulated penalty amounts are placed in escrow on a quarterly basis pending review of SJGS’s emissions performance. In May 2010, PNM filed a petition with the federal district court seeking a judicial determination on a dispute relating to PNM’s mercury controls. NMED and plaintiffs seek to require PNM to implement additional mercury controls. PNM estimates the implementation would increase annual mercury control costs for the entire station, which are currently $0.7 million, to a total of $6.6 million. On March 23, 2014, the court entered a stipulated order reflecting an agreement reached by the parties. In accordance with the stipulated order, PNM will repeat the mercury study required under the Consent Decree using sorbent traps instead of the monitoring system used in the initial study. The results of the mercury study will establish the activated carbon injection rate that maximizes mercury removal at SJGS, as required under the Consent Decree. PNM cannot predict the ultimate outcome of this matter.

Section 114 Request

In April 2009, APS received a request from EPA under Section 114 of the CAA seeking detailed information regarding projects at and operations of Four Corners. EPA has taken the position that many utilities have made physical or operational changes at their plants that should have triggered additional regulatory requirements under the NSR provisions of the CAA. APS has responded to EPA’s request. PNM is currently unable to predict the timing or content of EPA’s response, if any, or any resulting actions.

Four Corners Clean Air Act Lawsuit

In October 2011, Earthjustice, on behalf of several environmental organizations, filed a lawsuit in the United States District Court for the District of New Mexico against APS and the other Four Corners participants alleging violations of the NSR provisions of the CAA and NSPS violations. The plaintiffs seek to have the court enjoin operations at Four Corners until APS applies for and obtains any required NSR permits and complies with the NSPS. The plaintiffs further request the court to order the payment of civil penalties, including a beneficial mitigation project. On April 2, 2012, the Four Corners participants filed motions to dismiss. The case is being held in abeyance while the parties seek to negotiate a settlement. On March 30, 2013, upon joint motion of the parties, the court issued an order deeming the motions to dismiss withdrawn without prejudice during pendency of the stay. At such time as the stay is lifted, the Four Corners owners may reinstate their motions to dismiss without risk of default. PNM cannot currently predict the outcome of this matter or the range of its potential impact.

WEG v. OSM NEPA Lawsuit

In February 2013, WEG filed a Petition for Review in the United States District Court of Colorado against OSM challenging federal administrative decisions affecting seven different mines in four states issued at various times from 2007 through 2012.  In its petition, WEG challenges several unrelated mining plan modification approvals, which were each separately approved by OSM.  Of the fifteen claims for relief in the WEG Petition, two concern SJCC’s San Juan mine.  WEG’s allegations concerning the San Juan mine arise from OSM administrative actions in 2008.  WEG alleges various National Environmental Policy Act violations against OSM, including, but not limited to, OSM’s alleged failure to provide requisite public notice and participation, alleged failure to analyze certain environmental impacts, and alleged reliance on outdated and insufficient documents.  WEG’s petition seeks various forms of relief, including voiding, reversing, and remanding the various mining modification approvals, enjoining the federal defendants from re-issuing the mining plan approvals for the mines, and enjoining operations at the seven mines. SJCC intervened in this matter. The Court granted SJCC’s motion to sever its claims from the lawsuit and transfer venue to the United States District Court for the District of New Mexico. PNM cannot currently predict the outcome of this matter or the range of its potential impact.

Navajo Nation Environmental Issues

Four Corners is located on the Navajo Reservation and is held under an easement granted by the federal government, as well as a lease from the Navajo Nation. The Navajo Acts purport to give the Navajo Nation Environmental Protection Agency authority to promulgate regulations covering air quality, drinking water, and pesticide activities, including those activities that occur at Four Corners. In October 1995, the Four Corners participants filed a lawsuit in the District Court of the Navajo Nation challenging the applicability of the Navajo Acts to Four Corners. Although an agreement was reached resolving claims related to the CAA, the agreement does not address or resolve any dispute relating to other aspects of the Navajo Acts. PNM cannot currently predict the outcome of these matters or the range of their potential impacts.

Cooling Water Intake Structures

EPA issued its proposed cooling water intake structures rule in April 2011, which would provide national standards for certain cooling water intake structures at existing power plants and other facilities under the Clean Water Act to protect fish and other aquatic organisms by minimizing impingement mortality (the capture of aquatic wildlife on intake structures or against screens) and entrainment mortality (the capture of fish or shellfish in water flow entering and passing through intake structures). The proposed rule would require facilities such as Four Corners and SJGS to either demonstrate that impingement mortality at its cooling water intakes does not exceed a specified rate or reduce the flow at those structures to less than a specified velocity and to take certain protective measures with respect to impinged fish. The proposed rule would also require these facilities to either meet the definition of a closed cycle recirculating cooling system or conduct a “structured site-specific analysis” to determine what site-specific controls, if any, should be required.

The proposed rule would require existing facilities to comply with the impingement mortality requirements as soon as possible, but no later than eight years after the effective date of the rule, and to comply with the entrainment requirements as soon as possible under a schedule of compliance established by the permitting authority. EPA was required to issue a final rule by June 27, 2013; however, that date was extended to January 14, 2014. On January 10, 2014, EPA announced it would not meet that deadline. On February 10, 2014, EPA indicated it would issue the final rule by April 17, 2014 and did not intend to seek any more extensions. However, on April 16, 2014, EPA announced the final rule will not be published until May 16, 2014 due to the pending consultation activities with the U.S. Fish and Wildlife Service and the National Marine Fisheries Service. PNM and APS continue to follow the rulemaking and are performing analyses to determine the potential costs of compliance with the proposed rule. PNM is unable to predict the outcome of this matter or a range of the potential costs of compliance.

Effluent Limitation Guidelines

On June 7, 2013, EPA published proposed revised wastewater effluent limitation guidelines establishing technology-based wastewater discharge limitations for fossil fuel-fired electric power plants.  EPA’s proposal offers numerous options that target metals and other pollutants in wastewater streams originating from fly ash and bottom ash handling activities, scrubber activities, and non-chemical metal cleaning waste operations.  The preferred alternatives differ with respect to the scope of requirements that would be applicable to existing discharges of pollutants found in wastestreams generated at existing power plants. All four alternatives would establish a “zero discharge” effluent limit for all pollutants in fly ash transport water. However, requirements governing bottom ash transport water differ depending on which alternative EPA ultimately chooses and could range from effluent limits based on Best Available Technology Economically Achievable to “zero discharge” effluent limits. Depending on which alternative EPA finalizes, Four Corners may be required to change equipment and operating practices affecting boilers and ash handling systems, as well as change its waste disposal techniques. PNM has reviewed the proposed rule and continues to assess the potential impact to SJGS and Reeves Station, the only PNM-operated power plants that would be covered by the proposed rule. On April 9, 2014, several environmental groups agreed to allow EPA until September 30, 2015 to issue final effluent limits. Under the agreement, EPA will not seek any further extensions and will follow through on a separate agreement to issue a final rule on coal ash waste disposal by December 19, 2014. If EPA misses the December 19, 2014 deadline to issue a coal ash rule, then the agreement allows the environmental groups to require the EPA to issue the final effluent limits earlier. PNM is unable to predict the outcome of this matter or a range of the potential costs of compliance. 

Santa Fe Generating Station

PNM and the NMED are parties to agreements under which PNM installed a remediation system to treat water from a City of Santa Fe municipal supply well, an extraction well, and monitoring wells to address gasoline contamination in the groundwater at the site of the former Santa Fe Generating Station and service center. PNM believes the observed groundwater contamination originated from off-site sources, but agreed to operate the remediation facilities until the groundwater meets applicable federal and state standards or until the NMED determines that additional remediation is not required, whichever is earlier. The City of Santa Fe has indicated that since the City no longer needs the water from the well, the City would prefer to discontinue its operation and maintain it only as a backup water source. However, for PNM’s groundwater remediation system to operate, the water well must be in service. Currently, PNM is not able to assess the duration of this project or estimate the impact on its obligations if the City of Santa Fe ceases to operate the water well.

The Superfund Oversight Section of the NMED has conducted multiple investigations into the chlorinated solvent plume in the vicinity of the site of the former Santa Fe Generating Station. In February 2008, a NMED site inspection report was submitted to EPA, which states that neither the source nor extent of contamination has been determined and also states that the source may not be the former Santa Fe Generating Station. The NMED investigation is ongoing. In January 2013, NMED notified PNM that monitoring results from April 2012 showed elevated concentrations of nitrate in three monitoring wells and an increase in free-phase hydrocarbons in another well. None of these wells are routinely monitored as part of PNM’s obligations under the settlement agreement. In April 2013, NMED conducted the same level of testing on the wells as was conducted in April 2012, which produced similar results. PNM voluntarily agreed to conduct similar sampling activities on the site beginning in April 2014, as well as more specific “fingerprint” analysis, which may help identify potential off-site sources. PNM is unable to predict the outcome of this matter and does not believe the former generating station is the source of the nitrates or the increased levels of free-phase hydrocarbons, but no conclusive determinations have been made.

Coal Combustion Byproducts Waste Disposal

CCBs consisting of fly ash, bottom ash, and gypsum from SJGS are currently disposed of in the surface mine pits adjacent to the plant. SJGS does not operate any CCB impoundments. The Mining and Minerals Division of the New Mexico Energy, Minerals and Natural Resources Department currently regulates mine placement of ash with federal oversight by the OSM. APS disposes of CCBs in ash ponds and dry storage areas at Four Corners and also sells a portion of its fly ash for beneficial uses, such as a constituent in concrete production.  Ash management at Four Corners is regulated by EPA and the New Mexico State Engineer’s Office. 

In June 2010, EPA published a proposed rule that includes two options for waste designation of coal ash. One option is to regulate CCBs as a hazardous waste, which would allow EPA to create a comprehensive federal program for waste management and disposal of CCBs. The other option is to regulate CCBs as a non-hazardous waste, which would provide EPA with the authority to develop performance standards for waste management facilities handling the CCBs and would be enforced primarily by state authorities or through citizen suits. Both options allow for continued use of CCBs in beneficial applications. EPA’s proposal does not address the placement of CCBs in surface mine pits for reclamation. An OSM CCB rulemaking team has been formed to develop a proposed rule. 

On April 5, 2012, several environmental groups, including Sierra Club, filed a citizen suit in the D.C. Circuit claiming that EPA has failed to review and revise RCRA’s regulations with respect to CCBs. The groups allege that EPA has already determined that revisions to the CCBs regulations are necessary and that EPA now has a non-discretionary duty to revise the regulations. The environmental groups asked the court to direct EPA to complete its review of the regulation of CCBs and a hazardous waste analytical procedure and to issue necessary revisions of such regulations as soon as possible. Two industry group members subsequently filed separate lawsuits in the D.C. Circuit seeking to ensure that disposal of coal ash would not be regulated as a hazardous waste. The environmental and industry lawsuits have been consolidated. On January 29, 2014, EPA entered into a consent decree directing EPA to publish its final action regarding whether or not to pursue the proposed non-hazardous waste option for CCBs by December 19, 2014.

PNM advocates for the non-hazardous regulation of CCBs. If CCBs are ultimately regulated as a hazardous waste, costs could increase significantly. PNM would seek recovery from its ratepayers of all costs that are ultimately incurred. PNM cannot predict the outcome of EPA’s or OSM’s proposed rulemaking regarding CCB regulation, including mine placement of CCBs, or whether these actions will have a material impact on its operations, financial position, or cash flows.

Hazardous Air Pollutants (“HAPs”) Rulemaking

In December 2011, the EPA issued its final Mercury and Air Toxics Standards (“MATS”) to reduce emissions of heavy metals, including mercury, arsenic, chromium, and nickel, as well as acid gases, including hydrochloric and hydrofluoric gases, from coal and oil-fired electric generating units with a capacity of at least 25 MW. Existing facilities will generally have up to four years to demonstrate compliance with the new rule. PNM’s assessment of MATS indicates that the control equipment currently used at SJGS allows the plant to meet the emission standards set forth in the rule. With regard to mercury, stack testing performed for EPA during the MATS rulemaking process showed that SJGS achieved a mercury removal rate of 99% or greater. APS has determined that no additional equipment will be required at Four Corners Units 4 and 5 to comply with the rule. 

Other Commitments and Contingencies

Coal Supply

The coal requirements for SJGS are being supplied by SJCC, a wholly owned subsidiary of BHP. In addition to coal delivered to meet the current needs of SJGS, PNM prepays SJCC for certain coal mined but not yet delivered to the plant site. At March 31, 2014 and December 31, 2013, prepayments for coal, which are included in other current assets, amounted to $16.0 million and $12.3 million. These amounts reflect delivery of a portion of the prepaid coal and its utilization due to the mine fire incident described below. SJCC holds certain federal, state, and private coal leases and has an underground coal sales agreement to supply processed coal for operation of SJGS through 2017. Under the coal sales agreement, SJCC is reimbursed for all costs for mining and delivering the coal, including an allocated portion of administrative costs, and receives a return on its investment. BHP Minerals International, Inc. has guaranteed the obligations of SJCC under the coal agreement. The coal agreement contemplates the delivery of coal that would supply substantially all the requirements of SJGS through December 31, 2017.

APS purchases all of Four Corners’ coal requirements from a supplier that was also a subsidiary of BHP and had a long-term lease of coal reserves with the Navajo Nation. That contract was to expire on July 6, 2016 with pricing determined using an escalating base-price. On December 30, 2013, ownership of the mine was transferred to an entity owned by the Navajo Nation and a new coal supply contract for Four Corners, expiring in 2031, was entered into with that entity. The BHP subsidiary is to be retained as the mine manager and operator until July 2016. Coal costs are anticipated to increase approximately 21% for the first full year of the new contract and will further increase over the contract term. PNM anticipates that its share of the increased costs will be recovered through its FPPAC.

In 2013, PNM updated its study of the final reclamation costs for both the surface mines that previously provided coal to SJGS and the current underground mine providing coal and revised its estimates of the final reclamation costs. This estimate reflects that, with the proposed shutdown of SJGS Units 2 and 3 described above, the mine providing coal to SJGS will continue to operate through 2053, the anticipated life of SJGS. The 2013 estimate for decommissioning the Four Corners mine reflects the operation of the mine through 2031, the term of the new coal supply agreement. Based on the 2013 estimates, remaining payments for mine reclamation, in future dollars, are estimated to be $55.1 million for the surface mines at both SJGS and Four Corners and $93.3 million for the underground mine at SJGS as of March 31, 2014. At March 31, 2014 and December 31, 2013, liabilities, in current dollars, of $23.6 million and $23.8 million for surface mine reclamation and $7.9 million and $7.8 million for underground mine reclamation were recorded in other deferred credits.

PNM collects a provision for surface and underground mine reclamation costs in its rates. The NMPRC has capped the amount that can be collected from ratepayers for final reclamation of the surface mines at $100.0 million. Previously, PNM recorded a regulatory asset for the $100.0 million and recovers the amortization of this regulatory asset in rates. If future estimates increase the liability for surface mine reclamation, the excess would be expensed at that time. In conjunction with the proposed shutdown of SJGS Units 2 and 3 to comply with the BART requirements of the CAA discussed under The Clean Air Act - Regional Haze - SJGS above, an updated coal mine reclamation study was requested by the SJGS participants. As discussed under Coal Combustion Byproducts Waste Disposal above, SJGS currently disposes of CCBs from the plant in the surface mine pits adjacent to the plant. The updated coal mine reclamation study indicates reclamation costs have increased, including significant increases due to the proposed shutdown of SJGS Units 2 and 3, although the timing of payments will be delayed. The shutdown of Units 2 and 3 would reduce the amount of CCBs generated over the remaining life of SJGS, which could result in a significant increase in the amount of fill dirt required to remediate the underground mine area thereby increasing the overall reclamation costs. It has not been decided how costs would be divided among the owners of SJGS. Regulatory determinations made by the NMPRC may also affect the impact on PNM. The reclamation amounts discussed above reflect PNM’s estimates of its share of the revised costs. PNM is currently unable to determine the outcome of these matters or the range of possible impacts.

San Juan Underground Mine Fire Incident

On September 9, 2011, a fire was discovered at the underground mine owned and operated by SJCC that provides coal for SJGS. The federal Mine Safety and Health Administration (“MSHA”) was notified of the incident. On September 12, 2011, SJCC informed PNM that the fire was extinguished. However, MSHA required sealing the incident area and confirmation of a noncombustible environment before allowing re-entry of the sealed area. SJCC regained entry into the sealed area of the mine in early March 2012. At that time, MSHA conducted a root cause analysis inspection of the incident area, but has not yet issued its report. SJCC has completed inspection of the mine equipment and reported no significant damage. SJCC removed the equipment from the impacted mine panel and reassembled it at a new panel face. On May 4, 2012, SJCC received approval from MSHA and resumed longwall mining operations.

The costs of the mine recovery flowed through the cost-reimbursable component of the coal supply agreement. PNM included the portion of such costs allocable to its customers subject to New Mexico regulation in its FPPAC. PNM’s filings with the NMPRC reflected an estimate that this incident increased coal costs and the deferral of cost recovery under the FPPAC by between $17.4 million and $21.6 million. SJCC submitted an insurance claim regarding the costs it incurred due to the mine fire and informed PNM that it settled with its insurance carrier. PNM’s portion of the insurance recovery is estimated to be $18.7 million. PNM has credited its FPPAC balancing account for the amount of its estimated insurance proceeds allocable to PNM’s New Mexico jurisdictional customers. SJCC is refunding the insurance recovery to the owners of SJGS through reductions of the cost of purchases under the coal supply agreement. See Note 12.

Continuous Highwall Mining Royalty Rate

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

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

SJCC Arbitration

The coal supply agreement for SJGS provides that the participants in SJGS have the right to audit the costs billed by SJCC. An independent accounting firm has been engaged to perform audits of the costs billed under the provisions of the contract. The audit for the period from 2006 through 2009 resulted in disagreements between the SJGS participants and SJCC. As provided in the contract, certain issues have been submitted to a panel for binding arbitration. The issues are: 1) whether the SJGS participants owe SJCC unbilled mining costs of $5.2 million or whether SJCC owes the SJGS participants overbilled mining costs of $1.1 million, and 2) whether SJCC billed the SJGS participants $13.9 million as mining costs that SJCC should have considered to be capital costs, which are not billable under the mining contract.  PNM’s share of any amounts resulting from the arbitration would be approximately 46.3%. Of PNM’s share of the costs, approximately 33% of the first issue as well as approximately 25% of the second issue would be passed through PNM’s FPPAC and the rest would impact earnings. A hearing before the arbitration panel on the remaining issues is scheduled to be held in May 2014. PNM is unable to predict the outcome of the arbitration hearing.

Four Corners Severance Tax Assessment

On May 23, 2013, the New Mexico Taxation and Revenue Department (“NMTRD”) issued a notice of assessment for coal severance surtax, penalty, and interest totaling approximately $30 million related to coal supplied under the coal supply agreement for Four Corners. PNM’s share of any amounts paid related to this assessment would be approximately 8%, all of which would be passed through PNM’s FPPAC. For procedural reasons, on behalf of the Four Corners co-owners, including PNM, the coal supplier made a partial payment of the assessment and immediately filed a refund claim with respect to that partial payment in August 2013. The NMTRD denied the refund claim. On December 19, 2013, the coal supplier and APS, on its own behalf and as operating agent for Four Corners, filed a complaint in the New Mexico District Court contesting both the validity of the assessment and the refund claim denial. PNM believes the assessment and the refund claim denial are without merit, but cannot predict the outcome of this matter.

PVNGS Liability and Insurance Matters

Public liability for incidents at nuclear power plants is governed by the Price-Anderson Act, which limits the liability of nuclear reactor owners to the amount of insurance available from both private sources and an industry retrospective payment plan. In accordance with the Price-Anderson Act, the PVNGS participants have insurance for public liability exposure for a nuclear incident totaling $13.6 billion per occurrence. Commercial insurance carriers provide $375 million and $13.2 billion is provided through a mandatory industry wide retrospective assessment program. If losses at any nuclear power plant covered by the program exceed the accumulated funds, PNM could be assessed retrospective premium adjustments. Based on PNM’s 10.2% interest in each of the three PVNGS units, PNM’s maximum potential retrospective premium assessment per incident for all three units is $38.9 million, with an annual payment limitation of $5.7 million.

The PVNGS participants maintain “all risk” (including nuclear hazards) insurance for damage to, and decontamination of, property at PVNGS in the aggregate amount of $2.75 billion, a substantial portion of which must first be applied to stabilization and decontamination. These coverages are provided by Nuclear Electric Insurance Limited (“NEIL”). Effective April 1, 2014, a sublimit of $2.25 billion for non-nuclear property damage losses has been enacted to the primary policy offered by NEIL. If NEIL’s losses in any policy year exceed accumulated funds, PNM is subject to retrospective assessments of $4.8 million for each retrospective assessment declared by NEIL’s Board of Directors. The insurance coverages discussed in this and the previous paragraph are subject to policy conditions and exclusions.

Water Supply

Because of New Mexico’s arid climate and periodic drought conditions, there is concern in New Mexico about the use of water, including that used for power generation. PNM has secured groundwater rights in connection with the existing plants at Reeves Station, Delta, Afton, Luna, and Lordsburg. Water availability is not an issue for these plants at this time. However, prolonged drought, ESA activities, and a Federal lawsuit by the State of Texas (suing the State of New Mexico over water allocations) could pose a threat of reduced water availability for these plants.

PNM, APS, and BHP have undertaken activities to secure additional water supplies for SJGS, Four Corners, and related mines to accommodate the possibility of inadequate precipitation in coming years. Since 2004, PNM has entered into agreements for voluntary sharing of the impacts of water shortages with tribes and other water users in the San Juan basin. This agreement has been extended through 2016. In addition, in the case of water shortage, PNM, APS, and BHP have reached agreement with the Jicarilla Apache Nation on a long-term supplemental contract relating to water for SJGS and Four Corners that runs through 2016. Although PNM does not believe that its operations will be materially affected by drought conditions at this time, it cannot forecast the weather or its ramifications, or how policy, regulations, and legislation may impact PNM should water shortages occur in the future.

In April 2010, APS signed an agreement on behalf of the PVNGS participants with five cities to provide cooling water essential to power production at PVNGS for forty years.

PVNGS Water Supply Litigation

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

San Juan River Adjudication

In 1975, the State of New Mexico filed an action in New Mexico District Court to adjudicate all water rights in the San Juan River Stream System, including water used at Four Corners and SJGS. PNM was made a defendant in the litigation in 1976. In March 2009, President Obama signed legislation confirming a 2005 settlement with the Navajo Nation. Under the terms of the settlement agreement, the Navajo Nation’s water rights would be settled and finally determined by entry by the court of two proposed adjudication decrees.  The court issued an order in August 2013 finding that no evidentiary hearing was warranted in the Navajo Nation proceeding, and on November 1, 2013 issued a Partial Final Judgment and Decree of the Water Rights of the Navajo Nation approving the proposed settlement with the Navajo Nation. Several parties filed a joint motion for a new trial, which was denied by the court. A number of parties subsequently appealed to the New Mexico Court of Appeals. PNM is in the process of entering its appearance in the appellate case. No hearing dates or deadlines have been set at this time.

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

Rights-of-Way Matter

On January 28, 2014, the County Commission of Bernalillo County, New Mexico passed an ordinance requiring utilities to enter into a use agreement and pay a yet to be determined fee as a condition to installing, maintaining, and operating facilities on county rights-of-way. The fee is purported to compensate the county for costs of administering, maintaining, and capital improvements to the rights-of-way. On February 27, 2014, PNM and other utilities filed a Complaint for Declaratory and Injunctive Relief in the United States District Court for the District of New Mexico challenging the validity of the ordinance. If the challenge to the ordinance is unsuccessful, PNM believes any fees paid pursuant to the ordinance would be considered franchise fees and would be recoverable from customers. PNM is unable to predict the outcome of this matter or its impact on PNM’s operations.

Complaint Against Southwestern Public Service Company

In September 2005, PNM filed a complaint under the Federal Power Act against SPS alleging SPS overcharged PNM for deliveries of energy through its fuel cost adjustment clause practices and that rates for sales to PNM were excessive. PNM also intervened in a proceeding brought by other customers raising similar arguments relating to SPS’ fuel cost adjustment clause practices and issues relating to demand cost allocation (the “Golden Spread Proceeding”). In addition, PNM intervened in a proceeding filed by SPS to revise its rates for sales to PNM (“SPS 2006 Rate Proceeding”). In 2008, FERC issued its order in the Golden Spread Proceeding affirming an ALJ decision that SPS violated its fuel cost adjustment clause tariffs, but shortening the refund period applicable to the violation of the fuel cost adjustment clause issues that had been ordered by the ALJ.  FERC also reversed the decision of the ALJ, which had been favorable to PNM, on the demand cost allocation issues. PNM and SPS filed petitions for rehearing and clarification of the scope of the remedies that were ordered and seeking reversal of various rulings in the order. On August 15, 2013, FERC issued separate orders in the Golden Spread Proceeding and in the SPS 2006 Rate Proceeding. The order in the Golden Spread Proceeding determined that PNM was not entitled to refunds for SPS’ fuel cost adjustment clause practices. That order and the order in the SPS 2006 Rate Proceeding decided the demand cost allocation issues using the method that PNM had advocated.  PNM, SPS, and other customers of SPS have filed requests for rehearing of these orders and they are pending further action by FERC. PNM cannot predict the final outcome of the case at FERC or the range of possible outcomes.

Navajo Nation Allottee Matters

A putative class action was filed against PNM and other utilities in February 2009 in the United States District Court for the District of New Mexico. Plaintiffs claim to be allottees, members of the Navajo Nation, who pursuant to the Dawes Act of 1887, were allotted ownership in land carved out of the Navajo Nation and allege that defendants, including PNM, are rights-of-way grantees with rights-of-way across the allotted lands and are either in trespass or have paid insufficient fees for the grant of rights-of-way or both.  In March 2010, the court ordered that the entirety of the plaintiffs’ case be dismissed. The court did not grant plaintiffs leave to amend their complaint, finding that they instead must pursue and exhaust their administrative remedies before seeking redress in federal court.  In May 2010, plaintiffs filed a Notice of Appeal with the Bureau of Indian Affairs (“BIA”), which was denied by the BIA Regional Director. In May 2011, plaintiffs appealed the Regional Director’s decision to the DOI, Office of Hearings and Appeals, Interior Board of Indian Appeals. Following briefing on the merits, on August 20, 2013, that board issued a decision upholding the Regional Director’s decision that the allottees had failed to perfect their appeals, and dismissed the allottees’ appeals, without prejudice.  The allottees have not refiled their appeals. Although this matter was dismissed without prejudice, PNM considers the matter concluded. However, PNM continues to monitor this matter in order to preserve its interests regarding any PNM-acquired rights-of-way.

In a separate matter, in September 2012, forty-three landowners claiming to be Navajo allottees filed a notice of appeal with the BIA appealing a March 2011 decision of the BIA Regional Director regarding renewal of a right-of-way for a PNM transmission line. The allottees, many of whom are also allottees in the above matter, generally allege that they were not paid fair market value for the right-of-way, that they were denied the opportunity to make a showing as to their view of fair market value, and thus denied due process. On January 6, 2014, PNM received notice that the BIA, Navajo Region, requested a review of an appraisal report on 58 allotment parcels. After review, the BIA concluded it would continue to rely on the values of the original appraisal. On March 27, 2014, while this matter was stayed, the allottees filed a motion to dismiss their appeal with prejudice.  On April 2, 2014, the allotees’ appeal was dismissed with prejudice concluding this matter.

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Fair Value of Derivative and Other Financial Instruments

3 Months Ended

Mar. 31, 2014

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

Energy Related Derivative Contracts

Overview

The primary objective for the use of derivative instruments, including energy contracts, options, 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. The Company’s energy related derivative contracts manage commodity risk. PNM is required to meet the demand and energy needs of its retail and firm-requirements wholesale customers. PNM is exposed to market risk for its share of PVNGS Unit 3 and the needs of its firm-requirements wholesale customers not covered under a FPPAC. PNM’s operations are managed primarily through a net asset-backed strategy, whereby PNM’s aggregate net open forward contract position is covered by its forecasted excess generation capabilities or market purchases. PNM could be exposed to market risk if its generation capabilities were to be disrupted or if its load requirements were to be greater than anticipated. If all or a portion of load requirements were required to be covered as a result of such unexpected situations, commitments would have to be met through market purchases. Additional information concerning the Company’s energy related derivative contracts, including how commodity risk is managed, is contained in Note 8 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K.

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. Energy contracts that meet the definition of a derivative under GAAP and do not qualify, or are not designated, for the normal purchases and normal sales exception are recorded on the balance sheet at fair value at each period end. The changes in fair value are recognized in earnings unless specific hedge accounting criteria are met and elected. Normal purchases and normal sales are not marked to market and are reflected in results of operations when the underlying transactions settle.

During the three months ended March 31, 2014 and the year ended December 31, 2013, 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.

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.

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
	March 31, 2014			December 31, 2013
PNMR and PNM	(In thousands)
Current assets	$	4,003		$	4,064
Deferred charges	2,474			3,002
	6,477			7,066
Current liabilities	(5,446		)	(2,699		)
Long-term liabilities	(907		)	(1,094		)
	(6,353		)	(3,793		)
Net	$	124		$	3,273

Included in the above table are $3.0 million of current assets and $2.3 million of deferred charges at March 31, 2014 and $3.0 million of current assets and $3.0 million of deferred charges at December 31, 2013 related to contracts, which were entered into in July 2013, for the sale of energy from PVNGS Unit 3 for 2014 and 2015 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 March 31, 2014 and December 31, 2013.

At March 31, 2014 and December 31, 2013, PNMR and PNM had no amounts recognized for the legal right to reclaim cash collateral. However, at March 31, 2014 and December 31, 2013, amounts posted as cash collateral under margin arrangements were $3.1 million and $2.8 million for both PNMR and PNM. PNMR and PNM had obligations to return cash collateral of approximately $0.1 million at March 31, 2014 and $0.2 million at December 31, 2013. Cash collateral amounts are included in other current assets and other current liabilities on the Condensed 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 $0.4 million of current assets and $0.6 million of current liabilities at March 31, 2014 and $0.4 million of current assets and $0.1 million of current liabilities at December 31, 2013 related to this plan. The offsets to these amounts are recorded as regulatory assets and liabilities on the Condensed 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
	Three Months Ended
	March 31,
	2014			2013
PNMR and PNM	(In thousands)
Electric operating revenues	$	(4,151	)	$	(4,603	)
Cost of energy	189			756
Total gain (loss)	$	(3,962	)	$	(3,847	)

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
March 31, 2014
PNMR and PNM	775,000	(3,287,548	)
December 31, 2013
PNMR and PNM	905,000	(3,343,783	)

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)
March 31, 2014
PNMR and PNM	$	2,981	$	—	$	1,913
December 31, 2013
PNMR and PNM	$	2,398	$	—	$	2,152

Sale of Power from PVNGS Unit 3

Because PNM’s 134 MW share of Unit 3 at PVNGS is not included in retail rates, that unit’s power is being sold in the wholesale market. Since January 1, 2011, PNM has been selling power from its interest in PVNGS Unit 3 at market prices. As of March 31, 2014, PNM had contracted to sell 100% of PVNGS Unit 3 output through 2015, at market price plus a premium.  PNM has established fixed rates, which average approximately $37 per MWh, for substantially all of these sales through the end of 2014 through hedging arrangements that are accounted for as economic hedges. PNM is also partially hedged for 2015.

Non-Derivative Financial Instruments

The carrying amounts reflected on the Condensed Consolidated Balance Sheets approximate fair value for cash, receivables, and payables due to the short period of maturity. 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 a trust for PNM’s share of post-term reclamation costs related to the coal mines serving SJGS (Note 11). The fair value and gross unrealized gains of investments in available-for-sale securities are presented in the following table. At March 31, 2014 and December 31, 2013, the fair value of available-for-sale securities included $225.8 million and $222.5 million for the NDT and $4.4 million and $4.4 million for the mine reclamation trust.

	March 31, 2014				December 31, 2013
	Unrealized Gains		Fair Value		Unrealized Gains		Fair Value
PNMR and PNM			(In thousands)
Cash and cash equivalents	$	—	$	4,246	$	—	$	3,356
Equity securities:
Domestic value	14,558		41,055		14,523		39,460
Domestic growth	23,002		74,517		25,656		76,292
International and other	1,671		17,264		1,040		16,633
Fixed income securities:
U.S. Government	377		20,662		158		21,941
Municipals	2,659		61,158		1,018		58,568
Corporate and other	458		11,348		207		10,605
	$	42,725	$	230,250	$	42,602	$	226,855

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.

	Three Months Ended
	March 31,
	2014			2013
	(In thousands)
Proceeds from sales	$	22,804		$	14,284
Gross realized gains	$	3,119		$	1,391
Gross realized (losses)	$	(545	)	$	(407	)

Held-to-maturity securities are those investments in debt securities that the Company has the ability and intent to hold until maturity. Held-to-maturity securities consist of the investment in PVNGS lessor notes and certain items within other investments.

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 March 31, 2014, 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		PNM
	(In thousands)
Within 1 year	$	2,798	$	11,968	$	11,968
After 1 year through 5 years	21,550		33,618		32,903
After 5 years through 10 years	11,895		—		—
After 10 years through 15 years	8,521		—		—
After 15 years through 20 years	10,705		—		—
After 20 years	37,699		—		—
	$	93,168	$	45,586	$	44,871

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.

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 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, primarily the PVNGS lessor notes and other investments, fair values were determined by discounted cash flow models that take into consideration discount rates that are observable for similar type assets and liabilities. Management of the Company independently verifies the information provided by pricing services.

Items recorded at fair value on the Condensed Consolidated Balance Sheets are presented below by level of the fair value hierarchy. There were no Level 3 fair value measurements at March 31, 2014 and December 31, 2013 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 (Level 2)
March 31, 2014	(In thousands)
PNMR and PNM
Available-for-sale securities
Cash and cash equivalents	$	4,246		$	4,246	$	—
Equity securities:
Domestic value	41,055			41,055		—
Domestic growth	74,517			74,517		—
International and other	17,264			17,264		—
Fixed income securities:
U.S. Government	20,662			18,909		1,753
Municipals	61,158			—		61,158
Corporate and other	11,348			2,385		8,963
	$	230,250		$	158,376	$	71,874
Commodity derivative assets	$	6,477		$	—	$	6,477
Commodity derivative liabilities	(6,353		)	—		(6,353		)
Net	$	124		$	—	$	124
December 31, 2013
PNMR and PNM
Available-for-sale securities
Cash and cash equivalents	$	3,356		$	3,356	$	—
Equity securities:
Domestic value	39,460			39,460		—
Domestic growth	76,292			76,292		—
International and other	16,633			16,633		—
Fixed income securities:
U.S. Government	21,941			20,194		1,747
Municipals	58,568			—		58,568
Corporate and other	10,605			2,245		8,360
	$	226,855		$	158,180	$	68,675
Commodity derivative assets	$	7,066		$	—	$	7,066
Commodity derivative liabilities	(3,793		)	—		(3,793		)
Net	$	3,273		$	—	$	3,273

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 three months ended March 31, 2014 and 2013.

The carrying amounts and fair values of investments in PVNGS lessor notes, other investments, and long-term debt, which are not recorded at fair value on the Condensed Consolidated Balance Sheets are presented below:

					GAAP Fair Value Hierarchy
	Carrying Amount		Fair Value		Level 1		Level 2		Level 3
March 31, 2014	(In thousands)
PNMR
Long-term debt	$	1,845,338	$	2,040,868	$	—	$	2,040,868	$	—
Investment in PVNGS lessor notes	$	42,472	$	44,871	$	—	$	—	$	44,871
Other investments	$	1,813	$	2,529	$	681	$	—	$	1,848
PNM
Long-term debt	$	1,390,627	$	1,515,097	$	—	$	1,515,097	$	—
Investment in PVNGS lessor notes	$	42,472	$	44,871	$	—	$	—	$	44,871
Other investments	$	436	$	436	$	436	$	—	$	—
TNMP
Long-term debt	$	335,944	$	396,195	$	—	$	396,195	$	—
Other investments	$	245	$	245	$	245	$	—	$	—
December 31, 2013
PNMR
Long-term debt	$	1,745,420	$	1,905,230	$	—	$	1,905,230	$	—
Investment in PVNGS lessor notes	$	52,958	$	57,279	$	—	$	—	$	57,279
Other investments	$	1,835	$	3,196	$	690	$	—	$	2,506
PNM
Long-term debt	$	1,290,618	$	1,382,938	$	—	$	1,382,938	$	—
Investment in PVNGS lessor notes	$	52,958	$	57,279	$	—	$	—	$	57,279
Other investments	$	445	$	445	$	445	$	—	$	—
TNMP
Long-term debt	$	336,036	$	390,814	$	—	$	390,814	$	—
Other investments	$	245	$	245	$	245	$	—	$	—

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Variable Interest Entities

3 Months Ended

Mar. 31, 2014

Variable Interest Entities

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. GAAP also requires continual reassessment of the primary beneficiary of a variable interest entity. Additional information concerning PNM’s variable interest entities is contained in Note 9 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K.

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. 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 three months ended March 31, 2014 and 2013, PNM paid $4.8 million and $4.7 million for fixed charges and $0.2 million and $0.1 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 has concluded that the third party entity that owns Valencia is a variable interest entity 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. The assets and liabilities of Valencia set forth below are immaterial to PNM and, therefore, not shown separately on the Condensed Consolidated Balance Sheets. The owner’s equity and net income of Valencia are considered attributable to non-controlling interest.

Summarized financial information for Valencia is as follows:

Results of Operations

	Three Months Ended March 31,
	2014			2013
	(In thousands)
Operating revenues	$	4,931		$	4,775
Operating expenses	(1,400		)	(1,571		)
Earnings attributable to non-controlling interest	$	3,531		$	3,204

Financial Position

	March 31,		December 31,
	2014		2013
	(In thousands)
Current assets	$	2,780	$	2,658
Net property, plant, and equipment	74,433		75,137
Total assets	77,213		77,795
Current liabilities	1,022		766
Owners’ equity – non-controlling interest	$	76,191	$	77,029

During the term of the PPA, PNM has the option to purchase and own up to 50% of the plant or the variable interest entity.

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 has been initiated since the parties failed to reach agreement on fair market value within 60 days. After the purchase price has been determined through the appraisal process, PNM may in its sole discretion determine whether or not it desires to exercise its option to purchase the 50% interest. In that regard, PNM will evaluate all its alternatives with respect to Valencia with the goal of achieving a fair and economical benefit for its customers. Also, PNM is in the process of developing its 2014 IRP (Note 12). Through this process, PNM will evaluate all of its resource options, including Valencia, to determine the optimal way to serve its customers. If PNM decides to exercise its option, the approval of the NMPRC and FERC would be required, which process could take up to 15 months. Since the purchase price is yet to be established, PNM cannot determine whether or not it will exercise its option or if required regulatory approvals would be received.

PVNGS Leases

PNM leases interests in Units 1 and 2 of PVNGS under arrangements, which were entered into in 1985 and 1986, that are accounted for as operating leases. PNM is not the legal or tax owner of the leased assets. The leases provide PNM with an option to purchase the leased assets at appraised value at the end of the leases. PNM does not have a fixed price purchase option and does not provide residual value guarantees. The leases also provide PNM with options to renew the leases at fixed rates set forth in the leases for two years beyond the termination of the original lease terms. The option periods on certain leases may be further extended for up to an additional six years if the appraised remaining useful lives and fair value of the leased assets are greater than parameters set forth in the leases. See Note 7 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K and Note 6, for additional information regarding the leases and actions PNM has taken with respect to its renewal and purchase options. Under GAAP, these renewal options are considered to be variable interests in the trusts and result in the trusts being considered variable interest entities.

PNM is only obligated to make payments to the trusts for the scheduled semi-annual lease payments, which, net of amounts that will be returned to PNM through its ownership in related lessor notes and the Unit 2 beneficial trust, aggregate $36.5 million as of March 31, 2014 over the remaining original terms of the leases and $145.2 million during the renewal terms of the leases that PNM elected to renew. Under certain circumstances (for example, final shutdown of the plant, 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 beneficial owners and take title to the leased interests. If such an event had occurred as of March 31, 2014, PNM could have been required to pay the beneficial owners up to $144.7 million, which would result in PNM taking ownership of the leased assets and termination of the leases. Other than as discussed in Note 6, PNM has no other financial obligations or commitments to the trusts or the beneficial owners. 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 evaluated the PVNGS lease arrangements, including the notices, amendments, and agreements referred to above, and concluded that it does not have the power to direct the activities that most significantly impact the economic performance of the trusts and, therefore, is not the primary beneficiary of the trusts under GAAP. PNM has recorded no assets or liabilities related to the trusts other than the accrual of lease payments between the scheduled payment dates, which were $11.8 million at March 31, 2014 and $26.0 million at December 31, 2013, that are included in other current liabilities on the Condensed Consolidated Balance Sheets.

Delta

PNM has a 20-year PPA expiring in 2020 covering the entire output of Delta, which is a variable interest under GAAP. PNM also controls the dispatch of the generating plant, which impacts the variable payments made under the PPA and impacts the economic performance of the entity that owns Delta. PNM makes fixed and variable payments to Delta under the PPA. For the three months ended March 31, 2014 and 2013, PNM incurred fixed capacity charges of $1.6 million and $1.6 million and variable energy charges of $0.2 million and $0.2 million under the PPA. PNM’s only quantifiable obligation under the PPA is to make the fixed payments, which as of March 31, 2014, aggregated $37.7 million through the end of the PPA. PNM will also pay variable costs, which cannot be quantified since the amounts are based on how much the generating plant is in operation.

This arrangement was entered into prior to December 31, 2003 and PNM was unsuccessful in obtaining the information necessary to determine if it is the primary beneficiary of the entity that owns Delta, or to consolidate that entity if it were determined that PNM is 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 owns Delta. At closing PNM would make a cash payment of $23.0 million, which would be adjusted for actual working capital compared to a targeted working capital and certain prepayments of debt. Delta has project financing debt, which PNM would retire at closing of the purchase, amounting to $15.4 million at March 31, 2014, including $3.3 million due by March 31, 2015. FERC approved the purchase on February 26, 2013 and the NMPRC approved the purchase on June 26, 2013. Closing is subject to the seller remedying specified operational, NERC compliance, and environmental issues, as well as other customary closing conditions. PNM and Delta are working with the City of Albuquerque and EPA in order to remedy certain environmental issues. PNM anticipates closing of the purchase in the second quarter of 2014.

Delta informed PNM that at March 31, 2014 and December 31, 2013, it had total assets of $23.2 million and $23.7 million, including net property, plant, and equipment of $19.7 million and $20.3 million, and total liabilities of $17.4 million and $18.2 million. Delta also indicated its revenue for the three months ended March 31, 2014 and 2013 was $1.8 million and $1.8 million and its net earnings were $0.3 million and $0.2 million. Consolidation of Delta would be immaterial to the Condensed Consolidated Balance Sheets of PNMR and PNM. Since all of Delta’s revenues and expenses are attributable to its PPA arrangement with PNM, the primary impact of consolidating Delta to the Condensed Consolidated Statements of Earnings of PNMR and PNM would be 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.

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Lease Commitments (Notes)

3 Months Ended

Mar. 31, 2014

Leases [Abstract]

Leases of Lessee Disclosure [Text Block]

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 an interest in the EIP transmission line. Additional information concerning the Company’s lease commitments is contained in Note 7 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K.

The PVNGS leases 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 provides PNM with an option to purchase the leased assets at fair market value at the end of the lease. In addition, the leases provide 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 may be further extended for up to an additional six years (the “Maximum Option Period”) if the appraised remaining useful lives and fair values of the leased assets are greater than parameters set forth in the leases. The rental payments during the renewal option periods would be 50% of the amounts during the original terms of the leases.

Following procedures set forth in the PVNGS leases, PNM notified each of the lessors under the Unit 1 leases that it would elect to renew those leases for the Maximum Option Period on the expiration date of the original leases. In addition, PNM notified the lessor under the one Unit 2 lease containing the Maximum Option Period provision that it would elect to renew that lease for the Maximum Option Period on the expiration date of the original lease. On December 11, 2013, PNM and each of the Unit 1 lessors entered into amendments to each of the Unit 1 leases setting forth the terms and conditions that will implement the extension of the term of the lease through the agreed upon Maximum Option Period expiring on January 15, 2023. Similarly, on March 18, 2014, PNM and the lessor under the one Unit 2 lease containing the Maximum Option Period provision entered into an amendment to that lease setting forth the terms and conditions that will implement the extension of the term of the lease through the agreed upon Maximum Option Period expiring on January 15, 2024.

For the three PVNGS Unit 2 leases which do 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. On February 25, 2014, PNM and the lessor under one of the Unit 2 leases entered into a letter agreement that establishes that the purchase price, representing the fair market value, to be paid by PNM for the assets underlying that lease will be $78.1 million on January 15, 2016. This lease is for 31.2494 MW of the entitlement from PVNGS Unit 2. The lease remains in existence and PNM will record the purchase at the termination of the lease on January 15, 2016.

On May 1, 2014, PNM and the trusts that are the lessors under the other two PVNGS Unit 2 leases signed a letter agreement that establishes a binding agreement regarding the purchase price, representing the fair market value, to be paid by PNM for the assets underlying those leases of $85.2 million on January 15, 2016. These leases are for 32.76 MW of the entitlement from PVNGS Unit 2. PNMR Development, a wholly-owned subsidiary of PNMR, is also a party to the letter agreement, which constitutes a letter of intent providing PNMR Development with the option, subject to approval by the Board and negotiation of definitive documents, to acquire the entities that own the leased assets at any time from June 1, 2014 through January 14, 2016. The early purchase price would be equal to the January 15, 2016 purchase price discounted to the actual purchase date. The early purchase amount would be $79.9 million on June 1, 2014 and would escalate to $85.2 million on January 14, 2016. The consideration paid to the lessor on an early purchase would include an additional amount equal to the discounted value of the lessors’ equity return portion of the future lease payments. Such additional consideration would be $5.8 million on June 1, 2014 and would decline to $1.2 million on January 14, 2016. PNMR and PNM are unable to predict whether or not the early purchase will occur.

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Stock-Based Compensation

3 Months Ended

Mar. 31, 2014

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”). 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 and some of these awards also have time vesting requirements. Other awards of restricted stock are only subject to time vesting requirements. Additional information concerning stock-based compensation under the PEP is contained in Note 13 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K.

Restricted stock under the PEP refers to awards of stock subject to vesting, performance, or market conditions rather than to shares with contractual post-vesting restrictions. Generally, the awards vest ratably over three years from the grant date of the award. However, certain 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 stock awards.

The stock-based compensation expense related to stock options and restricted stock awards without performance or market conditions is amortized to compensation expense over the requisite vesting period, which is generally three years. However, compensation expense for awards to participants that are retirement eligible on the grant date is recognized immediately at the grant date and is not amortized. 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. At March 31, 2014 and December 31, 2013, PNMR had unrecognized expense related to stock awards of $8.1 million and $4.6 million. 

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:

	Three Months Ended March 31,
Restricted Shares and Performance Based Shares	2014			2013
Expected quarterly dividends per share	$	0.185		$	0.165
Risk-free interest rate	0.71		%	0.38		%
Market-Based Shares
Dividend yield	2.82		%	2.86		%
Expected volatility	25.11		%	25.11		%
Risk-free interest rate	0.64		%	0.36		%

The following table summarizes activity in stock options and restricted stock awards, including performance-based and market-based shares, for the three months endedMarch 31, 2014:

	Stock Option Shares		Weighted- Average Exercise Price		Restricted Stock		Weighted- Average Grant Date Fair Value
Outstanding at beginning of period	1,343,666		$	20.63	315,305		$	17.87
Granted	—		$	—	223,348		$	20.79
Exercised	(182,407	)	$	17.86	(262,358	)	$	16.53
Forfeited	(17,151	)	$	26.43	—		$	—
Expired	(13,501	)	$	25.82	—		$	—
Outstanding at end of period	1,130,607		$	20.92	276,295		$	21.55

Included as restricted stock granted and exercised in the table above are 112,864 shares that were based upon achieving performance or market targets for 2013. The Board approved these shares in February 2014 (based upon achieving market targets, weighted at 60%, at maximum levels, and performance targets, weighted at 40%, at below threshold levels for the 2011 through 2013 performance period).

PNMR’s stock-based compensation program provides for performance or market targets through 2016. Excluded from the above table are maximums of 198,369, 179,811, and 175,735 restricted stock shares for periods ending in 2014, 2015, and 2016 that would be awarded if all performance or market criteria are achieved 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 the Company meets specific market targets at the end of 2016 and she remains an employee of the Company. If the Company achieves specific market targets at the end of 2014 and, with certain exceptions, she remains an employee of the Company, she would receive 35,000 of the total shares at that time. The retention award was made under the PEP and was approved by the Board on February 28, 2012. The above table does not include any restricted stock shares under the retention award agreement.

At March 31, 2014, the aggregate intrinsic value of stock options outstanding, all of which are exercisable, was $8.0 million with a weighted-average remaining contract life of 3.39 years. At March 31, 2014, the exercise price of 486,016 outstanding stock options is greater than the closing price of PNMR common stock on that date; therefore, those options have no intrinsic value.

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

	Three Months Ended March 31,
Stock Options	2014		2013
Weighted-average grant date fair value of options granted	$	—	$	—
Total fair value of options that vested (in thousands)	$	—	$	620
Total intrinsic value of options exercised (in thousands)	$	1,469	$	1,824
Restricted Stock
Weighted-average grant date fair value	$	20.79	$	19.82
Total fair value of restricted shares that vested (in thousands)	$	4,336	$	3,871

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Segment Information (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013
Segment Reporting Information, Profit (Loss) [Abstract]
Electric operating revenues	$ 328,897	$ 317,665
Cost of energy	112,614	104,706
Margin	216,283	212,959
Other operating expenses	125,565	121,448
Depreciation and amortization	41,965	40,807
Operating income	48,753	50,704
Interest income	2,117	2,634
Other income (deductions)	1,216	(110)
Net interest charges	(29,535)	(31,297)
Earnings before Income Taxes	22,551	21,931
Income taxes (benefit)	6,420	7,969
Net Earnings	16,131	13,962
Valencia non-controlling interest	(3,531)	(3,204)
Subsidiary preferred stock dividends	(132)	(132)
Net Earnings Attributable to PNMR	12,468	10,626
Total Assets	5,507,026	5,370,760	5,500,210
Goodwill	278,297	278,297	278,297
PNM Electric [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Electric operating revenues	262,736	257,894
Cost of energy	96,626	91,660
Margin	166,110	166,234
Other operating expenses	107,724	103,161
Depreciation and amortization	27,082	25,834
Operating income	31,304	37,239
Interest income	2,128	2,673
Other income (deductions)	1,668	1,407
Net interest charges	(19,812)	(19,957)
Earnings before Income Taxes	15,288	21,362
Income taxes (benefit)	4,083	6,589
Net Earnings	11,205	14,773
Valencia non-controlling interest	(3,531)	(3,204)
Subsidiary preferred stock dividends	(132)	(132)
Net Earnings Attributable to PNMR	7,542	11,437
Total Assets	4,219,635	4,155,257
Goodwill	51,632	51,632
TNMP Electric [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Electric operating revenues	66,161	59,771
Cost of energy	15,988	13,046
Margin	50,173	46,725
Other operating expenses	21,069	21,990
Depreciation and amortization	11,842	11,681
Operating income	17,262	13,054
Interest income	0	0
Other income (deductions)	189	208
Net interest charges	(6,598)	(7,246)
Earnings before Income Taxes	10,853	6,016
Income taxes (benefit)	4,050	2,290
Net Earnings	6,803	3,726
Valencia non-controlling interest	0	0
Subsidiary preferred stock dividends	0	0
Net Earnings Attributable to PNMR	6,803	3,726
Total Assets	1,173,028	1,098,942
Goodwill	226,665	226,665
Corporate and Other [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Electric operating revenues	0	0
Cost of energy	0	0
Margin	0	0
Other operating expenses	(3,228)	(3,703)
Depreciation and amortization	3,041	3,292
Operating income	187	411
Interest income	(11)	(39)
Other income (deductions)	(641)	(1,725)
Net interest charges	(3,125)	(4,094)
Earnings before Income Taxes	(3,590)	(5,447)
Income taxes (benefit)	(1,713)	(910)
Net Earnings	(1,877)	(4,537)
Valencia non-controlling interest	0	0
Subsidiary preferred stock dividends	0	0
Net Earnings Attributable to PNMR	(1,877)	(4,537)
Total Assets	114,363	116,561
Goodwill	$ 0	$ 0

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Income Taxes (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Jun. 30, 2013	Dec. 31, 2013	Mar. 31, 2013
Income Tax Contingency [Line Items]
Deferred Tax Assets, Operating Loss Carryforwards, State and Local, Decrease				$ 1.5
New Mexico Corporate tax rate, current	7.60%
New Mexico Corporate tax rate, 2014	5.90%
Increase in regulatory liabilities due to change in state corporate tax rate	23.9
Increase in income tax expense due to change in state corporate tax rate	0.2	1.2
Decrease in regulatory liabilities due to change in state corporate tax rate	4.6
Additional Income Tax Expense, Impairment of NM Wind Credits		2.4
New Accounting Pronouncements Not Yet Adopted, Effect on Deferred Tax Asset			19.9
Public Service Company of New Mexico [Member]
Income Tax Contingency [Line Items]
New Accounting Pronouncements Not Yet Adopted, Effect on Deferred Tax Asset			11.2
Texas-New Mexico Power Company [Member]
Income Tax Contingency [Line Items]
New Accounting Pronouncements Not Yet Adopted, Effect on Deferred Tax Asset			$ 6.8

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Income Taxes

3 Months Ended

Mar. 31, 2014

Income Tax Disclosure [Abstract]

Income Taxes

Income Taxes

On January 3, 2013, the American Taxpayer Relief Act of 2012, which extended fifty percent bonus depreciation, was signed into law.  Due to provisions in the act, taxes payable to the State of New Mexico for 2013 were reduced, which resulted in an impairment of New Mexico wind energy production tax credits. In accordance with GAAP, PNMR was required to record this impairment, which after federal income tax benefit, amounted to $1.5 million as additional income tax expense during the three months ended March 31, 2013. This impairment is reflected in PNMR’s Corporate and Other segment.

On April 4, 2013, New Mexico House Bill 641 was signed into law. One of the provisions of the bill was to reduce the New Mexico corporate income tax rate from 7.6% to 5.9%. The rate reduction will be 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 three months ended June 30, 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. The increase in the regulatory liability was $23.9 million. In addition, the portion of the adjustment that is not related to PNM’s regulated activities was recorded as a reduction in deferred tax assets and an increase in income tax expense of $1.2 million. 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. In the three months ended March 31, 2014, PNM’s regulatory liability was reduced by $4.6 million, which increased deferred tax liabilities. Additionally, deferred tax assets not related to PNM’s regulatory activities were reduced by $0.2 million, which increased income tax expense.

In 2013, the future reduction in taxes payable to the State of New Mexico resulting from the rate reduction in House Bill 641 and revisions in estimates of future taxable income resulted in a further impairment of New Mexico wind energy production tax credits. In accordance with GAAP, PNMR was required to record this impairment, which after federal income tax benefit, amounted to $2.4 million as additional income tax expense during the three months ended June 30, 2013.

In 2013, the FASB issued Accounting Standards Update 2013-11, which requires entities to present an unrecognized tax benefit as a reduction to a deferred tax asset for a net operating loss carryforward, a similar tax loss, or a tax credit carryforward if such carryforward could be used to offset the unrecognized tax benefit upon settlement.  The update is required to be applied prospectively for periods beginning after December 15, 2013, and early adoption was permitted.  The Company elected not to adopt the change for 2013, but did adopt it for 2014 as required by the update.  Had the Company applied the update at December 31, 2013, the effect would have been decreases in net operating deferred tax assets of $19.9 million for PNMR, $11.2 million for PNM, and $6.8 million for TNMP, along with the elimination of the corresponding assets and liabilities associated with unrecognized tax benefits. There was no impact to earning from adopting the update.

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Accumulated Other Comprehensive Income (Loss) (Tables)

3 Months Ended

Mar. 31, 2014

Equity [Abstract]

Schedule of Accumulated Other Comprehensive Income (Loss) [Table Text Block]

Information regarding accumulated other comprehensive income (loss) for the three months ended March 31, 2014 and 2013 is as follows:

	Accumulated Other Comprehensive Income (Loss)
	Unrealized						Fair Value
	Gain on			Pension			Adjustment
	Available-for-			Liability			for Cash Flow
	Sale Securities			Adjustment			Hedges			Total
	(In thousands)
PNMR
Balance at December 31, 2013	$	25,748		$	(83,625	)	$	(263	)	$	(58,140	)
Amounts reclassified from AOCI (pre-tax)	(3,255		)	1,288			55			(1,912		)
Income tax impact of amounts reclassified	1,283			(508		)	(19		)	756
Other OCI changes (pre-tax)	3,379			—			(153		)	3,226
Income tax impact of other OCI changes	(1,332		)	—			53			(1,279		)
Net change after income taxes	75			780			(64		)	791
Balance at March 31, 2014	$	25,823		$	(82,845	)	$	(327	)	$	(57,349	)

PNM
Balance at December 31, 2013	$	25,748		$	(83,625	)	$	—	$	(57,877	)
Amounts reclassified from AOCI (pre-tax)	(3,255		)	1,288			—		(1,967		)
Income tax impact of amounts reclassified	1,283			(508		)	—		775
Other OCI changes (pre-tax)	3,379			—			—		3,379
Income tax impact of other OCI changes	(1,332		)	—			—		(1,332		)
Net change after income taxes	75			780			—		855
Balance at March 31, 2014	$	25,823		$	(82,845	)	$	—	$	(57,022	)

TNMP
Balance at December 31, 2013	$	—	$	—	$	(263	)	$	(263	)
Amounts reclassified from AOCI (pre-tax)	—		—		55			55
Income tax impact of amounts reclassified	—		—		(19		)	(19		)
Other OCI changes (pre-tax)	—		—		(153		)	(153		)
Income tax impact of other OCI changes	—		—		53			53
Net change after income taxes	—		—		(64		)	(64		)
Balance at March 31, 2014	$	—	$	—	$	(327	)	$	(327	)

	Accumulated Other Comprehensive Income (Loss)
	Unrealized						Fair Value
	Gain on			Pension			Adjustment
	Available-for-			Liability			for Cash Flow
	Sale Securities			Adjustment			Hedges			Total
	(In thousands)
PNMR
Balance at December 31, 2012	$	16,406		$	(97,820	)	$	(216	)	$	(81,630	)
Amounts reclassified from AOCI (pre-tax)	(1,336		)	1,591			48			303
Income tax impact of amounts reclassified	529			(631		)	(17		)	(119		)
Other OCI changes (pre-tax)	7,858			—			12			7,870
Income tax impact of other OCI changes	(3,111		)	—			(4		)	(3,115		)
Net change after income taxes	3,940			960			39			4,939
Balance at March 31, 2013	$	20,346		$	(96,860	)	$	(177	)	$	(76,691	)

PNM
Balance at December 31, 2012	$	16,406		$	(97,820	)	$	—	$	(81,414	)
Amounts reclassified from AOCI (pre-tax)	(1,336		)	1,591			—		255
Income tax impact of amounts reclassified	529			(631		)	—		(102		)
Other OCI changes (pre-tax)	7,858			—			—		7,858
Income tax impact of other OCI changes	(3,111		)	—			—		(3,111		)
Net change after income taxes	3,940			960			—		4,900
Balance at March 31, 2013	$	20,346		$	(96,860	)	$	—	$	(76,514	)

TNMP
Balance at December 31, 2012	$	—	$	—	$	(216	)	$	(216	)
Amounts reclassified from AOCI (pre-tax)	—		—		48			48
Income tax impact of amounts reclassified	—		—		(17		)	(17		)
Other OCI changes (pre-tax)	—		—		12			12
Income tax impact of other OCI changes	—		—		(4		)	(4		)
Net change after income taxes	—		—		39			39
Balance at March 31, 2013	$	—	$	—	$	(177	)	$	(177	)

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Commitments and Contingencies (Other Commitments and Contingencies) (Details) (USD $)													3 Months Ended
	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014 Public Service Company of New Mexico [Member]	Dec. 31, 2013 Public Service Company of New Mexico [Member]	Mar. 31, 2014 San Juan Generating Station [Member] Public Service Company of New Mexico [Member] Coal Supply [Member]	Dec. 31, 2013 San Juan Generating Station [Member] Public Service Company of New Mexico [Member] Coal Supply [Member]	Mar. 31, 2014 Surface [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 Nuclear Plant [Member] Palo Verde Nuclear Generating Station [Member] Public Service Company of New Mexico [Member]	Apr. 01, 2014 Nuclear Plant [Member] Maximum [Member] Palo Verde Nuclear Generating Station [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 Nuclear Plant [Member] Maximum [Member] Palo Verde Nuclear Generating Station [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 Nuclear Plant [Member] Commercial Providers [Member] Palo Verde Nuclear Generating Station [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 Nuclear Plant [Member] Industry Wide Retrospective Assessment Program [Member] Palo Verde Nuclear Generating Station [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 Loss on Long-term Purchase Commitment [Member] Surface [Member] Public Service Company of New Mexico [Member]	Dec. 31, 2013 Loss on Long-term Purchase Commitment [Member] Surface [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 Loss on Long-term Purchase Commitment [Member] Surface [Member] San Juan Generating Station [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 Loss on Long-term Purchase Commitment [Member] Underground [Member] Public Service Company of New Mexico [Member]	Dec. 31, 2013 Loss on Long-term Purchase Commitment [Member] Underground [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 Loss on Long-term Purchase Commitment [Member] Underground [Member] San Juan Generating Station [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 San Juan Underground Mine Fire [Member] Fuel and Purchased Power Adjustment Clause [Member] San Juan Generating Station [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 San Juan Underground Mine Fire [Member] Maximum [Member] Fuel and Purchased Power Adjustment Clause [Member] San Juan Generating Station [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 San Juan Underground Mine Fire [Member] Minimum [Member] Fuel and Purchased Power Adjustment Clause [Member] San Juan Generating Station [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 Continuous Highwall Mining [Member] San Juan Generating Station [Member]	Mar. 31, 2014 SJCC Arbitration [Member] San Juan Generating Station [Member]	Mar. 31, 2014 SJCC Arbitration [Member] San Juan Generating Station [Member] Public Service Company of New Mexico [Member]	Mar. 31, 2014 NMTRD Coal Severance Tax [Member] Four Corners [Member]	Mar. 31, 2014 NMTRD Coal Severance Tax [Member] Four Corners [Member] Public Service Company of New Mexico [Member]	Jan. 06, 2014 Navajo Nation Allottee Matters [Member] Public Service Company of New Mexico [Member] Allotment_Parcel
Public Utilities, Commitments and Contingencies [Line Items]
Other current assets	$ 44,689,000	$ 34,590,000	$ 40,498,000	$ 30,510,000	$ 16,000,000	$ 12,300,000
Public Utilities, Estimated Increase in Coal Cost, Percentage					21.00%
Final Reclamation, capped amount to be collected													100,000,000
Preliminary estimate increased deferral related to mine fire incident																				21,600,000	17,400,000
Public Utilities, Insurance Recovery																			18,700,000
Public Utilities, Proposed Retroactive Surface Mining Royalty Rate																						12.50%
Public Utilities, Current Surface Mining Royalty Rate applied between 2000 and 2003																						8.00%
Public Utilities, Estimated Underpaid Surface Mining Royalties under proposed rate change																						5,000,000
Public Utilities, PNM Share Estimated Underpaid Surface Mining Royalties under proposed rate change																						46.30%
Public Utilities, Potential Unbilled Mining Costs Owed to SJCC																							5,200,000.0
Public Utilities, Potential Overbilled Mining Costs SJCC Owes to SJGS Owners																							1,100,000.0
Public Utilities, Potential Capital Improvements billed as Mining Costs to SJGS Owners																							13,900,000.0
Public Utilities, PNM Share of arbitration ruling																								46.30%
Public Utilities, FFPAC Percentage of mining costs overbilled or unbilled ruled by arbitration																								33.00%
Public Utilities, FFPAC Percentage of capital improvements billed as mining costs ruled by arbitration																								25.00%
Public Utilities, Assessed Coal Severance Surtax Penalty and Interest																									30,000,000
Public Utilities, PNM Share Assessed Coal Severance Surtax Penalty and Interest to pass through FFPAC																										8.00%
Public Utilities, Liability Insurance Coverage										13,600,000,000	375,000,000	13,200,000,000
Public Utilities, Ownership Percentage in Nuclear Reactor								10.20%
Public Utilities, Maximum Potential Assessment Per Incident								38,900,000
Public Utilities, Annual Payment Limitation Related to Incident								5,700,000
Public Utilities, Aggregate Amount of All Risk Insurance								2,750,000,000
Public Utilities, Liability Insurance Coverage Sublimit									2,250,000,000
Public Utilities, Maximum Amount under Nuclear Electric Insurance Limited								4,800,000
Loss Contingency, Estimate of Possible Loss															55,100,000			93,300,000
Loss Contingency Accrual, at Carrying Value													23,600,000	23,800,000		7,900,000	7,800,000
Regulatory Assets							$ 100,000,000
Number of allotment parcels' appraisal requested for review																											58

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Fair Value of Derivative and Other Financial Instruments, Available for Sale Securities (Details) (PNMR and PNM [Member], USD $) In Thousands, unless otherwise specified	3 Months Ended		12 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Unrealized gains	$ 42,725		$ 42,602
Available-for-sale securities, Fair value	230,250		226,855
Proceeds from sales	22,804	14,284
Gross realized gains	3,119	1,391
Gross realized (losses)	(545)	(407)
Cash and equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Unrealized gains	0		0
Available-for-sale securities, Fair value	4,246		3,356
Domestic value [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Unrealized gains	14,558		14,523
Available-for-sale securities, Fair value	41,055		39,460
Domestic growth [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Unrealized gains	23,002		25,656
Available-for-sale securities, Fair value	74,517		76,292
International and other [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Unrealized gains	1,671		1,040
Available-for-sale securities, Fair value	17,264		16,633
U.S. Government [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Unrealized gains	377		158
Available-for-sale securities, Fair value	20,662		21,941
Municipals [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Unrealized gains	2,659		1,018
Available-for-sale securities, Fair value	61,158		58,568
Corporate and other [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Unrealized gains	458		207
Available-for-sale securities, Fair value	11,348		10,605
Fair Value, Measurements, Recurring [Member] | Nuclear Decommissioning Trust [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Fair value	225,800		222,500
Fair Value, Measurements, Recurring [Member] | Mine Reclamation Trust [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Fair value	$ 4,400		$ 4,400

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Condensed Consolidated Statements of Cash Flows (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Cash Flows From Operating Activities:
Net Earnings	$ 16,131	$ 13,962
Net earnings	12,468	10,626
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	51,949	51,818
Deferred income tax expense	6,276	7,795
Net unrealized (gains) losses on commodity derivatives	2,761	4,902
Realized (gains) on available-for-sale securities	(2,573)	(1,530)
Stock based compensation expense	2,131	1,903
Other, net	1,005	(351)
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	17,207	4,062
Materials, supplies, and fuel stock	5,894	944
Other current assets	8,344	2,335
Other assets	6,386	8,774
Accounts payable	(34,373)	(17,895)
Accrued interest and taxes	25,813	25,430
Other current liabilities	(30,359)	(38,761)
Other liabilities	(199)	(64,763)
Net cash flows from operating activities	76,393	(1,375)
Cash Flows From Investing Activities:
Additions to utility and non-utility plant	(83,838)	(73,584)
Proceeds from sales of available-for-sale securities	22,804	14,284
Purchases of available-for-sale securities	(23,612)	(15,128)
Return of principal on PVNGS lessor notes	10,231	10,965
Other, net	13	1,247
Net cash flows from investing activities	(74,402)	(62,216)
Cash Flows From Financing Activities:
Short-term borrowings (repayments), net	(49,200)	84,600
Long-term borrowings	175,000	0
Repayment of long-term debt	(75,000)	0
Proceeds from stock option exercise	3,258	2,293
Awards of common stock	(11,639)	(9,651)
Dividends paid	(14,868)	(11,683)
Valencia’s transactions with its owner	(4,369)	(5,260)
Other, net	(539)	(584)
Net cash flows from financing activities	22,643	59,715
Change in Cash and Cash Equivalents	24,634	(3,876)
Cash and Cash Equivalents at Beginning of Period	2,533	8,985
Cash and Cash Equivalents at End of Period	27,167	5,109
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	4,718	4,817
Income taxes paid (refunded), net	(1,419)	(603)
Supplemental schedule of noncash investing activities:
Changes in accrued plant additions	(13,095)	(3,847)
Public Service Company of New Mexico [Member]
Cash Flows From Operating Activities:
Net Earnings	11,205	14,773
Net earnings	7,674	11,569
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	35,950	34,655
Deferred income tax expense	4,185	6,685
Net unrealized (gains) losses on commodity derivatives	2,761	4,902
Realized (gains) on available-for-sale securities	(2,573)	(1,530)
Other, net	1,042	(346)
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	15,018	5,467
Materials, supplies, and fuel stock	5,974	879
Other current assets	6,809	(84)
Other assets	6,042	8,772
Accounts payable	(31,847)	(18,857)
Accrued interest and taxes	22,362	20,932
Other current liabilities	(29,609)	(44,068)
Other liabilities	(806)	(64,893)
Net cash flows from operating activities	46,513	(32,713)
Cash Flows From Investing Activities:
Additions to utility and non-utility plant	(51,594)	(44,389)
Proceeds from sales of available-for-sale securities	22,804	14,284
Purchases of available-for-sale securities	(23,612)	(15,128)
Return of principal on PVNGS lessor notes	10,231	10,965
Other, net	(1)	1,220
Net cash flows from investing activities	(42,172)	(33,048)
Cash Flows From Financing Activities:
Short-term borrowings (repayments), net	(49,200)	67,800
Short-term borrowings (repayments), affiliate, net	(32,500)	0
Long-term borrowings	175,000	0
Repayment of long-term debt	(75,000)	0
Dividends paid	(132)	(132)
Valencia’s transactions with its owner	(4,369)	(5,260)
Other, net	(409)	(584)
Net cash flows from financing activities	13,390	61,824
Change in Cash and Cash Equivalents	17,731	(3,937)
Cash and Cash Equivalents at Beginning of Period	21	3,958
Cash and Cash Equivalents at End of Period	17,752	21
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	4,222	4,304
Income taxes paid (refunded), net	(215)	0
Supplemental schedule of noncash investing activities:
Changes in accrued plant additions	(8,133)	1,128
Texas-New Mexico Power Company [Member]
Cash Flows From Operating Activities:
Net earnings	6,803	3,726
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	12,851	12,686
Deferred income tax expense	3,665	2,448
Other, net	(36)	0
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	2,189	(1,405)
Materials, supplies, and fuel stock	(81)	65
Other current assets	2,446	218
Other assets	302	(58)
Accounts payable	(2,551)	4,130
Accrued interest and taxes	335	686
Other current liabilities	(1,768)	(1,278)
Other liabilities	1,465	1,076
Net cash flows from operating activities	25,620	22,294
Cash Flows From Investing Activities:
Additions to utility and non-utility plant	(27,420)	(24,594)
Net cash flows from investing activities	(27,420)	(24,594)
Cash Flows From Financing Activities:
Short-term borrowings (repayments), net	0	25,000
Short-term borrowings (repayments), net	1,800	(22,700)
Net cash flows from financing activities	1,800	2,300
Change in Cash and Cash Equivalents	0	0
Cash and Cash Equivalents at Beginning of Period	1	1
Cash and Cash Equivalents at End of Period	1	1
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	73	171
Income taxes paid (refunded), net	(1,204)	(604)
Supplemental schedule of noncash investing activities:
Changes in accrued plant additions	$ (1,109)	$ (932)

XML

Earnings Per Share

3 Months Ended

Mar. 31, 2014

Earnings Per Share [Abstract]

Earnings Per Share

Earnings Per Share

In accordance with GAAP, dual presentation of basic and diluted earnings per share is presented in the Condensed Consolidated Statements of Earnings of PNMR. Information regarding the computation of earnings per share is as follows:

	Three Months Ended
	March 31,
	2014		2013
	(In thousands, except per share amounts)
Net Earnings Attributable to PNMR	$	12,468	$	10,626
Average Number of Common Shares:
Outstanding during period	79,654		79,654
Vested awards of restricted stock	182		211
Average Shares - Basic	79,836		79,865
Dilutive Effect of Common Stock Equivalents (1):
Stock options and restricted stock	551		715
Average Shares - Diluted	80,387		80,580
Net Earnings Per Share of Common Stock:
Basic	$	0.16	$	0.13
Diluted	$	0.16	$	0.13

⁽¹⁾  Excludes the effect of out-of-the-money options for 486,016 shares of common stock at March 31, 2014.

XML

Variable Interest Entities (Tables) (Public Service Company of New Mexico [Member])

3 Months Ended

Mar. 31, 2014

Public Service Company of New Mexico [Member]

Variable Interest Entity [Line Items]

Noncontrolling Interest Summarized Financial Information [Table Text Block]

Summarized financial information for Valencia is as follows:

Results of Operations

	Three Months Ended March 31,
	2014			2013
	(In thousands)
Operating revenues	$	4,931		$	4,775
Operating expenses	(1,400		)	(1,571		)
Earnings attributable to non-controlling interest	$	3,531		$	3,204

Financial Position

	March 31,		December 31,
	2014		2013
	(In thousands)
Current assets	$	2,780	$	2,658
Net property, plant, and equipment	74,433		75,137
Total assets	77,213		77,795
Current liabilities	1,022		766
Owners’ equity – non-controlling interest	$	76,191	$	77,029

XML

Fair Value of Derivative and Other Financial Instruments, Derivative Balance Sheet Information (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
Derivatives, Fair Value [Line Items]
Assets, Current	$ 401,030,000	$ 401,539,000
Liabilities, Current	312,088,000	492,671,000
Commodity derivative instruments, Current assets	4,003,000	4,064,000
Commodity derivative instruments, Deferred charges	2,474,000	3,002,000
Commodity derivative instruments, Current liabilities	(5,446,000)	(2,699,000)
Commodity derivative instruments, Long-term liabilities	(907,000)	(1,094,000)
PNMR and PNM [Member]
Derivatives, Fair Value [Line Items]
Margin Deposit Assets	3,100,000	2,800,000
Derivative, Collateral, Obligation to Return Cash	100,000	200,000
Public Service Company of New Mexico [Member]
Derivatives, Fair Value [Line Items]
Assets, Current	345,261,000	348,502,000
Liabilities, Current	156,140,000	357,266,000
Commodity derivative instruments, Current assets	4,003,000	4,064,000
Commodity derivative instruments, Deferred charges	2,474,000	3,002,000
Commodity derivative instruments, Current liabilities	(5,446,000)	(2,699,000)
Commodity derivative instruments, Long-term liabilities	(907,000)	(1,094,000)
Commodity Contract [Member] | Fair Value Hedging [Member] | PNMR and PNM [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative instruments, Current assets	4,003,000	4,064,000
Commodity derivative instruments, Deferred charges	2,474,000	3,002,000
Commodity derivative instruments, Assets	6,477,000	7,066,000
Commodity derivative instruments, Current liabilities	(5,446,000)	(2,699,000)
Commodity derivative instruments, Long-term liabilities	(907,000)	(1,094,000)
Commodity derivative instruments, Liabilities	(6,353,000)	(3,793,000)
Commodity derivative instruments, Net	124,000	3,273,000
Commodity Contract [Member] | Fuel and Purchased Power Adjustment Clause [Member] | Fair Value Hedging [Member] | Public Service Company of New Mexico [Member]
Derivatives, Fair Value [Line Items]
Assets, Current	400,000	400,000
Liabilities, Current	600,000	100,000
Palo Verde Nuclear Generating Station [Member] | Commodity Contract [Member] | Fair Value Hedging [Member] | PNMR and PNM [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative instruments, Current assets	3,000,000	3,000,000
Commodity derivative instruments, Deferred charges	2,300,000	3,000,000
Palo Verde Nuclear Generating Station [Member] | Firm Contract [Member] | Public Service Company of New Mexico [Member]
Derivatives, Fair Value [Line Items]
Percentage of Electric Power Plant Output Sold through 2013	100.00%
Palo Verde Nuclear Generating Station Unit 3 [Member] | PNMR and PNM [Member]
Derivatives, Fair Value [Line Items]
Public Utilities, Number of Megawatts Nuclear Generation	134
Palo Verde Nuclear Generating Station Unit 3 [Member] | Commodity Contract [Member] | PNMR and PNM [Member]
Derivatives, Fair Value [Line Items]
Derivative, Average Forward Price		37
Fair Value, Measurements, Recurring [Member] | Fair Value [Member] | Commodity Contract [Member] | PNMR and PNM [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative instruments, Assets	6,477,000	7,066,000
Commodity derivative instruments, Liabilities	(6,353,000)	(3,793,000)
Commodity derivative instruments, Net	124,000	3,273,000
Fair Value, Measurements, Recurring [Member] | Level 1 [Member] | Commodity Contract [Member] | PNMR and PNM [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative instruments, Assets	0	0
Commodity derivative instruments, Liabilities	0	0
Commodity derivative instruments, Net	0	0
Fair Value, Measurements, Recurring [Member] | Level 2 [Member] | Commodity Contract [Member] | PNMR and PNM [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative instruments, Assets	6,477,000	7,066,000
Commodity derivative instruments, Liabilities	(6,353,000)	(3,793,000)
Commodity derivative instruments, Net	$ 124,000	$ 3,273,000

XML

Regulatory and Rate Matters

3 Months Ended

Mar. 31, 2014

Regulatory and Rate Matters

Regulatory and Rate Matters

Regulatory and Rate Matters

The Company is involved in various regulatory matters, some of which contain contingencies that are subject to the same uncertainties as those described in Note 11. Additional information concerning regulatory and rate matters is contained in Note 17 of the Notes to Consolidated Financial Statements in the 2013 Annual Reports on Form 10-K.

PNM

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. The NMPRC requires renewable energy portfolios to be “fully diversified.” The current diversity requirements are 30% wind, 20% solar, 5% other, and 1.5% distributed generation, increasing to 3% in 2015, subject to the limitation of the RCT. In December 2013, the NMPRC modified the RCT calculation to establish a two to one REC weighting for renewable energy from the non-wind/non-solar category, such as geothermal resources. On motions for rehearing, the NMPRC reversed its weighting decision in April 2014.

The REA provides for streamlined proceedings for approval of utilities’ renewable energy procurement plans, assures utilities that they recover costs incurred consistent with approved procurement plans, and requires the NMPRC to establish a RCT for the procurement of renewable resources to prevent excessive costs being added to rates. The currently NMPRC approved RCT is set at 3% of customers’ annual electric charges.

PNM filed its 2014 renewable energy procurement plan on July 1, 2013. The plan meets RPS and diversity requirements within the RCT in 2014 and 2015. PNM’s procurements include 50,000 MWh of wind generated RECs in 2014, the construction by December 31, 2014 of 23 MW of PNM-owned solar PV facilities at a cost of $46.7 million, a 20-year PPA for the output of Red Mesa Wind, an existing wind facility having an aggregate capacity of 102 MW, beginning January 1, 2015 at a first year cost estimated to be $5.8 million, and the purchase of 120,000 MWh of wind RECs in 2015. The NMPRC approved the plan on December 18, 2013.

PNM is recovering certain renewable procurement costs from customers through a rate rider. See Renewable Energy Riderbelow.

Renewable Energy Rider

The NMPRC has authorized PNM to recover certain renewable procurement costs through a rate rider billed on a per KWh basis. The rider will terminate upon a final order in PNM’s next general rate case unless the NMPRC authorizes PNM to continue it. 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 10.5%, PNM would be required to refund the amount over 10.5% to customers during May through December of the following year. On April 1, 2014, PNM made a filing with the NMPRC demonstrating that it had not exceeded the 10.5% return for 2013. The 2013 approved rider rate was $0.0028371 per KWh through May 28, 2013 when it changed to $0.0030468 per KWh. The rider rate increased to $0.0044391 effective January 1, 2014 and to $0.0045959 per KWh on April 25, 2014. At the currently approved rider rate, PNM would collect an estimated $34.6 million annually.

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. Costs to implement approved programs are recovered through a rate rider. In 2013, this act was amended to set an annual program budget equal to 3% of an electric utility’s annual revenue.

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.

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. In 2010, PNM began implementing a NMPRC rule that authorized electric utilities to collect rate adders to remove disincentives and to provide incentives for energy and demand savings related to energy efficiency and demand response programs. 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 currently approved program costs, this equates to an estimated annual incentive of $1.7 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. Included in the proposed rule is a provision that would limit incentive awards to an amount equal to the product (expressed in dollars) of the utility’s WACC (expressed as a percent) and its approved annual program costs. The NMPRC received comments and a public hearing was held on November 20, 2013.

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 May 28, 2013, PNM filed the required continuation application and requested that its current FPPAC be modified to increase the reset frequency of the fuel factor from annually to quarterly, to allow PNM to retain 10% of its off-system sales margin, and to apply the same carrying charge rate to both over and under collections in the balancing account. On December 20, 2013, a stipulated agreement was filed to resolve this case. A public hearing on the stipulation was held on February 25, 2014. The Hearing Examiner recommended approval of the settlement in its entirety to the NMPRC. On April 23, 2014, the NMPRC approved the stipulation. The settlement allows PNM to retain 10% of off-system sales margin from July 1, 2013 through December 31, 2016, resolves all costs related to the San Juan Coal mine fire discussed in Note 11, resolves the ratemaking treatment for coal pre-treatment at SJGS until the next rate case, requires PNM to write-off $10.5 million of the under-collected balance in its FPPAC balancing account, and requires PNM to extend the recovery of the remaining under-collected balance over 18 months beginning July 1, 2014. PNM recorded the $10.5 million write-off as a regulatory disallowance in the fourth quarter of 2013.

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. In its most recent IRP, which was filed in July 2011, PNM indicated that it planned to meet its anticipated load growth through a combination of new natural gas-fired generating plants, renewable energy resources, load management, and energy efficiency programs. PNM has initiated the process to prepare its 2014 IRP. Public participation meetings have been held. The 2014 IRP is scheduled to be filed at the NMPRC by June 30, 2014.

Applications for Approvals to Purchase Delta

As discussed in Note 9 of the Notes to Consolidated Financial Statements in the 2013 Annual Report on Form 10-K, PNM has entered in to an agreement to purchase Delta, a 132 MW natural gas peaking unit from which PNM currently acquires energy and capacity under a PPA. The agreement to purchase Delta required approvals by the NMPRC and FERC. On June 26, 2013, the NMPRC granted PNM’s CCN application and approved PNM’s proposed ratemaking treatment. FERC approved the purchase on February 26, 2013. PNM anticipates closing on the purchase in the second quarter of 2014.

Application for Approval of La Luz Generating Station

On May 17, 2013, PNM filed an application with the NMPRC for a CCN to construct, own, and operate a 40 MW gas-fired generating facility near Belen, New Mexico. The application also requested a determination of related ratemaking principles and treatment. The facility was initially expected to cost approximately $63.2 million and go into service in the first quarter of 2016. PNM has entered into a contract for purchase of the turbine to be used for this project and a separate contract for the construction of the facility on a turn-key basis. Both contracts allow PNM to cancel if NMPRC approval is not obtained. On February 20, 2014, a stipulated agreement was filed that would resolve the case. The parties to the stipulation are PNM, the NMPRC staff, and another intervenor. The parties to the stipulation agree that a CCN should be granted and establishes a value of up to $56 million to be included in rate base for the facility. A public hearing was held on April 29, 2014. At the conclusion of the hearing, the Hearing Examiner requested that the parties to the stipulation draft a recommended decision approving the stipulation. PNM is unable to predict the outcome of this matter.

San Juan Generating Station Units 2 and 3 Retirement

As discussed in Note 11, on December 20, 2013, PNM filed an application at the NMPRC to retire SJGS Units 2 and 3 on December 31, 2017. In that application, PNM also seeks approval to recover the net book value of SJGS Units 2 and 3 at the date of retirement, for a CCN to include PNM’s share of PVNGS Unit 3 as a resource to serve New Mexico consumers, authority to install SNCRs on SJGS Units 1 and 4, and a CCN to exchange 78 MW in SJGS Unit 3 for the same amount of capacity in SJGS Unit 4. PNM requested the NMPRC issue its final ruling on the application no later than December 2014. A public hearing on the application has been scheduled to commence on August 19, 2014. Depending upon the terms and conditions agreed to as a result of the negotiations, including PNM’s share of the capacity of SJGS Unit 4, PNM may amend its December 20, 2013 filing with the NMPRC. PNM will also make an application at FERC to seek approval of the restructured SJGS participation agreements. PNM is unable to predict the outcome of these matters.

Formula Transmission Rate Case

On December 31, 2012, PNM filed an application with FERC for authorization to move from charging stated rates for wholesale electric transmission service to a formula rate mechanism pursuant to which rates for wholesale transmission service are calculated annually in accordance with an approved formula. In a settlement of a prior transmission rate case, the parties agreed that no party would oppose the general principle of a formula rate, although the parties may still object to particular aspects of the formula. PNM’s proposed formula includes updating cost of service components, including investment in plant and operating expenses, based on information contained in PNM’s annual financial report filed with FERC, as well as including projected large transmission capital projects to be placed into service in the following year. The projections included are subject to true-up in the following year formula rate. Certain items, including changes to return on equity and depreciation rates, require a separate filing to be made with FERC before being included in the formula rate. As filed, PNM’s request would result in a $3.2 million wholesale electric transmission rate increase, based on PNM’s 2011 data and a 10.81% return on equity (“ROE”), and authority to adjust transmission rates annually based on an approved formula.

On March 1, 2013, FERC issued an order (1) accepting PNM’s revisions to its rates for filing and suspending the proposed revisions to become effective August 2, 2013, subject to refund; (2) directing PNM to submit a compliance filing to establish its ROE using the median, rather than the mid-point, of the ROEs from a proxy group of companies; (3) directing PNM to submit a compliance filing to remove from its rate proposal the acquisition adjustment related to PNM’s 60% ownership of the EIP transmission line, which was acquired in 2003 ; and (4) setting the proceeding for hearing and settlement judge procedures. PNM would be allowed to make a separate filing related to recovery of the EIP acquisition adjustment. On April 1, 2013, PNM made the required compliance filing. In addition, PNM filed for rehearing of FERC’s order regarding the ROE. On June 3, 2013, PNM made additional filings incorporating final 2012 data into the formula rate request. The updated formula rate would result in a $1.3 million rate increase over the rates approved by FERC on January 2, 2013. The new rates will apply to all of PNM’s wholesale electric transmission service customers. The new rates will not apply to PNM’s retail customers. On June 10, 2013, FERC denied PNM’s motion for rehearing regarding FERC’s order requiring PNM to use the median, instead of the midpoint, to calculate its ROE for the formula rate case. On August 2, 2013, the new rates went into effect, subject to refund. On May 1, 2014, PNM updated its formula rate incorporating 2013 data resulting in a $0.5 million rate increase over the current rates. PNM anticipates filing the updated rate request with FERC on June 1, 2014, at which time the new rates will be effective, subject to refund. Settlement negotiations are ongoing concerning issues in this proceeding. PNM is unable to predict the outcome of this proceeding.

City of Gallup, New Mexico Contract

PNM provides both energy and power services to Gallup, PNM’s second largest firm-requirements wholesale customer, under an electric service agreement that was to expire on June 30, 2013. On May 1, 2013, PNM and Gallup agreed to extend the term of the agreement to June 30, 2014 and to increase the demand and energy rates under the agreement. On May 1, 2013, PNM requested FERC approval of the amended agreement to be effective July 1, 2013. On June 21, 2013, FERC approved the amended agreement. Revenue from Gallup will have increased by $3.1 million during the term of the amended agreement.

On September 26, 2013, Gallup issued a request for proposals for long-term power supply. PNM submitted a proposal in November 2013. On March 26, 2014, Gallup notified PNM that the contract for long-term power supply had been awarded to another utility.  PNM’s contract with Gallup will expire on June 29, 2014.  PNM’s 2013 revenues for power sold under the Gallup contract were $11.7 million. 

TNMP

Advanced Meter System Deployment

In July 2011, the PUCT approved a settlement and authorized an AMS deployment plan that permits TNMP to collect $113.3 million in deployment costs through a surcharge over a 12-year period. TNMP began collecting the surcharge on August 11, 2011. Deployment of advanced meters began in September 2011 and is scheduled to be completed over a 5-year period.

In February 2012, the PUCT opened a proceeding to consider the feasibility of an “opt-out” program for retail consumers that wish to decline receipt of an advanced meter. The PUCT has requested comments and convened a public meeting to hear various issues. However, various individuals filed a petition with the PUCT seeking a moratorium on any advanced meter deployment. The PUCT denied the petition and an appeal was filed with the Texas District Court on September 28, 2012.

On February 21, 2013, the PUCT filed a proposed rule to permit customers to opt-out of the AMS deployment. The PUCT adopted a rule on August 15, 2013 creating a non-standard metering service for retail customers choosing to decline standard metering service via an advanced meter. The cost of providing non-standard metering service will be borne by opt-out customers through an initial fee and ongoing monthly charge. All transmission and distribution utilities in ERCOT are required to initiate proceedings to establish these charges.

On September 30, 2013, TNMP filed an application to set the initial fee and monthly charges to be assessed for non-standard metering service provided to those retail customers who choose to decline the advanced meter necessary for standard metering service. TNMP’s filing seeks recovery of $0.2 million through proposed initial fees ranging from $142.84 to $247.48. An additional $0.5 million in ongoing expenses would be recovered via a proposed monthly charge of $38.99. The April 8, 2014 hearing on this matter has been suspended as the parties attempt to reach a settlement. TNMP cannot predict the outcome of this proceeding although TNMP does not expect it to have a material impact on its financial position, results of operations, or cash flows.

Energy Efficiency

TNMP recovers the costs of its energy efficiency programs through an energy efficiency cost recovery factor that includes projected program costs, under or over collected costs from prior years, case expenses, and performance bonuses (if the programs exceed expectations). On August 28, 2012, the PUCT approved a settlement that permitted TNMP to collect an aggregate of $5.2 million effective January 1, 2013. On October 25, 2013, the PUCT approved a settlement that permits TNMP to collect an aggregate of $5.6 million beginning March 1, 2014. By June 1, 2014, TNMP will file its 2015 energy efficiency cost recovery factor application with the PUCT.

Transmission Cost of Service Rates

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.

On January 31, 2013, TNMP filed an application to update its transmission rates to reflect changes in its invested capital. The requested increase in total rate base is $21.9 million, which will increase revenues $2.9 million annually. The PUCT ALJ approved TNMP’s interim transmission cost of service filing and rates went into effect with bills rendered on March 20, 2013.

On August 1, 2013, TNMP filed an application to further update its transmission rates to reflect changes in its invested capital. The requested increase in total rate base is $18.1 million, which would increase revenues by $2.8 million annually. The PUCT ALJ approved TNMP’s interim transmission cost of service filing and rates went into effect with bills rendered on September 17, 2013.

On January 21, 2014, TNMP filed an application to further update its transmission rates resulting from changes in its invested capital. The requested increase in total rate base is $18.2 million, which would increase revenues by $2.9 million annually. The PUCT ALJ approved TNMP’s interim transmission cost of service filing and rates went into effect with bills rendered on March 13, 2014.