10-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

 _________________________________________________

FORM 10-K

ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the Fiscal Year Ended December 31, 2014

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

Securities Registered Pursuant To Section 12(b) Of The Act:

Registrant	Title of Each Class	Name of Each Exchange on Which Registered
PNM Resources, Inc.	Common Stock, no par value	New York Stock Exchange

Securities Registered Pursuant To Section 12(g) Of The Act:

Registrant	Title of Each Class
Public Service Company of New Mexico	1965 Series, 4.58% Cumulative Preferred Stock
	($100 stated value without sinking fund)

Indicate by check mark whether each registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.

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

Indicate by check mark if each registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.

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

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.

PNMR	YES  ü	NO
PNM	YES  ü	NO
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 if disclosure of delinquent filers pursuant to Item 405 of Regulation S–K is not contained herein, and will not be contained, to the best of registrants’ knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.  ü

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 Act).

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

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

As of February 20, 2015, shares of common stock outstanding were:

PNMR	79,653,624
PNM	39,117,799
TNMP	6,358

On June 30, 2014, the aggregate market value of the voting common stock held by non-affiliates of PNMR as computed by reference to the New York Stock Exchange composite transaction closing price of $29.33 per share reported by The Wall Street Journal, was $2,336,240,792. PNM and TNMP have no common stock held by non-affiliates.

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

DOCUMENTS INCORPORATED BY REFERENCE

Portions of the following document are incorporated by reference into Part III of this report:

Proxy Statement to be filed by PNMR with the SEC pursuant to Regulation 14A relating to the annual meeting of stockholders of PNMR to be held on May 12, 2015.

This combined Form 10-K 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-K 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-K that relate to each other registrant are not incorporated by reference therein.

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PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

INDEX

	Page
GLOSSARY	iv
PART I
ITEM 1. BUSINESS	A- 1
THE COMPANY	A- 1
WEBSITES	A- 1
OPERATIONS AND REGULATION	A- 2
REGULATED OPERATIONS
PNM	A- 2
TNMP	A- 4
CORPORATE AND OTHER	A- 5
SOURCES OF POWER	A- 5
FUEL AND WATER SUPPLY	A- 8
ENVIRONMENTAL MATTERS	A- 10
COMPETITION	A- 10
EMPLOYEES	A- 10
DISCLOSURE REGARDING FORWARD LOOKING STATEMENTS	A- 11
SECURITIES ACT DISCLAIMER	A- 12
ITEM 1A. RISK FACTORS	A- 12
ITEM 1B. UNRESOLVED STAFF COMMENTS	A- 20
ITEM 2. PROPERTIES	A- 20
ITEM 3. LEGAL PROCEEDINGS	A- 21
ITEM 4. MINE SAFETY DISCLOSURES	A- 21
SUPPLEMENTAL ITEM – EXECUTIVE OFFICERS OF PNM RESOURCES, INC.	A- 22
PART II
ITEM 5. MARKET FOR PNMR’S COMMON EQUITY, RELATED STOCKHOLDER	A- 23
MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES
ITEM 6. SELECTED FINANCIAL DATA	A- 24
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	A- 28
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURE ABOUT MARKET RISK	A- 58
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA	B- 1
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING	C- 1
AND FINANCIAL DISCLOSURE
ITEM 9A. CONTROLS AND PROCEDURES	C- 1
ITEM 9B. OTHER INFORMATION	C- 2
PART III
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS, AND CORPORATE GOVERANCE	C- 2
ITEM 11. EXECUTIVE COMPENSATION	C- 2
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT	C- 2
AND RELATED STOCKHOLDER MATTERS
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR	C- 2
INDEPENDENCE
ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES	C- 2
PART IV
ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES	D- 1
SIGNATURES	E-1

iii

GLOSSARY

Definitions:
ABO	Accumulated Benefit Obligation
Afton	Afton Generating Station
AFUDC	Allowance for Funds Used During Construction
ALJ	Administrative Law Judge
AMS	Advanced Meter System
AOCI	Accumulated Other Comprehensive Income
APBO	Accumulated Postretirement Benefit Obligation
APS	Arizona Public Service Company, the operator and a co-owner of PVNGS and Four Corners
ARO	Asset Retirement Obligation
ASU	Accounting Standards Update
BACT	Best Available Control Technology
BART	Best Available Retrofit Technology
BDT	Balanced Draft 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 Study
EPA	United States Environmental Protection Agency
EPE	El Paso Electric
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
First Choice	FCP Enterprises, Inc. and Subsidiaries
Four Corners	Four Corners Power Plant
FPL	FPL Energy New Mexico Wind, LLC
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
IRS	Internal Revenue Service

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ISFSI	Independent Spent Fuel Storage Installation
KW	Kilowatt
KWh	Kilowatt Hour
LIBOR	London Interbank Offered Rate
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
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.
NEPA	National Environmental Policy Act
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
NMAG	New Mexico Attorney General
NMED	New Mexico Environment Department
NMIEC	New Mexico Industrial Energy Consumers Inc.
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
Optim Energy	Optim Energy, LLC, a limited liability company, formerly known as EnergyCo, LLC
OSM	United States Office of Surface Mining Reclamation and Enforcement
PBO	Projected Benefit Obligation
PCRBs	Pollution Control Revenue Bonds
PG&E	Pacific Gas and Electric Co.
PNM	Public Service Company of New Mexico and Subsidiaries
PNM 2013 Term Loan Agreement	PNM’s $75.0 Million Unsecured Term Loan
PNM 2014 Term Loan Agreement	PNM’s $175.0 Million Unsecured Term Loan
PNM Multi-draw Term Loan	PNM’s $125.0 Million Unsecured Multi-draw 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
PNMR	PNM Resources, Inc. and Subsidiaries
PNMR Development	PNMR Development and Management Company, an unregulated wholly-owned subsidiary of PNMR

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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
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
Rio Bravo	Rio Bravo Generating Station, formerly know as Delta
RMC	Risk Management Committee
ROE	Return on Equity
RPS	Renewable Energy Portfolio Standard
RSIP	Revised State Implementation Plan
SCE	Southern California Edison Company
SCPPA	Southern California Public Power Authority
SCR	Selective Catalytic Reduction
SEC	United States Securities and Exchange Commission
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
SRP	Salt River Project
S&P	Standard and Poor’s Ratings Services
TCEQ	Texas Commission on Environmental Quality
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 2011 Term Loan Agreement	TNMP’s $50.0 Million Secured Term Loan
TNMP Revolving Credit Facility	TNMP’s $75.0 Million Secured Revolving Credit Facility
TNP	TNP Enterprises, Inc. and Subsidiaries
Tri-State	Tri-State Generation and Transmission Association, Inc.
Tucson	Tucson Electric Power Company
UAMPS	Utah Associated Municipal Power System
Valencia	Valencia Energy Facility
VaR	Value at Risk
WACC	Weighted Average Cost of Capital
WEG	WildEarth Guardians
WSPP	Western Systems Power Pool

vi

PART I

ITEM 1. BUSINESS

THE COMPANY

Overview

PNMR is an investor-owned holding company with two regulated utilities providing electricity and electric services in New Mexico and Texas. PNMR’s electric utilities are PNM and TNMP. PNMR is focused on achieving the following strategic goals:

• Earning authorized returns on its regulated businesses

• Continuing to improve credit ratings

• Providing a top quartile total return to investors

PNMR’s success in accomplishing these strategic goals is highly dependent on continued favorable regulatory treatment for its regulated utilities. Both PNM and TNMP seek cost recovery for their investments through general rate cases and various rate riders. PNM filed a general rate case with the NMPRC in December 2014. Additional information about rate filings is provided in Operations and Regulation below and in Note 17.

PNMR’s common stock trades on the New York Stock Exchange under the symbol PNM. PNMR was incorporated in the State of New Mexico in 2000.

Other Information

These filings for PNMR, PNM, and TNMP include disclosures for each entity. For discussion purposes, this report uses the term “Company” when discussing matters of common applicability to PNMR, PNM, and TNMP. Discussions regarding only PNMR, PNM, or TNMP are so indicated. A reference to “MD&A” in this report refers to Part II, Item 7. –Management’s Discussion and Analysis of Financial Condition and Results of Operations. A reference to a “Note” refers to the accompanying Notes to Consolidated Financial Statements.

Financial information relating to amounts of revenue, net income, and total assets of reportable segments is contained in MD&A and Note 2.

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 corporate Internet addresses are:

• PNMR: www.pnmresources.com

• PNM: www.pnm.com

• TNMP: www.tnmp.com

In addition to the corporate websites, PNM established a website, www.PowerforProgress.com, dedicated to showing how it balances delivering reliable power at affordable prices and protecting the environment. This website is designed to be a resource for the facts about PNM's operations and support efforts, including plans for building a sustainable energy future for New Mexico. The contents of these websites are not a part of this Form 10-K. 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.

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Also available on the Company’s website at http://www.pnmresources.com/corporate-governance.aspx 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.

OPERATIONS AND REGULATION

Regulated Operations

PNM

PNM is an electric utility that provides electric generation, transmission, and distribution service to its rate-regulated customers. In New Mexico, the utility’s retail electric service territory covers a large area of north central New Mexico, including the cities of Albuquerque, Rio Rancho, and Santa Fe, and certain areas of southern New Mexico. PNM also provides electricity to firm-requirements wholesale customers in New Mexico and Arizona. Service to retail electric customers is subject to the jurisdiction of the NMPRC. Service to wholesale customers is regulated by FERC. Regulation encompasses the utility’s electric rates, service, accounting, issuances of securities, construction of major new generation, types of generation resources, transmission and distribution facilities, and other matters.

Other services provided by PNM include transmission services to third parties as well as the generation and sale of electricity into the wholesale market, which services are regulated by FERC. PNM owns or leases transmission lines, interconnected with other utilities in New Mexico, Texas, Arizona, Colorado, and Utah. The largest retail electric customer served by PNM accounted for 3.4% of the utility’s revenues for the year ended December 31, 2014. PNM was incorporated in the State of New Mexico in 1917.

NMPRC Regulated Retail Rate Proceedings

Customer rates for retail electric service are set by the NMPRC. PNM filed a general rate case with the NMPRC in December 2014. PNM’s application proposes a revenue increase of $107.4 million, effective January 1, 2016, based on a calendar 2016 future year test and a ROE of 10.5%. PNM requested this increase to account for infrastructure investments made since its last rate case and investments needed in the next two years to provide reliable service to PNM’s retail customers, as well as to reflect declining sales growth in PNM’s service territory. PNM is proposing several changes to rate design to establish fair and equitable pricing across rate classes and to better align cost recovery with cost causation, including an access charge to customers installing photovoltaic systems after December 31, 2015. See Note 17 for additional information concerning this filing.

PNM’s previous general rate case filing was made in June 2010. In August 2011, the NMPRC issued a final order that included, among other things, a $72.1 million increase in annual non-fuel revenues for New Mexico retail customers. As permitted by that order, PNM filed an application in January 2012 for a rate rider to collect costs for renewable energy procurements incurred after December 31, 2010 that are not otherwise being collected in rates. The rider will terminate upon a final order in PNM’s next general rate case unless that order authorizes a continuation of the rider. 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 operation, exceeded 10.5%, it would refund to customers during May through December of the following year the amount over 10.5%. PNM’s earned return on jurisdictional equity did not exceed 10.5% in 2013 or 2014.

FERC Regulated Wholesale Operations

In October 2010, PNM filed a notice with FERC to increase its wholesale electric transmission rates for all of PNM’s wholesale electric transmission service customers, which include other utilities, electric cooperatives, and entities that use PNM’s transmission system to transmit power at the wholesale level.  The proposed rates were implemented on June 1, 2011, subject to refund. On January 2, 2013, FERC approved a settlement among the parties providing for an increase in transmission service revenues of $2.9 million annually.

In December 2012, PNM filed a notice with FERC to increase its wholesale electric transmission rates for all of its transmission customers. The filing represents a formula based rate as contemplated by the approved settlement in the case described

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above. The proposed increase of $1.3 million, as updated, went into effect, subject to refund, on August 2, 2013. On May 1, 2014, PNM updated its formula rate incorporating 2013 data resulting in a $0.5 million rate increase over the then current rates. The updated rate request went into effect on May 30, 2014, subject to refund. The parties have engaged in settlement negotiations and PNM anticipates that a settlement will be filed with FERC in the near future. There is no required time frame for FERC to act upon a settlement. PNM is unable to predict the outcome of this proceeding.

PNM has entered into firm-requirements wholesale contracts to provide electricity to various customers. These contracts contain both capacity charges and energy charges. Capacity charges are monthly payments for a commitment of resources to service the contract requirements. Energy charges are payments based on the amount of electricity delivered to the customer and are intended to compensate for the variable costs incurred to provide the energy. The average billing demands for PNM’s firm-requirements wholesale customers aggregate approximately 62 MW, excluding the contract with Gallup that expired in 2014. No firm-requirements customer of PNM accounted for more than 2.5% of PNM’s revenues for the year ended December 31, 2014.

In September 2011, PNM filed with FERC to increase rates for electric service and ancillary services provided to NEC, PNM’s largest firm-requirements wholesale customer. PNM also requested a traditional FPPAC and full recovery of certain third-party transmission charges. FERC issued an order allowing the increased rates to be collected beginning April 14, 2012, subject to refund. The parties agreed to a settlement providing for an increase in rates of $5.3 million and an extension of the contract for 10 years through December 31, 2035. FERC approved the settlement in April 2013. PNM provided both energy and power services to Gallup, which was its second largest firm-requirements wholesale customer, under an electric service agreement that expired on June 30, 2014. PNM’s recently filed general rate case discussed above includes a reallocation of costs among regulatory jurisdictions reflecting the termination of the contract to serve Gallup. See Results of Operations in MD&A and Note 17. 

PNM also provides electricity at wholesale to the City of Aztec, New Mexico under a contract that expires on June 30, 2016. In 2014, PNM entered into a contract with the Jicarilla Apache Nation to provide electricity at wholesale through May 8, 2016, which date can be extended through May 8, 2019, if approved by the NMPRC.

PNM’s current authorization under FERC regulation requires that revenue requirements for sales of electricity at wholesale are to be based on PNM’s costs of providing such service. In August 2014, PNM filed an application with FERC to allow PNM to enter into arrangements to sell electricity at wholesale prices within PNM’s balancing authority area using rates that are based on market conditions. There is no statutory requirement for FERC to act upon this application within a specified period of time. PNM cannot predict if FERC will grant the request to sell at market-based rates.

Operational Information

Weather-normalized retail electric KWh sales decreased by 1.7% in 2014 and 1.8% in 2013. The system peak demands for retail and firm-requirements customers decreased in 2014 and increased in 2013. The system peak demands were as follows:

System Peak Demands

	2014	2013	2012
	(Megawatts)
Summer	1,878	2,008	1,948
Winter	1,471	1,576	1,523

PNM holds long-term, non-exclusive franchise agreements for its electric retail operations, with varying expiration dates. These franchise agreements allow the utility to access public rights-of-way for placement of its electric facilities. Franchise agreements have expired in some areas PNM serves, including Albuquerque, Rio Rancho, and Santa Fe. Because PNM remains obligated under New Mexico state law to provide service to customers in these areas, the expirations should not have a material adverse impact. The Albuquerque, Rio Rancho, and Santa Fe metropolitan areas accounted for 48.0%, 10.5%, and 9.6% of PNM’s 2014 revenues and no other franchise area represents more than 5%. Although PNM is not required to collect or pay franchise fees in some areas it serves, the utility continues to collect and pay such fees in certain parts of its service territory, including Albuquerque, Rio Rancho, and Santa Fe.

As discussed in Note 16, the County Commission of Bernalillo County, New Mexico passed an ordinance on January 28, 2014 that would require PNM and other utilities to enter into a use agreement and pay a yet to be determined fee as a condition for installing, maintaining, and operating facilities on county rights-of-way. PNM and other utilities have filed complaints in federal and state courts challenging the validity of the ordinance. If the challenge to the ordinance is unsuccessful, PNM believes

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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.

PNM owns or leases 3,197 circuit miles of electric transmission lines that interconnect with other utilities in New Mexico, Arizona, Colorado, Texas, and Utah. There has been little development of new transmission facilities in recent years. Therefore, most of the capacity on PNM’s transmission system is fully committed during peak hours, with very little to no additional access available on a firm commitment basis. These factors result in physical constraints on the system and limit the ability to wheel power into PNM’s service area from outside of New Mexico.

PNM also generates and sells electricity into the wholesale market. Because PNM’s 134 MW share of Unit 3 at PVNGS currently is excluded from retail rates, that unit’s power is being sold in the wholesale market and any earnings or losses are realized by shareholders. PNM has contracted to sell 100% of PVNGS Unit 3 output through 2015, at market price plus a premium.  Through hedging arrangements that are accounted for as economic hedges, PNM has established fixed rates for substantially all of these sales. As discussed in Note 16, PNM has requested NMPRC approval to include PVNGS Unit 3 as a jurisdictional resource to serve New Mexico retail customers beginning in 2018 as part of the revised plan to comply with the regional haze requirements of the CAA. Beyond the PVNGS contracts, PNM also engages in activities to optimize its existing jurisdictional assets and long-term power agreements through spot market, hour ahead, day ahead, week ahead, and other sales of any excess generation not required to fulfill retail load and contractual commitments. Ninety percent of the margins from these optimization sales are credited to retail customers through the FPPAC.

Use of Future Test Year

Under New Mexico law, the NMPRC must set rates using the test period, including a future test year, that best reflects the conditions the utility will experience when new rates are anticipated to go into effect. In addition, the NMPRC must include certain construction work in progress (“CWIP”) for environmental improvement, generation, and transmission projects in rate base. These provisions are designed to promote more timely recovery of reasonable costs of providing utility service.

The use of a future test year should help PNM mitigate the adverse effects of regulatory lag, which is inherent when using a historical test year. Accordingly, the utility’s earnings should more closely reflect the rate of return allowed by the NMPRC. PNMR believes that achieving earnings that approximate its allowed rate of return is an important factor in attracting equity investors, as well as being considered favorably by credit rating agencies and financial analysts.

As discussed above, in December 2014, PNM filed a request for a general rate increase with the NMPRC, which is based on a 2016 future test year. As with any forward looking financial information, utilizing a future test year in a rate filing presents challenges that exist in the forecasting process. These include forecasts of both operating and capital expenditures that necessitate reliance on many assumptions concerning future conditions and operating results. In the rate making process, PNM’s assumptions are subject to challenge by regulators and intervenors who may assert different interpretations or assumptions.

Renewable Portfolio Standard

The REA was enacted to encourage the development of renewable energy in New Mexico. The act establishes a mandatory RPS requiring a utility to acquire a renewable energy portfolio equal to 10% by 2011, 15% by 2015, and 20% by 2020. The act provides for streamlined proceedings for approval of utilities’ renewable energy procurement plans, assures utilities recovery of 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. PNM files required renewable energy plans with the NMPRC annually and makes procurements consistent with the plans approved by the NMPRC. See Note 17.

TNMP

TNMP is a regulated utility operating in Texas. TNMP’s predecessor was organized in 1925. TNMP is incorporated in the State of Texas.

TNMP provides transmission and distribution services in Texas under the provisions of TECA and the Texas Public Utility Regulatory Act. TNMP is subject to traditional cost-of-service regulation with respect to rates and service under the jurisdiction of the PUCT and certain municipalities. Because its transmission and distribution activities are solely within ERCOT, TNMP is not subject to traditional rate regulation by FERC. TNMP serves a market of small to medium sized communities, most of which have populations of less than 50,000. TNMP is the exclusive provider of transmission and distribution services in most areas it serves.

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TNMP’s service territory consists of three non-contiguous areas. One portion of this territory extends from Lewisville, which is approximately 10 miles north of the Dallas-Fort Worth International Airport, eastward to municipalities near the Red River, and to communities north, west, and south of Fort Worth. The second portion of its service territory includes the area along the Texas Gulf Coast between Houston and Galveston, and the third portion includes areas of far west Texas between Midland and El Paso. ERCOT is the independent system operator that is responsible for maintaining reliable operations for the bulk electric power supply system in its region.

TNMP provides transmission and distribution services at regulated rates to various REPs that, in turn, provide retail electric service to consumers within TNMP’s service area. TNMP experienced increases in weather-normalized retail KWh sales of 3.2% in 2014 and 2.6% in 2013. As of December 31, 2014, 94 active REPs receive transmission and distribution services from TNMP. The acquirer of First Choice, including the former First Choice operations, accounted for 15% of TNMP’s revenues in 2014. Two other unaffiliated customers of TNMP accounted for operating revenues of 15% and 11% in 2014. No other customer accounted for more than 10% of revenues.

Regulatory Activities

In July 2011, the PUCT approved a settlement and authorized an AMS deployment plan that permits TNMP to collect $113.4 million in deployment costs through a surcharge over a 12-year period. TNMP began collecting the surcharge on August 11, 2011. Deployment of smart meters began in September 2011 and is scheduled to be completed over a 5-year period.

The PUCT approved interim adjustments to TNMP’s transmission rates of $2.5 million on September 27, 2012, $2.9 million on March 20, 2013, $2.8 million on September 17, 2013, $2.9 million on March13, 2014, and $4.2 million on September 8, 2014. On January16, 2015, TNMP filed an application to further update its transmission rates, which would increase revenues by $4.4 million annually. The application is pending before the PUCT.

Franchise Agreements

TNMP holds long-term, non-exclusive franchise agreements for its electric transmission and distribution services. These agreements have varying expiration dates and some have expired. TNMP intends to negotiate and execute new or amended franchise agreements with municipalities where the agreements have expired or will be expiring. Since TNMP is the exclusive provider of transmission and distribution services in most areas that it serves, the need to renew or renegotiate franchise agreements should not have a material adverse impact. TNMP also earns revenues from service provided to facilities in its service area that lie outside the territorial jurisdiction of the municipalities with which TNMP has franchise agreements.

Corporate and Other

The Corporate and Other segment includes PNMR holding company activities, primarily related to corporate level debt and PNMR Services Company. PNMR Services Company provides corporate services through shared services agreements to PNMR and all of PNMR’s business units, including PNM and TNMP. These services are charged and billed at cost on a monthly basis to the business units.

SOURCES OF POWER

PNM

Generation Capacity

As of December 31, 2014, the total net generation capacity of facilities owned or leased by PNM was 2,397 MW. PNM also obtains power under a long-term PPA for the power produced by New Mexico Wind, which has a capacity of 204 MW, and the output of the Lightning Dock Geothermal facility, which currently has a capacity of 4 MW. On January 1, 2015, PNM began obtaining the power output of Red Mesa Wind, which has a capacity of 102 MW.

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PNM’s capacity in electric generating facilities, which are owned, leased, or under PPAs, in commercial service as of January 1, 2015 is:

			Generation
			Capacity
Type	Name	Location	(MW)
Coal	SJGS	Waterflow, New Mexico	783
Coal	Four Corners	Fruitland, New Mexico	200
Gas	Reeves Station	Albuquerque, New Mexico	154
Gas	Afton (combined cycle)	La Mesa, New Mexico	230
Gas	Lordsburg	Lordsburg, New Mexico	80
Gas	Luna (combined cycle)	Deming, New Mexico	185
Gas/Oil	Rio Bravo, formerly known as Delta	Albuquerque, New Mexico	138
Gas	Valencia	Belen, New Mexico	158
Nuclear	PVNGS	Wintersburg, Arizona	402
Solar	PNM-owned solar	Eleven sites in New Mexico	67
Wind	New Mexico Wind	House, New Mexico	204
Wind	Red Mesa Wind	Seboyeta, New Mexico	102
Geothermal	Lightning Dock Geothermal	Lordsburg, New Mexico	4
			2,707

Fossil‑Fueled Plants

SJGS consists of four units operated by PNM. Units 1, 2, 3, and 4 at SJGS have net rated capacities of 340 MW, 340 MW, 497 MW and 507 MW. SJGS Units 1 and 2 are owned on a 50% shared basis with Tucson. SJGS Unit 3 is owned 50% by PNM, 41.8% by SCPPA, and 8.2% by Tri‑State. SJGS Unit 4 is owned 38.457% by PNM, 28.8% by MSR Public Power Agency, 10.04% by the City of Anaheim, California, 8.475% by the City of Farmington, New Mexico, 7.2% by the County of Los Alamos, New Mexico, and 7.028% by UAMPS. See Note 16 for additional information about SJGS, including the proposal to shut down Units 2 and 3 on December 31, 2017 and the restructuring of the ownership interests in SJGS.

Four Corners Units 4 and 5 are 13% owned by PNM. Units 4 and 5 at Four Corners are jointly owned with APS, SRP, Tucson, and EPE and are operated by APS. PNM had no ownership interest in Four Corners Units 1, 2, or 3, which were shutdown by APS on December 30, 2013. The Four Corners plant site is leased from the Navajo Nation and is also subject to an easement from the federal government. APS, on behalf of the Four Corners participants, negotiated amendments to an existing facility lease with the Navajo Nation, which extends the Four Corners leasehold interest from 2016 to 2041. 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. PNM cannot predict whether the 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 PNM and the other Four Corners owners. See Note 16 for additional information about Four Corners.

PNM owns 100% of Reeves, Afton, Rio Bravo, and Lordsburg and one-third of Luna. The remaining interests in Luna are owned equally by Tucson and Samchully Power & Utilities 1, LLC. Prior to July 17, 2014 when PNM closed on the purchase of Rio Bravo, PNM was entitled to its energy and capacity under a PPA. PNM has a PPA that entitles it to the entire output of Valencia. Valencia is a variable interest entity and is consolidated by PNM as required by GAAP. Therefore, Valencia is reflected in the above table as if it were owned. Reeves, Lordsburg, Rio Bravo, and Valencia are used primarily for peaking power and transmission support. See Note 9 for additional information about Rio Bravo and Valencia, including the potential purchase of 50% of Valencia.

Nuclear Plant

PNM is participating in the three units of PVNGS, also known as the Arizona Nuclear Power Project, with APS (the operating agent), SRP, EPE, SCE, SCPPA, and the Department of Water and Power of the City of Los Angeles. PNM is entitled to 10.2% of the power and energy generated by PVNGS. PNM has ownership interests of 2.3% in Unit 1, 4.6% in Unit 2, and 10.2% in Unit 3 and has leasehold interests of 7.9% in Unit 1 and 5.6% in Unit 2. The lease payments for the leased portions of

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PVNGS are recovered through retail rates approved by the NMPRC. See Note 7 for additional information concerning the PVNGS leases, including agreements with the lessors of the PVNGS Unit 1 leases and one of the PVNGS Unit 2 leases for PNM to renew those leases and agreements with the lessors of the other three Unit 2 leases for PNM to exercise its fair market purchase options to purchase the assets underlying those leases. See Note 16 for information on other PVNGS matters, including PNM’s proposal to include PVNGS Unit 3 as a jurisdictional resource to serve New Mexico retail customers.

On March 11, 2011, a 9.0 magnitude earthquake occurred off the northeastern coast of Japan. The earthquake produced tsunamis that caused significant damage to the Fukushima Daiichi Nuclear Power Station in Japan. Following these events, the NRC established a task force to conduct a systematic and methodical review of NRC processes and regulations to determine whether the agency should make additional improvements to its regulatory system. In March 2012, the NRC issued the first regulatory requirements based on the recommendations of the task force. With respect to PVNGS, the NRC issued two orders requiring safety enhancements regarding: (1) mitigation strategies to respond to extreme natural events resulting in the loss of power at plants; and (2) enhancement of spent fuel pool instrumentation. The NRC has issued a number of guidance documents regarding implementation of these requirements. Due to the developing nature of these requirements, PNM cannot predict the financial or operational impacts on PVNGS. However, PVNGS expects to spend approximately $40 million for capital enhancements to the plant over the next two years in addition to the approximately $80 million that has already been spent on capital enhancements as of December 31, 2014. PNM’s share of these enhancements would be 10.2%, substantially all of which are included in PNM’s current projection of capital expenditures.

Solar

In 2011, PNM completed its first major utility-owned renewable energy project aggregating 22 MW when five utility-scale solar facilities in New Mexico went online. In addition to these facilities, PNM completed its solar-storage demonstration project in Albuquerque, which has a generation capacity of 0.5 MW and is included in the above table. In 2013, PNM completed the installation of an additional 21.5 MW of utility-owned solar capacity at four sites, including expansion of capacity at two of the existing sites. In 2014, PNM completed construction of an additional 23 MW of PNM-owned solar PV facilities at three additional sites. PNM’s 2015 renewable energy procurement includes the construction by December 31, 2015 of an additional 40 MW of PNM-owned solar PV facilities.

Plant Operating Statistics

Equivalent availability of PNM’s major base-load generating stations was:

Plant	Operator	2014	2013	2012
SJGS	PNM	76.5%	77.6%	81.7%
Four Corners	APS	68.1%	72.9%	83.5%
PVNGS	APS	91.8%	89.4%	90.6%

Joint Projects

SJGS, PVNGS, Four Corners, and Luna are joint projects each owned or leased by several different entities. Some participants in the joint projects are investor-owned entities, while others are municipally or co-operatively owned. Furthermore, participants in SJGS have varying percentage interests in different generating units within the project. The primary operating or participation agreements for the joint projects expire in July 2016 for Four Corners, July 2022 for SJGS, December 2046 for Luna, and November 2047 for PVNGS. In addition, SJGS and Four Corners are coal-fired generating plants that obtain their coal requirements from mines near the plants. The agreement for coal supply for SJGS expires on December 31, 2017. In late December 2013, the coal supply arrangement for Four Corners was extended through 2031. As described above, Four Corners is situated on land under a lease from the Navajo Nation. Portions of PNM’s interests in PVNGS Units 1 and 2 are leased. See Nuclear Plant above and Note 7 regarding PNM’s actions related to options under these leases. Several of the participants in the joint projects are located in California. There are legislative and regulatory mandates in California that may prohibit utilities from entering into new, or extending existing, arrangements for coal-fired generation. It is also possible that the participants in the joint projects have changed circumstances and objectives from those existing at the time of becoming participants. The status of these joint projects is further complicated by the uncertainty surrounding the form of potential legislation and/or regulation of CCBs, GHG, and other air emissions, as well as the impacts of the costs of compliance and operational viability of all or certain units within the joint projects. It is unclear how these factors will enter into discussion and negotiations concerning the status of the joint projects as the expiration of basic operational agreements approaches. PNM can provide no assurance that its participation in the joint projects will continue in the manner that currently exists. See Note 16 for a discussion of potential restructuring of SJGS ownership and developments with respect to Four Corners.

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PPAs

In addition to generating its own power, PNM purchases power under long-term PPAs. PNM also purchases power in the forward, day-ahead, and real-time markets.

In 2002, PNM entered into an agreement with FPL to develop New Mexico Wind. PNM began receiving power from the project in June 2003. FPL owns and operates New Mexico Wind, which consists of 136 wind-powered turbines having an aggregate capacity of 204 MW on a site in eastern New Mexico. PNM has a contract to purchase all the power and RECs generated by New Mexico Wind for 25 years. The NMPRC has approved a voluntary tariff that allows PNM retail customers to buy renewable electricity for a small monthly premium. Power from New Mexico Wind is used to service load under the voluntary tariff and as part of PNM’s electric supply mix for meeting retail load.

PNM has a 20-year agreement to purchase energy and RECs from the Lightning Dock Geothermal facility built near Lordsburg. The facility, which is the first geothermal project for the PNM system, began providing limited power to PNM on January 1, 2014. The current capacity of the facility is 4 MW and future expansion may result in up to 10 MW of generation capacity.

In June 2013, PNM entered into a 20 year PPA with Red Mesa Wind, LLC, a subsidiary of NextEra Energy Resources, LLC, to purchase all of the power and RECs produced by Red Mesa Wind beginning on January 1, 2015. Red Mesa Wind, LLC owns and operates the facility, which consists of 64 wind-powered turbines having an aggregate capacity of 102 MW on a site west of Albuquerque.

A summary of purchased power, excluding Rio Bravo and Valencia, is as follows:

	Year Ended December 31,
	2014		2013		2012
Purchased under long-term PPAs
MWh	492,906		490,539		546,321
Cost per MWh	$	27.82	$	27.25	$	27.25
Other purchased power
Total MWh	1,023,744		1,061,514		948,911
Cost per MWh	$	40.30	$	35.64	$	27.30

TNMP

TNMP provides only transmission and distribution services and does not sell power.

FUEL AND WATER SUPPLY

PNM

The percentages of PNM’s generation of electricity (on the basis of KWh), including Valencia and Rio Bravo, fueled by coal, nuclear fuel, and gas and oil, and the average costs to PNM of those fuels per MMBTU were as follows:

	Coal				Nuclear				Gas and Oil
	Percent of Generation		Average Cost		Percent of Generation		Average Cost		Percent of Generation		Average Cost
2014	56.7	%	$	3.00	32.0	%	$	0.83	10.3	%	$	4.26
2013	56.8	%	$	2.62	30.4	%	$	0.88	12.2	%	$	4.12
2012	59.2	%	$	2.99	31.3	%	$	0.88	9.0	%	$	3.25

In 2014, 2013, and 2012, 1.0%, 0.6%, and 0.5% of PNM’s generation was from utility owned solar, which has no fuel cost. The generation mix for 2015 is expected to be 56.7% coal, 30.7% nuclear, 11.0% gas and oil, and 1.6% utility owned solar. Due to locally available natural gas and oil supplies, the utilization of locally available coal deposits, and the generally adequate supply of nuclear fuel, PNM believes that adequate sources of fuel are available for its generating stations into the foreseeable future. See Sources of Power – PNM – PPAs for information concerning the cost of purchased power.

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Coal

The coal supply contract that provides fuel for SJGS expires on December 31, 2017. Coal supply has not been arranged for periods after the existing contract expires although negotiations are ongoing. PNM believes there is adequate availability of coal resources to continue to operate SJGS although an extended or new contract could result in higher prices. In late December 2013, the expiration date of the coal supply contract for Four Corners was extended from 2016 to 2031. Coal costs are anticipated to increase approximately 30% at the inception of the new contract. The contract provides for pricing adjustments over its term based on economic indices. See Note 16 for additional information about PNM’s coal supply.

Natural Gas

The natural gas used as fuel for the electric generating plants is procured on the open market and delivered by third party transportation providers. The supply of natural gas can be subject to disruptions due to extreme weather events and/or pipeline or facility outages. PNM has contracted for firm gas transmission capacity to minimize the potential for disruptions due to extreme weather events. PNM’s natural gas plants are generally used as peaking resources that are highly relied upon during periods of extreme weather, which also may be the times natural gas has the highest demand from other users.

Nuclear Fuel and Waste

PNM is one of several participants in PVNGS. The PVNGS participants are continually identifying their future nuclear fuel resource needs and negotiating arrangements to fill those needs. The PVNGS participants have contracted for all of PVNGS’s requirements for uranium concentrates and conversion services through 2018 and 45% of its requirements in 2019-2020. The participants have also contracted for 100% of PVNGS’s enrichment services through 2020. All of PVNGS’s fuel assembly fabrication services are contracted through 2022.

The Nuclear Waste Policy Act of 1982 required the DOE to begin to accept, transport, and dispose of spent nuclear fuel and high level waste generated by the nation’s nuclear power plants by 1998. The DOE’s obligations are reflected in a contract with each nuclear power plant. The DOE failed to begin accepting spent nuclear fuel by 1998. APS (on behalf of itself and the other PVNGS participants) has pursued legal actions. See Note 16 for information concerning these actions.

The DOE had planned to meet its disposal obligations by designing, licensing, constructing, and operating a permanent geologic repository at Yucca Mountain, Nevada. In March 2010, the DOE filed a motion to dismiss with prejudice its Yucca Mountain construction authorization application that was pending before the NRC. Several interested parties have intervened in the NRC proceeding. Additionally, a number of interested parties have filed a variety of lawsuits in different jurisdictions around the country challenging the DOE’s authority to withdraw the Yucca Mountain construction authorization application. None of these lawsuits has been conclusively decided by the courts. However, in August 2013, the D.C. Circuit ordered the NRC to resume its review of the application with available appropriated funds.

On October 16, 2014, the NRC issued Volume 3 of the safety evaluation report developed as part of the Yucca Mountain construction authorization application. This volume addresses repository safety after permanent closure, and its issuance is a key milestone in the Yucca Mountain licensing process. Volume 3 contains the staff’s finding that the DOE’s repository design meets the requirements that apply after the repository is permanently closed, including but not limited to the post-closure performance objectives in NRC’s regulations. On December 18, 2014, the NRC issued Volume 4 of the safety evaluation report developed as part of the Yucca Mountain construction authorization application. This volume covers administrative and programmatic requirements for the repository. It documents the staff’s evaluation of whether the DOE’s research and development and performance confirmation programs, as well as other administrative controls and systems, meet applicable NRC requirements. Volume 4 contains the staff’s finding that most administrative and programmatic requirements in NRC regulations are met, except for certain requirements relating to ownership of land and water rights. Publication of Volumes 3 and 4 does not signal whether or when the NRC might authorize construction of the repository.

All spent nuclear fuel from PVNGS is being stored on-site. PVNGS has sufficient capacity at its on-site ISFSI to store all of the nuclear fuel that will be irradiated during the initial operating license periods, which end in November 2027. Additionally, PVNGS has sufficient capacity at its on-site ISFSI to store a portion of the fuel that will be irradiated during the extended license periods, which end in November 2047. If uncertainties regarding the United States government’s obligation to accept and store spent fuel are not favorably resolved, the PVNGS participants will evaluate alternative storage solutions. These may obviate the need to expand the ISFSI to accommodate all of the fuel that will be irradiated during the extended license periods.

Water Supply

See Note 16 for information about PNM’s water supply.

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ENVIRONMENTAL MATTERS

Electric utilities are subject to stringent laws and regulations for protection of the environment by local, state, federal, and tribal authorities. In addition, PVNGS is subject to the jurisdiction of the NRC, which has the authority to issue permits and licenses and to regulate nuclear facilities in order to protect the health and safety of the public from radioactive hazards and to conduct environmental reviews pursuant to NEPA. The liabilities under these laws and regulations can be material. In some instances, liabilities may be imposed without regard to fault, or may be imposed for past acts, whether or not such acts were lawful at the time they occurred. The construction expenditure projection includes environmental upgrades at SJGS and Four Corners aggregating $72.1 million in 2015 and $78.6 million in 2016 through 2019, as discussed in Note 16. See MD&A – Other Issues Facing the Company – Climate Change Issues for information on GHG. In addition, Note 16 contains information related to the following matters, incorporated in this item by reference:

• PVNGS Decommissioning Funding

• Nuclear Spent Fuel and Waste Disposal

• Environmental Matters under the caption “The Clean Air Act”

• WEG v. OSM NEPA Lawsuit

• Navajo Nation Environmental Issues

• Cooling Water Intake Structures

• Effluent Limitation Guidelines

• Santa Fe Generating Station

• Environmental Matters under the caption “Coal Combustion Byproducts Waste Disposal”

• Hazardous Air Pollutants (“HAPs”) Rulemaking

COMPETITION

Regulated utilities are generally not subject to competition from other utilities in areas that are under the jurisdiction of state regulatory commissions. In New Mexico, PNM does not have direct competition for services provided to its retail electric customers. In Texas, TNMP is not currently in any direct retail competition with any other regulated electric utility. However, PNM and TNMP are subject to customer conservation and energy efficiency activities as well as initiatives to utilize alternative energy sources, including self-generation, or otherwise bypass the PNM and TNMP systems.

PNM is subject to varying degrees of competition in certain territories adjacent to or within the areas it serves. This competition comes from other utilities in its region as well as rural electric cooperatives and municipal utilities.  PNM is involved in the generation and sale of electricity into the wholesale market.  It is subject to competition from regional utilities and merchant power suppliers with similar opportunities to generate and sell energy at market-based prices and larger trading entities that do not own or operate generating assets.

EMPLOYEES

The following table sets forth the number of employees of PNMR, PNM, and TNMP as of December 31, 2014:

	PNMR	PNM	TNMP
Corporate (1)	433	—	—
PNM	1,093	1,093	—
TNMP	355	—	355
Total	1,881	1,093	355

(1)Represents employees of PNMR Services Company.

As of December 31, 2014, PNM had 593 employees in its power plant and operations areas that are currently covered by a collective bargaining agreement with the IBEW Local 611 that was entered into in July 2012 and expires April 30, 2015. Negotiations for a new agreement with the IBEW began in January 2015.  While the Company is optimistic that a timely agreement will be reached, PNM cannot, at this time, predict the outcome of the negotiations.  PNM is currently working on contingency planning for certain scenarios that may occur as a result of negotiations. The wages and benefits for all PNM employees who are members of the IBEW are typically included in the rates charged to electric customers, subject to approval of the NMPRC.

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.

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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 began. 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. As of December 31, 2014, TNMP had 195 employees represented by IBEW Local 66. In January 2015, a decertification election was held for those employees covered by the original petition. The employees voted to retain union representation. The parties have reached a tentative agreement on a collective bargaining agreement. A vote of the union members on whether to ratify the agreement is in process.

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 treatment of SJGS Units 2 and 3 at the date of their proposed early retirement

• 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 potential future environmental compliance matters

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

• State and federal regulation or legislation relating to environmental matters, including the RSIP 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 ability of the Company to successfully forecast and manage its operating and capital expenditures

• Physical and operational risks related to climate change and potential financial risks resulting from climate change litigation and legislative and regulatory efforts to limit GHG

• 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, fuel quality, unplanned outages, extreme weather conditions, terrorism, cybersecurity breaches, and other catastrophic events

• 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

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

• 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 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

• The risk that FERC rulemakings may negatively impact the operation of PNM’s transmission system

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

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

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

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

• Changes in applicable accounting principles or policies

For information about the risks associated with the use of derivative financial instruments see Part II, Item 7A. “Quantitative and Qualitative Disclosures About Market Risk.”

SECURITIES ACT DISCLAIMER

Certain securities described 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-K does not constitute an offer to sell or the solicitation of an offer to buy any securities.

ITEM 1A.RISK FACTORS

The business and financial results of PNMR, PNM, and TNMP are subject to a number of risks and uncertainties, including those set forth below and in MD&A, Note 16, and Note 17. TNMP provides transmission and distribution services to REPs that provide electric service to consumers in TNMP’s service territories. References to customers in the risk factors discussed below also encompass the customers of these REPs who are the ultimate consumers of electricity transmitted and distributed through TNMP’s facilities.

Regulatory Factors

The profitability of PNMR’s utilities depends on being able to recover their costs through regulated rates and earn a fair return on invested capital. PNM and TNMP are in a period of significant capital expenditures. While increased capital investments and other costs are placing upward pressure on rates, energy efficiency and a sluggish New Mexico economy are reducing usage by customers.

The rates PNM charges its customers are regulated by the NMPRC and FERC. TNMP is regulated by the PUCT. The Company is in a period requiring significant capital investment and is projecting total construction expenditures for the years 2015-2019 to be $2,207.3 million. See Note 14. PNM and TNMP anticipate a trend toward increasing costs, for which it will have to seek regulatory recovery. These costs include or are related to:

• Environmental compliance expenditures

• The proposed early retirement of SJGS Units 2 and 3 as part of a revised plan to comply with the regional haze provisions of the CAA, including treatment of their net book value at the date of retirement and costs of generation capacity to replace those units

• New asset construction related to generation, transmission, and distribution systems necessary to provide electric service

• The regulatory mandate to acquire power from renewable resources

• Increased regulation related to nuclear safety

• Fuel costs

• Increased interest costs to finance capital investments

• Depreciation

At the same time costs are increasing, there are factors placing downward pressures on the demand for power, thereby reducing load growth and customer usage. These factors include:

• Changing customer behaviors, including increased emphasis on energy efficiency measures and utilization of alternative sources of power

• Reduced new sources of demand

• Reductions in costs of energy efficient technology

• Unpredictable weather patterns

• Adverse economic conditions

In 2014 and 2013, PNM experienced decreases in weather-normalized retail sales of 1.7% and 1.8%. The sales decreases reflect a continued sluggish economy in New Mexico. In particular, the Albuquerque metropolitan area continues to lag the nation in economic recovery. After several years of being relatively flat, New Mexico’s employment showed modest growth in 2014 and

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only modest growth is anticipated in the near future. Also, low population growth will result in low growth in the number of customers. In Texas, the drop in oil prices has impacted the economy although it remains relatively strong.

The combination of costs increasing relatively rapidly and the slowing of customer usage places upward pressure on the per unit prices that must be charged to recover costs. This upward pressure on unit prices could result in additional efforts by customers to reduce consumption through energy efficiency or to pursue self-generation or other alternative sources of power. Without timely cost recovery and the authorization to earn a reasonable return on invested capital, the Company’s liquidity and results of operations could be negatively impacted.

Under New Mexico law, utilities may propose the use of a future test year in establishing rates. As with any forward looking financial information, a future test year presents challenges that are inherent in the forecasting process. Forecasts of both operating and capital expenditures necessitate reliance on many assumptions concerning future conditions and operating results. Accordingly, if rate requests based on a future test year cannot be successfully supported, cash flows and results of operations may be negatively impacted. This could result from not being able to withstand challenges from regulators and intervenors regarding the utility’s capability to make reasonable forecasts.

The coal supply contract that currently provides fuel for SJGS expires on December 31, 2017. Negotiations for a new coal supply contract, which are in process, could result in higher prices. In late December 2013, the expiration date of the coal supply contract for Four Corners was extended from 2016 to 2031. Coal costs are anticipated to increase approximately 30% at the inception of the new contract. The contract provides for pricing adjustments over its term based on economic indices. PNM currently recovers the cost of fuel for its generation facilities through its FPPAC. Although PNM believes costs under new coal supply arrangements would continue to be recovered through the FPPAC, there can be no assurance that full recovery would be allowed.

PNMR’s utilities are subject to numerous federal, state, and local environmental laws and regulations that may significantly limit or affect their operations and financial results.

Compliance with federal, state, and local environmental laws and regulations, including those addressing climate change, air quality, CCBs, discharges of wastewater originating from fly ash and bottom ash handling facilities, cooling water, and other matters, may result in increased capital, operating, and other costs, particularly with regard to enforcement efforts focused on power plant emission obligations. These costs could include remediation, containment, civil liability, and monitoring expenses. The Company cannot predict how they would be affected if existing environmental laws and regulations were to be revised or reinterpreted, or if new environmental statutes and rules were to be adopted. See Note 16 and the Climate Change Issues subsection of the Other Issues Facing the Company section of MD&A.

EPA, environmental advocacy groups, other organizations, and some other federal and state agencies are predicted to focus considerable attention on GHG from power generation facilities, including the role of those facilities in climate change. PNM depends on fossil-fueled generation for a significant share of its electricity. Therefore, it could be exposed to possible future GHG regulations imposed by New Mexico and/or the federal government. For example, as discussed in the Climate Change Issues subsection of the Other Issues Facing the Company section of MD&A, EPA has proposed its GHG NSPS rules for new sources, as well as modified and existing EGU’s. Any such proposals that become regulations could result in additional operating restrictions on facilities and increased generation and compliance costs.

CCBs from the operation of SJGS are currently being used in the reclamation of a surface coal mine. These CCBs consist of fly ash, bottom ash, and gypsum. Any new regulation that would affect the reclamation process, including mine use of CCBs being classified as hazardous waste by EPA, could significantly increase the costs of the disposal of CCBs and the costs of mine reclamation. See Note 16.

A regulatory body may identify a site requiring environmental cleanup and designate PNM or TNMP as a responsible party. There is also uncertainty in quantifying exposure under environmental laws that impose joint and several liability on all potentially responsible parties. Failure to comply with environmental laws and regulations, even if caused by factors beyond PNM’s or TNMP’s control, may result in the assessment of civil or criminal penalties and fines.

BART determinations have been made for both SJGS and Four Corners under the program to address regional haze in the “four corners” area, which would reduce the levels of NOx emitted at both plants. Significant capital expenditures will be required for the installation of control technology at both generating stations and operating costs would increase.PNMR and its operating subsidiaries may underestimate the costs of environmental compliance, liabilities, and litigation due to the uncertainty inherent in these matters. Although there is uncertainty about the timing and form of regulations regarding climate change, CCBs, and other power plant emissions, such regulations could have a material impact on operations. Timely regulatory recovery of

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costs associated with any environmental-related regulations would be needed to maintain a strong financial and operational profile. The above factors could adversely affect the Company’s business, financial position, results of operations, and liquidity.

PNM has a case pending before the NMPRC requesting regulatory approvals necessary for PNM to comply with the regional haze requirements of the CAA pertaining to SJGS. Failure to obtain the approval of the NMPRC in this matter could impact PNM’s ability to efficiently operate SJGS, which could have a negative impact on PNM’s business, financial condition, results of operations, and cash flows.

SJGS, which currently comprises 28.9% of PNM’s owned and leased generation capacity and is its largest generation resource, is subject to the CAA. In February 2013, PNM, NMED, and EPA agreed to pursue a revised plan regarding SJGS. In October 2014, EPA published its approval of NMED’s RSIP, which requires the installation of SNCRs on SJGS Units 1 and 4 combined with the shutdown of SJGS Units 2 and 3. PNM believes significant progress is being made towards implementation of the RSIP. In order to retire San Juan Units 2 and 3, final binding agreements must be reached among the SJGS owners on a revised ownership structure of SJGS, as well as addressing continuing liabilities for reclamation, decommissioning, environmental, and other matters. The participants are attempting to agree on these items and are engaged in ongoing mediated negotiations, but binding agreements have not been reached.

The coal supply contract that currently provides fuel for SJGS expires on December 31, 2017. Coal supply has not been arranged for periods after the existing contract expires. In order for the participants to approve the restructuring of ownership in SJGS, they have indicated they need to obtain greater certainty regarding fuel supply for SJGS for the period after December 31, 2017. The remaining participants in SJGS are in the process of negotiating agreements concerning future fuel supply for SJGS. The date for negotiation of a transaction has been extended until May 1, 2015. However, it is possible that the participants may not be able to negotiate a new contract for coal supply or that a new contract for coal could result in higher prices, either of which could impact the restructuring process.

PNM has a filing pending before the NMPRC that requests the regulatory approvals required to effectuate the RSIP. A public hearing on PNM’s requests was held in January 2015 and PNM believes it justified that its requests provide the best alternative for New Mexico retail ratepayers in order to comply with the requirements of the CAA. Final approvals from the NMPRC are necessary to implement the RSIP. PNM believes that for the NMPRC to approve PNM’s requests, the SJGS participants will have to reach binding agreements regarding restructuring ownership in SJGS. In the NMPRC proceeding, PNM has committed to reaching binding agreements on restructuring by May 1, 2015. For the participants to reach such agreements, it is likely that the remaining participants in SJGS will need to have completed negotiations regarding the coal supply for SJGS for periods after December 31, 2017.

Additional information regarding the RSIP, the restructuring negotiations, the request for NMPRC approvals, and coal supply is discussed in Note 16.

PNM can provide no assurance that these requirements will be accomplished or that the NMPRC will approve PNM’s requests. If NMPRC approval is not obtained, PNM may not be able to implement the RSIP. If the RSIP requirements ultimately are not implemented due to adverse or alternative regulatory, legislative, legal, or restructuring developments or other factors, PNM would need to pursue other alternatives to address compliance with the CAA.In such circumstances, PNM could be forced to temporarily or permanently cease operation of some or all of the SJGS units. If a shutdown was required, PNM would then have to acquire 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. To the extent any additional costs incurred are not allowed to be recovered from customers through the ratemaking process, PNM’s financial condition, results of operation, and cash flows could be negatively impacted.

It is also possible that failure to reach a satisfactory agreement to restructure SJGS ownership, requirements to comply with the final BART determinations, the financial impact of possible future climate change regulation or legislation, if any, other environmental regulations, the result of litigation, the adequacy and timeliness of cost recovery mechanisms, and other business considerations, could jeopardize the economic viability of the plant or the ability of individual participants to continue participation in SJGS.

PNMR, PNM, and TNMP are subject to complex government regulation unrelated to the environment, which may have a negative impact on their businesses, financial position and results of operations.

To operate their businesses, PNMR, PNM, and TNMP are required to have numerous permits and approvals from a variety of regulatory agencies. Regulatory bodies with jurisdiction over the utilities include the NMPRC, NMED, PUCT, TCEQ, ERCOT,

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FERC, NRC, EPA, and NERC. Oversight by these agencies covers many aspects of the Company’s utility operations including: location, construction, and operation of facilities; the purchase of power under long-term contracts; conditions of service; the issuance of securities; and rates charged to customers. FERC has issued a number of rules pertaining to preventing undue discrimination in transmission services and electric reliability standards.

PNMR and its subsidiaries are unable to predict the impact on their business and operating results from future actions of any agency regulating the Company. Changes in existing regulations or the adoption of new ones could result in additional expenses and/or changes in business operations. In turn, operating results could be adversely impacted. 

Operational Factors

Customer electricity usage could be reduced by increases in prices charged and other factors.  This could result in underutilization of PNM’s generating capacity, as well as the capacities of PNM’s and TNMP’s transmission and distribution systems.  Should this occur, operating and capital costs might not be fully recovered, and financial performance could be negatively impacted.

A number of factors influence customers’ electricity purchases.  These factors include, but are not limited to:

• Rates charged by PNM and TNMP

• Rates charged by REPs utilizing TNMP’s facilities to deliver power

• Energy efficiency initiatives

• Availability and cost of alternative sources of power

• National, regional, or local economic conditions

These factors and others may prompt customers to institute additional energy efficiency measures or take other actions that would result in lower power consumption. If customers bypass or underutilize PNM’s and TNMP’s facilities through self-generation, renewable or other energy resources, technological change, or other measures, revenues would be negatively impacted.

PNM’s and TNMP’s service territories include several military bases and federally funded national laboratories, as well as large industrial customers that have significant direct and indirect impacts on the local economies where they operate.  The Company does not directly provide service to any of the military bases or national laboratories, but does provide service to large industrial customers. The Company’s business could be hurt from the impacts on the local economies associated with these customer groups, as well as directly from the large industrial customers, for a number of reasons, including:

• Federally-mandated base closures or significant curtailment of the activities at the bases or national laboratories

• Closure of industrial facilities or significant curtailment of their activities

Another factor that could negatively impact the Company is that proposals are periodically advanced in various localities to municipalize, or otherwise take over PNM’s facilities, which PNM believes would require state legislative action to implement, or to establish new municipal utilities in areas currently served by PNM.  For example, officials in the City of Santa Fe, New Mexico have indicated a desire to reduce the carbon footprint of the city, which could include exploring renewable resources dedicated to serve the city, a partnership with existing utilities, or the feasibility of a city-owned municipal electric utility. PNM is monitoring that situation. If any such initiative is successful, the result could be a material reduction in the usage of the facilities, a reduction in rate base, and reduced earnings.

Should any of the above factors result in facilities being underutilized, the Company’s financial position, operational results, and cash flows could be significantly impacted.

Costs of decommissioning, remediation, and restoration of nuclear and fossil-fueled power plants, as well as related coal mines, could exceed the estimates of PNMR and PNM, which could negatively impact results of operations and liquidity.

PNM has interests in a nuclear power plant, two coal-fired power plants, and several natural gas-fired power plants. PNM is obligated to pay for the costs of decommissioning its share of the power plants. PNM is also obligated to pay for its share of the costs of decommissioning the mines that supply coal to the coal-fired power plants. Likewise, other owners or participants are responsible for their shares of the decommissioning obligations and it is important to PNM that those parties fulfill their obligations. Rates charged by PNM to its customers, as approved by the NMPRC, include a provision for recovery of certain costs of decommissioning, remediation, and restoration. The NMPRC has established a cap on the amount of decommissioning costs for the surface coal mines that may be recovered from customers. PNM records estimated liabilities for its share of the legal

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obligations for decommissioning and reclamation. These estimates include many assumptions about future events and are inherently imprecise. In the event any of these costs exceed current estimates, results of operations could be negatively impacted.

The financial performance of PNMR, PNM, and TNMP may be adversely affected if power plants and transmission and distribution systems do not operate reliably and efficiently.

The Company’s financial performance depends on the successful operation of PNM’s generation assets, as well as the transmission and distribution systems of PNM and TNMP. Unscheduled or longer than expected maintenance outages, breakdown or failure of equipment or processes due to aging infrastructure, temporary or permanent shutdowns to achieve environmental compliance, other performance problems with the electric generation assets, severe weather conditions, accidents and other catastrophic events, acts of war or terrorism, disruptions in the supply, quality, and delivery of fuel and water supplies, and other factors could result in PNM’s load requirements being larger than available system generation capacity. Assured supplies of water are important for PNM’s generating plants. Water in the southwestern United States is limited and there are conflicting claims regarding water rights. In addition, the “four corners” region where two of PNM’s power plants are located is prone to drought conditions, which could potentially affect the plants’ water supplies. In addition, unplanned outages of generating units and extensions of scheduled outages occur from time to time and are an inherent risk of the Company’s business. If these were to occur, PNM would be required to purchase electricity in either the wholesale market or spot market at the then-current market price. There can be no assurance that sufficient electricity would be available at reasonable prices, or available at all. The failure of transmission or distribution facilities may also affect PNM’s and TNMP’s ability to deliver power. These potential generation, distribution, and transmission problems, and any service interruptions related to them, could result in lost revenues and additional costs.

PNMR, PNM, and TNMP are subject to information security breaches and risks of unauthorized access to their information and operational technology systems as well as physical threats to assets.

The Company faces the risk of physical and cyber attacks, both threatened and actual, against generation facilities, transmission and distribution infrastructure used to transport power, and information technology systems and network infrastructure, which could negatively impact the ability of the Company to generate, transport, and deliver power, or otherwise operate facilities in the most efficient manner or at all.

The Company functions in a highly regulated industry that requires the continued operation of sophisticated information technology systems and network infrastructure, some of which are deemed to be critical infrastructure under NERC guidelines. Certain of the Company’s systems are interconnected with external networks. In the regular course of business, the utilities handle a range of sensitive security and customer information. PNM and TNMP are subject to the rules of various agencies concerning safeguarding and maintaining the confidentiality of this information.

In the event a party desires to disrupt the bulk power or transmission systems in the United States, the Company’s computer and operating systems could be subject to physical or cyber attack.  Although the Company has implemented security measures, critical infrastructure, including information and operational technology systems, are vulnerable to disability, failures, or unauthorized access.  A successful physical or cyber attack or other similar failure of the systems could impact the reliability of PNM’s generation and PNM’s and TNMP’s transmission and distribution systems, including the possible unauthorized shutdown of facilities. Such an event could lead to significant disruptions of business operations, including the Company’s ability to generate, transport, and deliver power to serve customers, to bill customers, and to process other financial information. A major physical or cyber incident could lead to increased regulatory oversight, litigation, fines, other remedial action, and reputational damage. The costs incurred to investigate and remediate a physical or cyber security attack could be significant. If the Company’s systems were to fail or be breached and not recovered in a timely way, critical business functions could be impaired and sensitive or confidential data could be compromised. A physical or cyber attack on the Company’s critical infrastructure could have a material adverse impact on the operations and financial condition of PNMR, PNM, and TNMP.

There are inherent risks in the ownership and operation of nuclear facilities.

PNM has a 10.2% undivided interest in PVNGS, including interests in Units 1 and 2 held under leases. PVNGS represents 16.8% of PNM’s total owned and leased generating capacity. PVNGS is subject to environmental, health, and financial risks, including, but not limited to:

• The ability to obtain adequate supplies of nuclear fuel and water

• The ability to dispose of spent nuclear fuel

• Decommissioning of the plant

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• Securing the facilities against possible terrorist attacks

• Unscheduled outages due to equipment failures

PNM maintains trust funds designed to provide adequate financial resources for decommissioning at the end of the expected life of the PVNGS units. However, if the units are decommissioned before their planned date, these funds may prove to be insufficient. PNM also has external insurance coverage to minimize its financial exposure to some risks. However, it is possible that liabilities associated with nuclear operations could exceed the amount of insurance coverage. See Note 16.

The NRC has broad authority under federal law to impose licensing and safety-related requirements for the operation of nuclear generation facilities. Events at nuclear facilities of other operators or impacting the industry generally may lead the NRC to impose additional requirements and regulations on all nuclear generation facilities, including PVNGS. As a result of the March 2011 earthquake and tsunamis that caused significant damage to the Fukushima Daiichi Nuclear Power Plant in Japan, various industry organizations are working to analyze information from the Japan incident and develop action plans for nuclear power plants in the United States. Additionally, the NRC has been performing its own independent review of the events at Fukushima Daiichi, including a review of the agency’s processes and regulations in order to determine whether the agency should promulgate additional regulations and possibly make more fundamental changes to the NRC’s system of regulation. PNM cannot predict when or if the NRC will complete its formal actions as a result of its review. However, PVNGS expects to spend approximately $40 million for capital enhancements to the plant over the next two years in addition to the approximately $80 million that has already been spent on capital enhancements as of December 31, 2014. PNM’s share of these enhancements would be 10.2%, substantially all of which are included in PNM’s current projection of capital expenditures. PNM cannot predict whether these amounts will increase or whether additional financial and/or operational requirements on PVNGS may be imposed.

In the event of noncompliance with its requirements, the NRC has the authority to impose a progressively increased inspection regime that could ultimately result in the shut down of a unit or civil penalties, or both, depending upon the NRC’s assessment of the severity of the situation, until compliance is achieved. Increased costs resulting from penalties, a heightened level of scrutiny, and/or implementation of plans to achieve compliance with NRC requirements could adversely affect the financial condition, results of operations, and cash flows of PNMR and PNM. Although PNM has no reason to anticipate a serious nuclear incident at PVNGS, if an incident did occur, it could materially and adversely affect PNM’s results of operations and financial condition.  A major incident at a nuclear facility anywhere in the world could cause the NRC to limit or prohibit the operation or licensing of any domestic nuclear unit and to promulgate new regulations that could require significant capital expenditures and/or increase operating costs.

Demand for power could exceed supply capacity, resulting in increased costs for purchasing capacity in the open market or building additional generation facilities.

PNM is obligated to supply power to retail customers and certain wholesale customers. At peak times, power demand could exceed PNM’s available generation capacity. Market forces, competitive forces, or adverse regulatory actions may require PNM to purchase capacity on the open market or build additional generation capabilities. Regulators or market conditions may not permit PNM to pass all of these purchases or construction costs on to customers. If that occurs, PNM may not be able to fully recover these costs. Or, there may be a lag between when costs are incurred and when regulators permit recovery in customers’ rates. These situations could have negative impacts on results of operations and cash flows.

General Economic and Weather Factors

General economic conditions of the nation and/or specific areas can affect the Company’s customers and suppliers. Economic recession or downturn may result in decreased consumption by customers and increased bad debt expense, and could also negatively impact suppliers, all of which could negatively impact the Company.

Economic activity is a key factor in PNMR subsidiaries’ performance. Decreased economic activity can lead to declines in energy consumption, which could adversely affect future revenues, earnings, and growth.  Higher unemployment rates, both in the Company’s service territories and nationwide, could result in commercial customers ceasing operations and lower levels of income for residential customers. These customers might then be unable to pay their bills on time, which could increase bad debt expense and negatively impact results of operations and cash flows. Economic conditions also impact the supply and/or cost of commodities and materials needed to construct or acquire utility assets or make necessary repairs.

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The operating results of PNMR and its operating subsidiaries fluctuate on a seasonal and quarterly basis as well as being affected by weather conditions, including regional drought.

Electric generation, transmission, and distribution are generally seasonal businesses that vary with the demand for power. With power consumption typically peaking during the hot summer months, revenues traditionally peak during that period. As a result, quarterly operating results of PNMR and its operating subsidiaries vary throughout the year. In addition, PNMR and its operating subsidiaries have historically had lower revenues resulting in lower earnings when weather conditions are milder. Unusually mild weather in the future could reduce the revenues, net earnings, and cash flows of the Company.

Drought conditions in New Mexico, especially in the “four corners” region, where SJGS and Four Corners are located, may affect the water supply for PNM’s generating plants.  If inadequate precipitation occurs in the watershed that supplies that region, PNM may have to decrease generation at these plants. This would require PNM to purchase power to serve customers and/or reduce the ability to sell excess power on the wholesale market and reduce revenues. Drought conditions or actions taken by regulators or legislators could limit PNM’s supply of water, which would adversely impact PNM’s and PNMR’s business. Although PNM has in place supplemental contracts and voluntary shortage sharing agreements with tribes and other water users in the “four corners” region, PNM cannot be certain these contracts will be enforceable in the event of a major drought or that it will be able to renew these contracts in the future.

TNMP’s service areas are exposed to extreme weather, including high winds, drought, flooding, and periodic hurricanes. Extreme weather conditions, particularly high winds and severe thunderstorms, also occur periodically in PNM’s service areas. These severe weather events can physically damage TNMP’s and PNM’s owned facilities. Any such occurrence both disrupts the ability to deliver energy and increases costs. Extreme weather can also reduce customers’ usage and demand for energy. These factors could negatively impact results of operations and cash flows.

Financial Factors

PNMR may be unable to meet its ongoing and future financial obligations and to pay dividends on its common stock if its subsidiaries are unable to pay dividends or distributions to PNMR.

PNMR is a holding company and has no operations of its own. PNMR’s ability to meet its financial obligations and to pay dividends on its common stock primarily depends on the net income and cash flows of PNM and TNMP and their capacity to pay upstream dividends or distributions. Prior to providing funds to PNMR, PNM and TNMP have financial and regulatory obligations that must be satisfied, including among others, debt service and, in the case of PNM, preferred stock dividends.

The NMPRC has placed certain restrictions on the ability of PNM to pay dividends to PNMR, including that PNM cannot pay dividends that cause its debt rating to fall below investment grade. The NMPRC has also restricted PNM from paying dividends in any year, as determined on a rolling four-quarter basis, in excess of net earnings without prior NMPRC approval. PNM is permitted to pay dividends to PNMR from prior equity contributions made by PNMR. Additionally, PNM has various financial covenants that limit the transfer of assets, through dividends or other means.

Further, the ability of PNMR to declare dividends depends upon:

• The extent to which cash flows will support dividends

• The Company’s financial circumstances and performance

• NMPRC’s and PUCT’s decisions in various regulatory cases currently pending and which may be docketed in the future

• Conditions imposed by the NMPRC or PUCT

• The effect of federal regulatory decisions and legislative acts

• Economic conditions in the United States and in the Company’s service areas

• Future growth plans and the related capital requirements

• Other business considerations

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Disruption in the credit and capital markets may impact the Company’s strategy and ability to raise capital.

PNMR and its subsidiaries rely on access to both short-term and longer-term capital markets as sources of liquidity for any capital requirements not satisfied by cash flow from operations, including energy infrastructure investments and new projects. In general, the Company relies on its short-term credit facilities as the initial source to finance construction expenditures. This results in increased borrowings under the facilities over time. The Company is currently projecting total construction expenditures for the years 2015-2019 to be $2,207.3 million. If PNMR or its operating subsidiaries are not able to access capital at competitive rates, or at all, PNMR’s ability to finance capital requirements and implement its strategy will be limited. Disruptions in the credit markets, which could negatively impact the Company’s access to capital, could be caused by:

• An economic recession

• Declines in the health of the banking sector generally, or the failure of specific banks who are parties to the Company’s credit facilities

• Deterioration in the overall health of the utility industry

• The bankruptcy of an unrelated energy company

• War, terrorist or cybersecurity attacks, or threatened attacks

If the Company’s cash flow and credit and capital resources are insufficient to fund capital expenditure plans, the Company may be forced to delay important capital investments, sell assets, seek additional equity or debt capital, or restructure debt. In addition, insufficient cash flows and capital resources may result in reductions of credit ratings. This could negatively impact the Company’s ability to incur additional indebtedness on acceptable terms and would result in an increase in the interest rates applicable under the Company’s credit facilities. The Company’s cash flow and capital resources may be insufficient to pay interest and principal on debt in the future. If that should occur, the Company’s capital raising or debt restructuring measures may be unsuccessful or inadequate to meet scheduled debt service obligations. This could cause the Company to default on its obligations and further impair liquidity.

Reduction in credit ratings or changing rating agency requirements could materially and adversely affect the Company’s growth, strategy, business, financial position, results of operations, and liquidity.

PNMR, PNM, and TNMP cannot be sure that any of their current ratings will remain in effect for any given period of time or that a rating will not be put under review for a downgrade, lowered, or withdrawn entirely by a rating agency. Downgrades or changing requirements could result in increased borrowing costs due to higher interest rates in future financings, a smaller potential pool of investors, and decreased funding sources. Such conditions also could require the provision of additional support in the form of letters of credit and cash or other collateral to various counterparties.

Declines in values of marketable securities held in trust funds for pension and other postretirement benefits and in the NDT could result in sustained increases in costs and funding requirements for those obligations, which may affect operational results.

The Company targets 21% of its pension trust funds and 70% of its trust funds for other postretirement benefits to be invested in marketable equity securities. Over one-half of funds held in the NDT are typically invested in marketable equity securities. Declines in market values could result in increased funding of the trusts as well as the recognition of losses as impairments for the NDT and additional expense for the benefit plans.

Impairments of goodwill and long-lived assets of PNMR, PNM, and TNMP could adversely affect the Company’s business, financial position, liquidity, and results of operations.

PNMR, PNM, and TNMP annually evaluate their recorded goodwill for impairment. They also assess long-lived assets whenever indicators of impairment exist. Factors that affect the long-term value of these assets as well as other economic and market conditions could result in impairments. Significant impairments could adversely affect the Company’s business, financial position, liquidity, and results of operations.

PNM’s PVNGS leases describe certain events, including “Events of Loss” and “Deemed Loss Events”, the occurrence of which could require PNM to take ownership of the underlying assets and pay the lessors for the assets.

The “Events of Loss” generally relate to casualties, accidents, and other events at PVNGS, including the occurrence of specified nuclear events, which would severely adversely affect the ability of the operating agent, APS, to operate, and the ability of PNM to earn a return on its interests in PVNGS.  The “Deemed Loss Events” consist primarily of legal and regulatory changes (such as issuance by the NRC of specified violation orders, changes in law making the sale and leaseback transactions illegal, or

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changes in law making the lessors liable for nuclear decommissioning obligations). PNM believes that the probability of such “Events of Loss” or “Deemed Loss Events” occurring is remote for the following reasons: (1) to a large extent, prevention of “Events of Loss” and some “Deemed Loss Events” is within the control of the PVNGS participants through the general PVNGS operational and safety oversight process; and (2) other “Deemed Loss Events” would involve a significant change in current law and policy. PNM is unaware of any proposals pending or being considered for introduction in Congress, or in any state legislative or regulatory body that, if adopted, would cause any of those events. See Note 7.

Governance Factors

Provisions of PNMR’s organizational documents, as well as several other statutory and regulatory factors, will limit another party’s ability to acquire PNMR and could deprive PNMR’s shareholders of the opportunity to receive a takeover premium for shares of PNMR’s common stock.

PNMR’s restated articles of incorporation and by-laws include a number of provisions that may have the effect of discouraging persons from acquiring large blocks of PNMR’s common stock, or delaying or preventing a change in control of PNMR. The material provisions that may have such an effect include:

• Authorization for the Board to issue PNMR’s preferred stock in series and to fix rights and preferences of the series (including, among other things, voting rights and preferences with respect to dividends and other matters)

• Advance notice procedures with respect to any proposal other than those adopted or recommended by the Board

• Provisions specifying that only a majority of the Board, the chairman of the Board, the chief executive officer, or holders of at least one-tenth of all of PNMR’s shares entitled to vote may call a special meeting of stockholders

Under the New Mexico Public Utility Act, NMPRC approval is required for certain transactions that may result in PNMR’s change in control or exercise of control, including ownership of 10% or more of PNMR’s voting stock. Certain acquisitions of PNMR’s outstanding voting securities also require FERC approval.

ITEM 1B. UNRESOLVED STAFF COMMENTS

None.

ITEM 2. PROPERTIES

PNMR

The significant properties owned by PNMR include those owned by PNM and TNMP and are disclosed below.

PNM

See Sources of Power in Part I, Item. 1 Business above for information on PNM’s owned and leased capacity in electric generating stations. As of December 31, 2014, PNM owned, jointly owned, or leased, 3,197 circuit miles of electric transmission lines (including the EIP), 5,851 miles of distribution overhead lines, 5,715 cable miles of underground distribution lines (excluding street lighting), and 280 substations. PNM’s electric transmission and distribution lines are generally located within easements and rights-of-way on public, private, and Native American lands. The EIP line is a 223 mile, 345 kilovolt line with a capacity of 200 MW. PNM leases interests in PVNGS Units 1 and 2 and related property, EIP and associated equipment, data processing, communication, office and other equipment, office space, vehicles, and real estate. PNM also owns and leases service and office facilities in Albuquerque and in other areas throughout its service territory. See Note 7 for additional information concerning leases, including notices given to the lessors under the PVNGS leases that PNM would renew certain of the leases and would exercise its option to purchase the assets underlying certain other leases at the expiration of the original lease terms. As discussed in Note 7, PNM agreed to exercise its option to purchase the leased portion of the EIP at expiration of the lease at fair market value. See Note 9 for additional information about Valencia, including the potential purchase of 50% of Valencia.

TNMP

TNMP’s facilities consist primarily of transmission and distribution facilities located in its service areas. TNMP also owns and leases service and office facilities in other areas throughout its service territory. As of December 31, 2014, TNMP owned 966 circuit miles of overhead electric transmission lines, 7,085 pole miles of overhead distribution lines, 1,152 circuit miles of underground distribution lines, and 109 substations. Substantially all of TNMP’s property is pledged to secure its first mortgage bonds. See Note 6.

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ITEM 3. LEGAL PROCEEDINGS

See Note 16 and Note 17 for information related to the following matters for PNMR, PNM, and TNMP, incorporated in this item by reference.

Note 16

• 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

• Coal Combustion Byproducts Waste Disposal – Sierra Club Consent Decree

• 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 Nations Allottee Matters

Note 17

• PNM – 2014 Electric Rate Case

• PNM – Renewable Portfolio Standard

• PNM – Renewable Energy Rider

• PNM – Energy Efficiency and Load Management

• PNM – FPPAC Continuation Application

• PNM – Integrated Resource Plan

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

• PNM – Transmission Rate Case

• PNM – Formula Transmission Rate Case

• TNMP – Advanced Meter System Deployment

• TNMP – Remand of ERCOT Transmission Rates for 1999 and 2000

• TNMP – Energy Efficiency

• TNMP – Transmission Cost of Service Rates

ITEM 4. MINE SAFETY DISCLOSURES

Not Applicable.

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SUPPLEMENTAL ITEM – EXECUTIVE OFFICERS OF PNM RESOURCES, INC.

All officers are elected annually by the Board of PNMR. Executive officers, their ages as of February 20, 2015 and offices held with PNMR for the past five years, or other companies if less than five years with PNMR, are as follows:

Name	Age	Office	Initial Effective Date
P. K. Collawn	56	Chairman, President, and Chief Executive Officer	January 2012
		President and Chief Executive Officer	March 2010
		President and Chief Operating Officer	August 2008
C. N. Eldred	61	Executive Vice President and Chief Financial Officer	July 2007
P. V. Apodaca	63	Senior Vice President, General Counsel and Secretary	January 2010
		University Counsel, University of New Mexico	May 2006
R. E. Talbot	54	Senior Vice President and Chief Operating Officer	January 2012
		Chief Operating Officer, Power Supply and Power Delivery – Indianapolis Power and Light Company	June 2011
		Senior Vice President, Power Supply – Indianapolis Power and Light Company	February 2007
R. N. Darnell	57	Senior Vice President, Public Policy	January 2012
		Vice President, Regulatory Affairs	April 2008
T. G. Sategna (1)	61	Vice President and Corporate Controller	October 2003

⁽¹⁾ On December 9, 2014, T. G. Sategna notified the Company that he intends to retire as the Company’s principal accounting officer effective as of March 31, 2015. Mr. Sategna has agreed to continue employment with PNMR Services Company through December 31, 2015 to (among other things) assist the Company and his successor in the transition process. On December 11, 2014, the Company appointed J. D. Tarry as its Vice President and Controller (and principal accounting officer), effective as of April 1, 2015. His appointment was approved by the Board on February 26, 2015. Mr. Tarry, 44, joined the Company in 1996 and has served as Vice President, Customer Service and Chief Information Officer since May 2012. From January 1, 2010 through May 2012, he served as Executive Director of Financial Planning and Business Analysis.

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PART II

ITEM 5. MARKET FOR PNMR’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS, AND ISSUER PURCHASES OF EQUITY SECURITIES

PNMR’s common stock is traded on the New York Stock Exchange (Symbol: PNM). Ranges of sales prices of PNMR’s common stock, reported as composite transactions, and dividends declared on the common stock for 2014 and 2013, by quarters, are as follows:

Quarter Ended	Range of Sales Prices				Dividends Declared Per Share
	High		Low
2014
March 31	$	27.15	$	23.53	$	0.185
June 30	29.33		26.28		0.185
September 30	29.80		24.27		0.185
December 31	31.39		25.18		0.200
Fiscal Year	31.39		23.53		0.755
2013
March 31	$	23.29	$	20.28	$	0.165
June 30	24.01		21.35		0.165
September 30	24.29		21.25		0.165
December 31	24.28		22.21		0.185
Fiscal Year	24.29		20.28		0.680

Dividends on PNMR’s common stock are declared by its Board. The timing of the declaration of dividends is dependent on the timing of meetings and other actions of the Board. This has historically resulted in dividends considered to be attributable to the second quarter of each year being declared through actions of the Board during the third quarter of the year. The Board declared dividends on common stock considered to be for the second quarter of $0.165 per share in July 2013 and $0.185 per share in July 2014, which are reflected as being in the second quarter above. The Board declared dividends on common stock considered to be for the third quarter of $0.165 per share in September 2013 and $0.185 per share in September 2014, which are reflected as being in the third quarter above. On February 26, 2015, the Board declared a quarterly dividend of $0.20 per share. PNMR targets a long-term dividend payout ratio of 50% to 60% of consolidated earnings. During the period it was outstanding, PNMR’s Series A convertible preferred stock was entitled to receive dividends equivalent to any dividends paid on PNMR common stock as if the preferred stock had been converted into common stock.

On February 20, 2015, there were 10,283 holders of record of PNMR’s common stock. All of the outstanding common stock of PNM and TNMP is held by PNMR.

See Note 5 for a discussion on limitations on the payments of dividends and the payment of future dividends, as well as dividends paid by PNM and TNMP.

See Part III, Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters.

Preferred Stock

PNM is not aware of any active trading market for its cumulative preferred stock. Quarterly cash dividends were paid on PNM’s outstanding cumulative preferred stock at the stated rates during 2014 and 2013. PNMR and TNMP do not have any preferred stock outstanding.

Sales of Unregistered Securities

None.

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ITEM 6. SELECTED FINANCIAL DATA

The selected financial data and comparative operating statistics for PNMR should be read in conjunction with the Consolidated Financial Statements and Notes thereto and MD&A. PNMR sold First Choice on November 1, 2011. First Choice is included in the following information through October 31, 2011. PNMR fully impaired its equity method investment in Optim Energy in 2010 and recorded no income or loss for that investment through September 23, 2011, when Optim Energy was restructured reducing PNMR’s ownership to 1%.

PNM RESOURCES, INC. AND SUBSIDIARIES
	2014			2013			2012			2011			2010
	(In thousands except per share amounts and ratios)
Total Operating Revenues	$	1,435,853		$	1,387,923		$	1,342,403		$	1,700,619		$	1,673,517
Net Earnings (Loss)	$	130,909		$	115,556		$	120,125		$	190,934		$	(31,124	)
Net Earnings (Loss) Attributable to PNMR	$	116,254		$	100,507		$	105,547		$	176,359		$	(45,215	)
Net Earnings (Loss) Attributable to PNMR per Common Share
Basic	$	1.46		$	1.26		$	1.32		$	1.98		$	(0.49	)
Diluted	$	1.45		$	1.25		$	1.31		$	1.96		$	(0.49	)
Cash Flow Data
Net cash flows from operating activities	$	414,876		$	386,587		$	281,349		$	292,240		$	287,352
Net cash flows from investing activities	$	(485,329	)	$	(331,446	)	$	(285,895	)	$	19,778		$	(275,906	)
Net cash flows from financing activities	$	96,194		$	(61,593	)	$	(1,560	)	$	(312,331	)	$	(10,683	)
Total Assets	$	5,829,325		$	5,500,210		$	5,372,583		$	5,204,613		$	5,225,083
Long-Term Debt, including current installments	$	1,975,090		$	1,745,420		$	1,672,290		$	1,674,013		$	1,565,847
Common Stock Data
Market price per common share at year end	$	29.63		$	24.12		$	20.51		$	18.23		$	13.02
Book value per common share at year end	$	21.61		$	21.01		$	20.19		$	19.76		$	17.90
Tangible book value per share at year end	$	18.12		$	17.52		$	16.70		$	16.27		$	14.10
Average number of common shares outstanding – diluted	80,279			80,431			80,417			89,757			91,557
Dividends declared per common share	$	0.755		$	0.680		$	0.580		$	0.500		$	0.500
Capitalization
PNMR common stockholders’ equity	46.4		%	48.8		%	48.9		%	48.3		%	47.8		%
Convertible preferred stock	—			—			—			—			3.1
Preferred stock of subsidiary, without mandatory redemption requirements	0.3			0.3			0.3			0.3			0.4
Long-term debt	53.3			50.9			50.8			51.4			48.7
	100.0		%	100.0		%	100.0		%	100.0		%	100.0		%

Note: The book value per common share at year end, tangible book value per share at year end, average number of common shares outstanding, and return on average common equity reflect the 477,800 shares of PNMR Series A convertible preferred stock as if it was converted into common stock through September 23, 2011, when it was retired by PNMR.

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PNM RESOURCES, INC. AND SUBSIDIARIES
COMPARATIVE OPERATING STATISTICS
	2014		2013		2012		2011		2010
	(In thousands)
PNM Revenues
Residential	$	411,412	$	411,579	$	409,005	$	390,380	$	355,905
Commercial	428,085		415,621		413,332		386,383		355,699
Industrial	73,002		74,552		78,637		73,742		65,358
Public authority	25,278		25,745		25,495		23,970		21,302
Economy service	39,123		32,909		25,354		21,141		20,218
Transmission	38,284		38,228		39,373		43,637		38,667
Firm-requirements wholesale	38,313		42,370		39,390		34,127		31,870
Other sales for resale	82,508		67,538		47,321		69,318		121,729
Mark-to-market activity	5,996		293		892		4,214		(3,599		)
Other	5,913		7,477		13,465		10,377		9,979
Total PNM Revenues	$	1,147,914	$	1,116,312	$	1,092,264	$	1,057,289	$	1,017,128
TNMP Revenues
Residential	$	114,826	$	111,373	$	103,255	$	100,290	$	83,645
Commercial	99,701		95,098		88,258		84,896		77,474
Industrial	15,049		13,084		13,405		13,065		12,342
Other	58,362		52,056		45,222		39,607		39,127
Total TNMP Revenues	$	287,938	$	271,611	$	250,140	$	237,858	$	212,588
First Choice Revenues
Residential	$	—	$	—	$	—	$	260,161	$	305,834
Commercial	—		—		—		166,498		159,785
Trading gains (losses)	—		—		—		—		(4		)
Other	—		—		—		12,791		17,588
Total First Choice Revenues	$	—	$	—	$	—	$	439,450	$	483,203

Notes: Under TECA, consumers in Texas can choose any REP to provide energy. TNMP delivers energy to consumers within its service area regardless of the REP chosen. Therefore, TNMP earns revenue for energy delivery and REPs earn revenue on the usage of that energy by its customers. The revenues reported above for TNMP include $33.8 million and $39.1 million received from First Choice in 2011 and 2010.     

First Choice is included through October 31, 2011, when it was sold by PNMR.

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PNM RESOURCES, INC. AND SUBSIDIARIES
COMPARATIVE OPERATING STATISTICS
	2014	2013	2012	2011	2010
PNM MWh Sales
Residential	3,169,071	3,304,350	3,323,544	3,402,842	3,361,472
Commercial	3,874,292	3,954,774	4,022,184	4,043,796	4,015,999
Industrial	984,130	1,041,160	1,136,011	1,132,110	1,073,475
Public authority	251,187	266,368	279,169	282,062	263,424
Economy service	758,629	719,342	635,305	428,757	376,458
Firm-requirements wholesale	527,597	654,135	651,972	650,356	677,508
Other sales for resale	2,271,480	2,061,851	1,652,225	2,076,869	2,203,787
Total PNM MWh Sales	11,836,386	12,001,980	11,700,410	12,016,792	11,972,123
TNMP MWh Sales
Residential	2,802,768	2,796,661	2,714,511	2,862,337	2,699,601
Commercial	2,564,751	2,451,299	2,353,135	2,360,998	2,260,505
Industrial	2,727,064	2,598,442	2,727,126	2,578,877	2,241,452
Other	102,118	104,516	103,856	108,664	103,341
Total TNMP MWh Sales	8,196,701	7,950,918	7,898,628	7,910,876	7,304,899
First Choice MWh Sales
Residential	—	—	—	2,006,437	2,267,836
Commercial	—	—	—	1,538,203	1,363,746
Total First Choice MWh Sales	—	—	—	3,544,640	3,631,582

Notes: The MWh reported above for TNMP include 836,599 and 1,012,842 MWh for 2011 and 2010, used by consumers who chose First Choice as their REP. These MWh are also included in the First Choice MWh sales.

First Choice is included through October 31, 2011, when it was sold by PNMR.

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PNM RESOURCES, INC. AND SUBSIDIARIES
COMPARATIVE OPERATING STATISTICS
	2014		2013		2012		2011		2010
PNM Customers
Residential	455,907		453,218		450,507		448,979		447,789
Commercial	55,853		55,447		54,953		54,468		54,005
Industrial	249		251		250		251		259
Economy service	1		1		1		1		1
Other sales for resale	39		34		36		28		46
Other	911		928		952		983		1,003
Total PNM Customers	512,960		509,879		506,699		504,710		503,103
TNMP Consumers
Residential	199,963		196,799		193,550		192,356		190,809
Commercial	38,033		37,460		36,819		37,208		37,356
Industrial	70		70		70		73		72
Other	2,044		2,070		2,037		2,092		2,099
Total TNMP Consumers	240,110		236,399		232,476		231,729		230,336
First Choice Customers
Residential	—		—		—		176,577		172,506
Commercial	—		—		—		44,485		41,695
Total First Choice Customers	—		—		—		221,062		214,201
PNMR Generation Statistics
Net Capability – MW, including PPAs	2,707		2,572		2,537		2,547		2,631
Coincidental Peak Demand – MW	1,878		2,008		1,948		1,938		1,973
Average Fuel Cost per MMBTU	$	2.415	$	2.237	$	2.308	$	2.267	$	2.064
BTU per KWh of Net Generation	10,422		10,308		10,289		10,441		10,237

Notes: The consumers reported above for TNMP include 64,732 and 70,366 consumers for 2011 and 2010, who chose First Choice as their REP. These TNMP customers are also included in the First Choice customers.

First Choice is as of October 31, 2011, when it was sold by PNMR.

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ITEM 7. 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-K General Instruction I (2). A reference to a “Note” in this Item 7 refers to the accompanying Notes to Consolidated Financial Statements included in Part II, Item 8, 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 753,000 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

• Continuing to improve 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

• 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. PNM filed a general rate case with the NMPRC in December 2014. PNM’s application proposes a revenue increase of $107.4 million, effective January 1, 2016, based on a calendar 2016 future year test and a ROE of 10.5%. PNM requested this increase to account for infrastructure investments made since its last rate case and investments needed in the next two years to provide reliable service to PNM’s retail customers, as well as to reflect declining sales growth in PNM’s service territory. The infrastructure investments account for approximately 92% of the rate increase. PNM’s success with energy efficiency programs is a contributing factor to the decline in sales growth and accounts for the balance of the rate increase after offsetting cost reductions. PNM is proposing several changes to rate design to establish fair and equitable pricing across rate classes and to better align cost recovery with cost causation, including an access charge to customers installing photovoltaic systems after December 31, 2015.

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 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.

In 2012, PNM completed rate proceedings for all of its FERC regulated transmission customers and for NEC, its largest generation services customer, which improved PNM’s returns for providing those services. However, the contract to provide power to Gallup, PNM’s second largest customer for wholesale generation services, ended on June 29, 2014. PNM’s recently filed general rate case discussed above includes a reallocation of costs among regulatory jurisdictions reflecting the termination of the contract to serve Gallup. 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. The parties have engaged in settlement negotiations and

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PNM anticipates that a settlement will be filed with FERC in near future. There is no required time frame for FERC to act upon a settlement. Additional information about rate filings is provided in Note 17.

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

Currently, PNM's 134 MW interest in PVNGS Unit 3 is excluded from NMPRC jurisdictional rates. The power generated from that interest is currently sold into the wholesale market and any earnings or losses are realized by shareholders. 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. 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.

Continuing to Improve Credit Ratings

PNM is committed to improving its credit ratings. See the subheading Liquidity included in the full discussion of Liquidity and Capital Resources below for the specific credit ratings for PNMR, PNM, and TNMP. On January 30, 2014, Moody’s raised the credit ratings for PNMR, PNM and TNMP by one notch, while maintaining the positive outlook. On April 30, 2014, S&P changed the outlook for PNMR, PNM, and TNMP to positive from stable. Currently, all of the credit ratings issued by both Moody’s and S&P on the Company’s debt are investment grade.

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% to 13%. Ongoing earnings, which is a non-GAAP financial measure, excludes certain non-recurring, infrequent, and other items from earnings determined in accordance with GAAP.

PNMR targets a dividend payout ratio of 50% to 60% of its ongoing earnings. The annual common stock dividend was raised by 16% in February 2012, 14% in February 2013, 12% in December 2013, and 8% in December 2014. 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, communities, and stockholders. 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 aware of the important 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 reliable electric service.

In September 2011, TNMP began its deployment of smart meters in homes and businesses across its Texas service area. Through the end of 2014, TNMP had completed installation of more than 184,000 smart meters, which is approximately 80% of the anticipated total. TNMP’s deployment is expected to be completed in 2016.

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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. TNMP is currently installing a new outage management system that will leverage capabilities of the smart meters to enhance TNMP’s responsiveness to outages.

During the 2012 to 2014 period, PNM and TNMP together invested $1,062.8 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. The facility is expected to go into service in late 2015. On July 17, 2014, PNM completed the purchase of Rio Bravo, formerly known as Delta, a 132 MW gas-fired peaking facility, which has served PNM jurisdictional needs under a 20-year PPA since 2000.

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. PNM filed its 2014 IRP on July 1, 2014. The four-year action plan was consistent with the replacement resources identified in PNM’s application to retire SJGS Units 2 and 3 discussed below. PNM indicated that it planned to meet its anticipated long-term load growth with a combination of additional renewable energy resources, energy efficiency, and natural gas-fired facilities.

Environmentally Responsible Power

PNMR has a long-standing record of environmental stewardship. PNM’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 that also demonstrate progress in addressing proposed new federal regulations for CO₂ emissions from existing power plants

• 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 25% 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. As discussed below, PNM has requested approval to shut down SJGS Units 2 and 3, which would reduce water consumption at that plant by about 50%. In addition to the above areas of focus, the Company is working to reduce the amount of solid waste going to landfills through increased recycling and reduction of waste. The Company has performed well in this area in the past and expects to continue to do so in the future.

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 capacity 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 included 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. PNM’s 2015 renewable energy procurement plan meets RPS and diversity requirements within the RCT in 2015 and 2016. PNM’s proposed new procurements include the construction of 40 MW of PNM-owned solar PV facilities in 2015, which are contemplated in PNM’s application to retire SJGS Units 2 and 3 discussed below.

In addition to PNM’s utility-owned PV solar facilities, PNM 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 has a PPA for the output from a 204 MW wind facility and purchases power from a customer-owned distributed solar generation program that had an installed capacity of 39 MW at the end of 2014. 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. 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.

In August 2011, EPA issued a FIP for regional haze that would have required 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 RSIP from the State of New Mexico. The RSIP has been approved by the EIB and EPA.

The RSIP would achieve similar visibility improvements as the installation of SCRs on all four units at SJGS at a lower cost to PNM customers. It has the added advantage of reducing other emissions beyond NOx, including SO₂, particulate matter, CO₂, and mercury, as well as reducing water usage.

In December 2013, PNM made a filing with the NMPRC requesting certain approvals necessary to effectuate the RSIP. On October 1, 2014, PNM filed a stipulation with the NMPRC that, if approved, would settle this case. The stipulation is supported to by the staff of the NMPRC, the NMAG, and NMIEC. The stipulation is opposed by other intervenors.

Under the terms of the stipulation, PNM would:

• Retire SJGS Units 2 and 3 at December 31, 2017 and recover over 20 years 50% of their undepreciated net book value at that date, after transferring $26 million to SJGS Unit 4, and earn a regulated return on those costs

• Acquire an additional 132 MW of SJGS Unit 4

• Include PNM’s ownership of PVNGS Unit 3 as a resource to serve New Mexico retail customers effective January 1, 2018 at a value of $221.1 million ($1,650 per KW)

• File for recovery of up to $90.6 million of costs for the installation of SNCR equipment and the additional equipment to comply with NAAQS requirements on SJGS Units 1 and 4

• Not recover approximately $20 million of increased operations and maintenance expenses and other costs incurred in connection with CAA compliance

There would be no initial cost for PNM to acquire the additional 132 MW of SJGS Unit 4 although PNM’s share of capital improvements, including the costs of installing SNCRs, and operating expenses would increase to reflect the increased ownership.

A public hearing in the NMPRC case was held in January 2015. PNM expects a decision from the NMPRC in the second quarter of 2015. PNM is unable to predict if the NMPRC will approve the stipulation. If the stipulation is approved as filed, PNM anticipates that upon approval it would incur a regulatory disallowance, which would include the write-off of 50% of the undepreciated investment in SJGS Units 2 and 3, an offset to the regulatory disallowance to reflect including the investment in PVNGS Unit 3 in the ratemaking process at the stipulated value, and other impacts of the stipulation. PNM currently estimates the net pre-tax regulatory disallowance would be between $60 million and $70 million. See Note 16.

The December 20, 2013 filing also identified 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. The additional solar capacity is included in PNM’s 2015 renewable procurement strategy (Note 17). Specific approval for the additional gas facility and the treatment of associated costs will be addressed 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 non-binding resolution, approved by the SJGS Coordination Committee on June 26, 2014, identifies the participants who would be exiting active participation in SJGS effective December 31, 2017, and participants, including PNM, who would retain an interest in the ongoing operation of one or more units of SJGS. The non-binding resolution provides the essential terms of restructured ownership of SJGS between the exiting participants and the remaining participants and addresses other related matters. Also, on June 26, 2014, a non-binding term sheet was approved by all of the remaining participants that provides the essential terms of restructured ownership of SJGS among the remaining participants. The non-binding resolution and term sheet recognize that prior to executing a binding restructuring agreement, the remaining participants will need to have greater certainty

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in regard to the economic cost and availability of fuel for SJGS for the period after December 31, 2017. See Coal Supply in Note 16, for additional information. In September 2014, the SJGS participants executed a binding Fuel and Capital Funding Agreement to implement certain provisions of the above resolution. The Fuel and Capital Funding Agreement was approved by FERC on November 13, 2014. On January 7, 2015, one of the participants in SJGS Unit 4 notified the other participants that it will not acquire additional MWs in Unit 4, leaving 65 MWs unsubscribed in that unit. PNM has indicated that it will not acquire any of the unsubscribed MWs. However, a scenario is being evaluated in which PNMR Development would acquire the 65 MWs. The participant’s action was taken under the Fuel and Capital Funding Agreement and has the impact of negating certain provisions of that agreement. Accordingly, on February 3, 2015, PNM informed the participants in the Fuel and Capital Funding Agreement that the agreement would terminate by its terms no later than February 6, 2015. The continuing participants in SJGS have indicated that they remain committed to on-going ownership in SJGS and mediated discussions regarding remaining issues have continued. Other definitive agreements among the participants are being negotiated. PNM cannot predict if final agreements will be executed.

A number of regulatory approvals are required to implement the proposed ownership restructuring of SJGS. Final binding agreements relating to the ownership restructuring are subject to the approval of each participant’s board or other decision-making body and are subject to required regulatory approvals. PNM is unable to predict the outcome of the negotiations, whether definitive agreements will be reached among the owners, or whether required approvals will be obtained.

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. PNM is authorized and obligated under the SJPPA to take reasonable and prudent actions necessary for the successful and proper operation of SJGS pending resolution by the participants. In March 2014, June 2014, and January 2015, PNM requested that the owners of Unit 4 approve expenditures critical to being able to comply with the time frame in the RSIP with respect to Unit 4 project. The Unit 4 owners did not approve the requests. On March 10, 2014 and July 14, 2014, PNM issued “Prudent Utility Practice” notices that, under the SJPPA, PNM was continuing certain critical activities to keep the Unit 4 project on schedule.

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, including recently proposed rules regarding GHG under Section 111(d) of the CAA. 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 42%, SO₂ by 67%, particulate matter by 71%, and mercury by 95%.

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 2014, annual energy saved as a result of PNM’s portfolio of energy efficiency programs was approximately 70 GWh. This is equivalent to the annual consumption of approximately 9,700 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 2014 resulted in energy savings totaling an estimated 17 GWh. This is equivalent to the annual consumption of approximately 1,600 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. Beginning 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, including billing and payment options, 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.

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.

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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 gas-fired La Luz 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 avoided.

PNM expanded its integrated communication efforts with the launch of a new customer information website focused on PNM’s major regulatory filings, including the stipulated settlement agreement regarding BART at SJGS and PNM’s general rate case. The website, www.PowerforProgress.com, provides the details of current requests, as well as the background on PNM’s efforts to maintain reliability, keep prices affordable, and protect the environment. The website is designed to be a resource for the facts about PNM's operations and community support efforts, including plans for building a sustainable energy future for New Mexico.

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 2014, PNM hosted 31 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 3,153 families in 2014. In 2014, PNM committed funding of $0.4 million to the PNM Good Neighbor Fund.

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 2014, the foundation awarded $0.2 million to support 54 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 $1.6 million of support. In 2014, the PNM Resources Foundation launched a new grant program designed to help nonprofit organizations build more vibrant communities.  Power Up Grants in the aggregate amount of $0.5 million were awarded to 24 nonprofits in New Mexico and Texas for projects ranging from creating community gathering spaces to revitalizing neighborhood parks to building a youth sports field.

In Texas, community outreach is centered first on local relationships, specifically with community leaders, nonprofit organizations and key customers in areas served by TNMP. Community liaisons serve in each of TNMP's three geographic business areas, reaching out and ensuring productive lines of communication between TNMP and its customer base.

TNMP maintains long-standing relationships with several key nonprofit organizations, including agencies that support children and families in crisis, food banks, environmental organizations, and educational nonprofits, through employee volunteerism and corporate support. TNMP also actively participates in safety fairs and demonstrations in addition to supporting local chambers of commerce in efforts to build their local economies.

TNMP's energy efficiency program provides unique offers to multiple customer groups, including residential, commercial, government, education, and nonprofit customers. These programs not only enable peak load and consumption reductions, particularly important when extreme weather affects Texas' electric system, but they also demonstrate TNMP's commitment to more than just delivering electricity by partnering with customers to optimize their energy usage.

Economic Factors

In 2014 and 2013, PNM experienced decreases in weather-normalized retail load of 1.7% and 1.8%. New Mexico’s economy still lags the nation in post-recession recovery. TNMP experienced increases in weather-normalized retail load of 3.2% in 2014 and 2.6% 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 the latter part of 2014. Employment growth is a stronger predictor of load. Texas’ employment growth rates are well above the national rate, while New Mexico’s employment showed modest growth in 2014 after several years of being relatively flat.

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Results of Operations

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

	Year Ended December 31,						Change
	2014		2013		2012		2014/2013			2013/2012
	(In millions, except per share amounts)
Net earnings	$	116.3	$	100.5	$	105.5	$	15.8		$	(5.0	)
Average diluted common and common equivalent shares	80.3		80.4		80.4		(0.1		)	—
Net earnings per diluted share	$	1.45	$	1.25	$	1.31	$	0.20		$	(0.06	)

The components of the changes in earnings from continuing operations attributable to PNMR by segment are:

	Change
	2014/2013			2013/2012
	(In millions)
PNM	$	(0.8	)	$	(3.4	)
TNMP	8.7			2.4
Corporate and Other	7.8			(4.0		)
Net change	$	15.8		$	(5.0	)

PNMR’s operational results were affected by the following:

• Rate increases for PNM and TNMP; additional information about these rate increases is provided in Note 17

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

• Milder weather

• Higher prices for sales of power from PVNGS Unit 3

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

• Increased income tax expense due to impairments of state tax credits and state net operating loss carryforwards, as well as a tax rate change in New Mexico Note 11

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

Liquidity and Capital Resources

PNMR has a $300.0 million revolving credit facility and PNM has a $400.0 million revolving credit facility, both of which expire in October 2019 and can be extended for one year upon approval by the lenders. Both facilities provide capacities for short-term borrowing and letters of credit. 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 $768.2 million at February 20, 2015. 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 $2,528.5 million for 2015-2019. 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 16. 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, environmental upgrades at Four Corners, the purchase of the leased portion of the EIP, and the purchase of the assets underlying three of the PVNGS Unit 2 leases at the expiration of those leases. 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 2015-2019 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.

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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 2 for more information on PNMR’s operating segments.

The following discussion and analysis should be read in conjunction with the 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 in Part I, Item 1 and to Part II, Item 7A. Risk Factors.

PNM

The table below summarizes operating results for PNM:

	Year Ended December 31,									Change
	2014			2013			2012			2014/2013			2013/2012
	(In millions)
Electric operating revenues	$	1,147.9		$	1,116.3		$	1,092.3		$	31.6		$	24.0
Cost of energy	403.6			374.7			353.6			28.9			21.1
Margin	744.3			741.6			738.6			2.7			3.0
Operating expenses	422.1			428.6			435.4			(6.5		)	(6.8		)
Depreciation and amortization	109.5			103.8			97.3			5.7			6.5
Operating income	212.7			209.2			205.9			3.5			3.3
Other income (deductions)	20.8			21.5			26.5			(0.7		)	(5.0		)
Interest charges	(79.4		)	(79.2		)	(76.1		)	(0.2		)	(3.1		)
Segment earnings before income taxes	154.1			151.5			156.3			2.6			(4.8		)
Income (taxes)	(52.6		)	(48.8		)	(50.7		)	(3.8		)	1.9
Valencia non-controlling interest	(14.1		)	(14.5		)	(14.1		)	0.4			(0.4		)
Preferred stock dividend requirements	(0.5		)	(0.5		)	(0.5		)	—			—
Segment earnings	$	86.8		$	87.6		$	91.0		$	(0.8	)	$	(3.4	)

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

	2014/2013 Change									2013/2012 Change
	Total Revenues			Cost of Energy			Margin			Total Revenues			Cost of Energy			Margin
	(In millions)
Customer usage/load	$	(10.9	)	$	—		$	(10.9	)	$	(8.6	)	$	—		$	(8.6	)
Weather	(11.0		)	—			(11.0		)	(3.3		)	—			(3.3		)
Transmission	2.0			0.9			1.1			(1.6		)	1.0			(2.6		)
FPPAC	23.0			23.0			—			6.8			6.8			—
Economy energy service	6.2			6.0			0.2			7.6			7.3			0.3
Wholesale contracts	(1.2		)	(1.6		)	0.4			2.9			—			2.9
Rio Bravo purchase	—			(3.3		)	3.3			—			—			—
Unregulated margins	5.3			(1.8		)	7.1			2.8			(2.7		)	5.5
Energy efficiency rider	3.8			—			3.8			(2.1		)	—			(2.1		)
Renewable energy rider	10.2			3.7			6.5			14.7			6.3			8.4
Net unrealized economic hedges	5.7			1.1			4.6			(0.6		)	(0.9		)	0.3
Other	(1.5		)	0.9			(2.4		)	5.4			3.3			2.2
Net change	$	31.6		$	28.9		$	2.7		$	24.0		$	21.1		$	3.0

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

	Year Ended December 31,						Change
	2014		2013		2012		2014/2013			2013/2012
	(In millions, except customers)
Residential	$	411.4	$	411.6	$	409.0	$	(0.2	)	$	2.6
Commercial	428.1		415.6		413.3		12.5			2.3
Industrial	73.0		74.6		78.6		(1.6		)	(4.0		)
Public authority	25.3		25.7		25.5		(0.4		)	0.2
Economy energy service	39.1		32.9		25.4		6.2			7.5
Transmission	38.3		38.2		39.4		0.1			(1.2		)
Firm-requirements wholesale	38.3		42.4		39.4		(4.1		)	3.0
Other sales for resale	82.5		67.5		47.4		15.0			20.1
Mark-to-market activity	6.0		0.3		0.9		5.7			(0.6		)
Other	5.9		7.5		13.4		(1.6		)	(5.9		)
	$	1,147.9	$	1,116.3	$	1,092.3	$	31.6		$	24.0
Average retail customers (thousands)	511.2		508.2		505.6		3.0			2.6

The following table shows PNM GWh sales by customer class:

	Year Ended December 31,			Change
	2014	2013	2012	2014/2013		2013/2012
	(Gigawatt hours)
Residential	3,169.1	3,304.3	3,323.5	(135.2	)	(19.2	)
Commercial	3,874.3	3,954.8	4,022.2	(80.5	)	(67.4	)
Industrial	984.1	1,041.2	1,136.0	(57.1	)	(94.8	)
Public authority	251.2	266.4	279.2	(15.2	)	(12.8	)
Economy energy service	758.6	719.3	635.3	39.3		84.0
Firm-requirements wholesale	527.6	654.1	652.0	(126.5	)	2.1
Other sales for resale	2,271.5	2,061.9	1,652.2	209.6		409.7
	11,836.4	12,002.0	11,700.4	(165.6	)	301.6

In 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. PNM's weather normalized retail KWh sales were lower in 2014 by 1.7%, which decreased revenues and margins $10.9 million compared to 2013. Milder weather in New Mexico decreased revenues and margin $11.0 million in 2014 as cooling degree days were 7.4% lower and heating degree days were 12.7% lower in 2014 compared to 2013. In spite of the economic pressures, PNM experienced growth in average retail customers of 0.6% in 2014 compared to 2013. For 2013, PNM's weather normalized and leap-year adjusted retail KWh sales were lower in 2013 by 1.8%, which decreased margin $8.6 million compared to 2012 primarily due to the sluggish economy. PNM experienced growth in average retail customers of 0.5% in 2013 compared to 2012. Weather negatively impacted revenues and margin by $3.3 million in 2013 as cooling degree days were 10.7% lower in 2013 compared to 2012.

Transmission rate increases in August 2013 and May 2014 increased revenues and margin $1.3 million in 2014 compared to 2013. See Note 17. In 2013, lower transmission revenues as a result of expiration of contracts combined with higher third-party transmission expenses incurred to deliver power to retail customers reduced margins by $2.6 million.

As discussed in Note 17, the NMPRC approved the continuation of PNM’s FPPAC and authorized PNM to recover the remaining under-collected balance in its FPPAC balancing account over 18 months effective July 1, 2014. As a result PNM’s revenues increased in 2014 compared to 2013. These revenues were offset in cost of energy with no impact on margin.

PNM provides “economy energy services” to a major customer. Under this contract, PNM purchases energy on the customer’s behalf and delivers the energy to the customer’s location through PNM’s transmission system. PNM charges the

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customer for the cost of the energy as a direct pass through to the customer with no impact to PNM’s margin. Although KWh sales to this customer increased in both 2014 and 2013 compared to the previous year, there is only a minor impact in margin resulting from providing ancillary services.

Unregulated revenues and margins are primarily associated with PVNGS Unit 3. In 2014, higher market prices combined with higher available generation increased revenues by $5.3 million. In addition, gas imbalance settlements lowered cost of energy $2.1 million in 2014 compared to 2013. In 2013, higher market power prices on sales offset by lower available generation increased revenue and margin $2.8 million. In addition, PNM incurred cost of energy for gas imbalance settlements of $2.0 million in 2012 that did not recur in 2013.

PNM’s contract with Gallup, its second largest wholesale generation customer, expired on June 29, 2014.  In 2014, decreases in revenues for the Gallup contract of $5.6 million were partially offset by increases in off-system sales of $3.3 million for power that would have otherwise been used to serve Gallup and lower fuel expense of $1.0 million. In addition, in May 2014, PNM entered into a new wholesale contract with the Jicarilla Apache Nation, which increased revenues and margin $1.0 million. PNM’s recently filed general rate case includes a reallocation of costs among regulatory jurisdictions reflecting the termination of the contract to serve Gallup. See Note 17.  PNM implemented new rates for NEC, its largest wholesale firm-requirements customer, in April 2012 and for Gallup in July 2013. These increases improved revenues and margins $2.9 million in 2013.

PNM closed on the acquisition of Rio Bravo, formerly known as Delta, on July 17, 2014. Prior to acquiring Rio Bravo, PNM had a 20 year PPA covering all of the output of the facility, which PNM accounted for as an operating lease and recorded fixed and variable costs in cost of energy. As a result of the Rio Bravo acquisition, cost of energy decreased and margin increased $3.3 million for 2014 compared to 2013. The increase in margin is partially offset by increases in operating and depreciation expenses.

PNM offers several energy efficiency programs and initiatives to its retail customers regulated by the NMPRC. In addition, PNM is allowed to earn incentives on these programs based on authorized calculations. See Note 17. PNM recovers the energy efficiency program costs and incentives via a rate rider. Changes in energy efficiency revenues are offset by changes in operating expenses. In 2014, revenues and margins from the energy efficiency rider were higher by $3.8 million compared to 2013, due to an increase in the recovery rate for program costs and higher authorized incentives. In 2013, revenues and margins from the energy efficiency rider were lower by $2.1 million compared to 2012 due to lower KWh sales and a decrease in the recovery rate.

In August 2012, PNM implemented its renewable energy rider, which recovers renewable energy procurement costs to meet the RPS, including PNM-owned solar PV facilities. In January 2014, PNM increased the rate charged under the rider to include additional PNM-owned solar PV facilities completed in 2013. See Note 17. For 2014, this rider increased revenues by $10.2 million compared to 2013. These revenues include a return on investment increase of $1.9 million for 2014 compared to 2013. Cost of energy, reflecting purchase of RECs and purchase of geothermal power, increased $3.7 million for 2014 compared to 2013. Revenues under this rider increased by $14.7 million for 2013 compared to 2012. Cost of energy, reflecting the purchase cost of RECs, increased by an additional $6.3 million in 2013. Revenue increased due to the earned return component on investment of $1.8 million in 2013 compared to $1.2 million for 2012. The remaining revenues from this rider recover renewable energy operating, depreciation, and interest expenses.

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 gains of $6.5 million in 2014 compared to unrealized gains of $1.9 million for 2013 increased margin by $4.6 million, primarily due to PVNGS Unit 3 hedge gains of $5.7 million offset by losses on purchase power contracts of $1.1 million. Unrealized gains of $1.9 million in 2013 compared to unrealized gains of $1.6 million for 2012 increased margin by $0.3 million, primarily due to gains on purchase power contracts of $0.8 million and gains on retail hedges of $0.1 million offset by PVNGS Unit 3 hedge losses of $0.6 million.

Changes in revenue, cost of energy, and margin shown as “other” in the table above include the following items. In 2014, PNM recorded a $1.7 million increase in cost of energy and decrease in margin related to the resolution of issues covered by the arbitration with SJCC discussed in Note 16. As part of the approval of the continuation of PNM’s FPPAC, PNM retains 10% of the revenue from off-system sales that would otherwise be passed through the FPPAC, effective as of July 1, 2013. PNM recorded revenue of $1.7 million for its 10% share of off-system sales from the effective date through December 31, 2014. Lower cost of nuclear fuel handling due to discontinuance of the DOE one-mill fees decreased cost of energy and increased margins by $1.0 million in 2014 compared to 2013. Other also includes the impacts of off-system purchases and sales that are not passed through PNM’s FPPAC. Other sales for resale revenues and KWh volumes increased in 2013 compared to 2012, primarily due to reduced off-system sales at SJGS in 2012 resulting from the fire incident at the mine providing coal to SJGS. See Note 16 for more discussion on the SJGS mine fire incident. Lower cost of energy associated with coal mine decommissioning of $1.9 million increased margins in 2013 compared to 2012.

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In 2014, operating expenses decreased $6.5 million compared to 2013. Increases in plant maintenance costs at Four Corners, Palo Verde, and PNM’s natural gas plants of $2.4 million, $1.5 million, and $2.8 million were offset by lower maintenance costs at SJGS of $0.6 million. Higher energy efficiency rider program costs and higher renewable rider costs of $3.2 million and $0.4 million, which are offset in revenues, increased operating expenses. Higher property taxes of $2.4 million due to increased plant in service and higher assessed values, as well as higher bad debt expense of $0.4 million further increased operating expenses in 2014 compared to 2013. In 2014, PNM undertook process improvement initiatives designed to decrease future operating expenses. In connection with those initiatives, PNM incurred $1.9 million of costs, primarily related to severances, in 2014. These increases in costs were offset by lower labor and employee benefit costs of $2.4 million and $0.6 million in 2014 compared to 2013. Lower property and casualty claims reduced operating expenses by $1.0 million for 2014 compared to 2013. Capitalization of administrative and general expenses increased by $2.7 million due to higher capital spending also reduced operating expenses in 2014 compared to 2013, as did the $3.3 million allocation to contributions to the PNM Resources Foundation and additional financial support to the PNM Good Neighbor Fund in 2013, which did not occur in 2014. PNM concluded that certain costs that were being deferred as regulatory assets were no longer probable of recovery through the ratemaking process and recorded regulatory disallowances of $1.1 million in 2014 and $12.2 million in 2013, resulting in a decrease in operating expenses of $11.1 million in 2014. The 2013 disallowance includes $10.5 million of the under-collected balance of the FPPAC pursuant to a settlement in the FPPAC continuation matter discussed in Note 17.

In 2013, operating expenses decreased $6.8 million compared to 2012 due to lower maintenance expenses related to planned outages at SJGS of $8.8 million and unplanned outages at SJGS, PVNGS, and PNM’s natural gas plants of $0.9 million, $0.6 million, and $2.1 million, partially offset by increased maintenance expense for unplanned outages at Four Corners of $2.3 million. Lower healthcare claims and lower pension and retiree medical expenses reduced operating expense by $2.3 million in 2013. In addition, capitalized administrative and general expenses increased $3.0 million in 2013 due to increased capital spending, resulting in lower operating expenses compared to 2012. Also, lower energy efficiency expenses of $2.6 million, which are offset in revenues, reduced operating expenses. The allocation of corporate expenses in 2012 included $2.3 million related to business restructuring, which did not recur in 2013. Improved collection experience in 2013 decreased bad debt expense by $0.5 million further decreasing operating expenses. Higher incentive compensation expenses of $2.8 million increased operating expense in 2013. Property taxes increased $1.8 million due to increased plant in service and higher assessed values and a $0.7 million increase in regulatory, payroll, and gross receipts taxes increased operating expenses in 2013 compared to 2012. Donation allocations and regulatory disallowances in 2013, discussed above, increased operating expense in 2013. In addition, PNM recorded a lease abandonment loss of $6.2 million in operating expenses in 2012, which did not recur in 2013.

Depreciation and amortization expense increased in 2014 and 2013 due to additions to utility plant in service, including PNM-owned solar PV facilities and the Rio Bravo purchase. Depreciation on the PNM-owned solar PV facilities is recovered through the renewable energy rate rider as discussed above.

For 2014, other income (deductions) decreased $0.7 million compared to 2013, primarily due to lower interest income on the PVNGS lessor notes of $1.8 million due to lower outstanding balances. In addition, gains of $0.7 million on the disposition of property in 2013 decreased other income (deductions) for 2014. These decreases were offset by income from the pre-treatment of coal of $0.5 million in 2014 and PNM’s commitments in 2013 of $1.0 million to support employment and other economic activities in the “four corners” area, including the Navajo nation. Other income (deductions) also reflects the performance of the NDT and the trust for coal mine reclamation, including investment income, gains or losses on sales of investments, management expenses, and taxes paid by the trusts. Pre-tax gains on available-for-sale securities decreased $0.1 million in 2014 compared to 2013. For 2013, other income (deductions) was $5.0 million lower than 2012, primarily related to $2.4 million lower gains on available-for-sale securities and $2.3 million lower interest income on the PVNGS lessor notes. PNM commitments of $1.0 million to support the "four corners" area further decreased earnings. These decreases were partially offset by higher equity AFUDC of $0.4 million.

Interest expense increased $0.2 million and $3.1 million in 2014 and 2013 primarily due to the regulatory deferral in2012 of interest costs associated with the construction of PNM-owned solar PV facilities, which are now being amortized as interest income and recovered through the renewable energy rate rider.

As discussed in Note 11, the Company settled an IRS examination in 2014, which resulted in PNM recording an additional income tax expense of $1.1 million. An income tax benefit of $1.3 million reflected in the Corporate and Other segment offsets this amount. In addition, income tax expense for PNM was impacted by an impairment of New Mexico net operating loss carryforwards resulting in additional income tax expense of $2.1 million in 2014.

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TNMP

The table below summarizes the operating results for TNMP:

	Year Ended December 31,									Change
	2014			2013			2012			2014/2013			2013/2012
	(In millions)
Electric operating revenues	$	287.9		$	271.6		$	250.1		$	16.3		$	21.5
Cost of energy	67.9			57.6			46.2			10.3			11.4
Margin	220.0			214.0			203.9			6.0			10.1
Operating expenses	84.4			91.6			87.1			(7.2		)	4.5
Depreciation and amortization	50.1			50.2			49.3			(0.1		)	0.9
Operating income	85.6			72.2			67.5			13.4			4.7
Other income (deductions)	2.1			1.9			2.7			0.2			(0.8		)
Interest charges	(27.4		)	(27.4		)	(28.2		)	—			0.8
Segment earnings before income taxes	60.3			46.7			42.1			13.6			4.6
Income (taxes)	(22.5		)	(17.6		)	(15.4		)	(4.9		)	(2.2		)
Segment earnings	$	37.8		$	29.1		$	26.7		$	8.7		$	2.4

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

	2014/2013 Change								2013/2012 Change
	Total Revenues			Cost of Energy		Margin			Total Revenues			Cost of Energy		Margin
	(In millions)
Rate increases	$	6.3		$	—	$	6.3		$	4.8		$	—	$	4.8
Customer usage/load	0.9			—		0.9			2.0			—		2.0
Customer growth	1.7			—		1.7			1.5			—		1.5
Demand based customers	(0.4		)	—		(0.4		)	3.6			—		3.6
Weather	(2.0		)	—		(2.0		)	(0.7		)	—		(0.7		)
Recovery of third-party transmission costs	10.3			10.3		—			11.8			11.4		0.4
AMS surcharge	4.0			—		4.0			2.7			—		2.7
CTC surcharge	0.3			—		0.3			(3.4		)	—		(3.4		)
Hurricane Ike surcharge	(4.8		)	—		(4.8		)	(0.6		)	—		(0.6		)
Energy efficiency incentive	0.8			—		0.8			0.5			—		0.5
1999 rate settlement	—			—		—			(1.6		)	—		(1.6		)
Other	(0.8		)	—		(0.8		)	0.9			—		0.9
Net change	$	16.3		$	10.3	$	6.0		$	21.5		$	11.4	$	10.1

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

	Year Ended December 31,						Change
	2014		2013		2012		2014/2013		2013/2012
	(In millions, except customers)
Residential	$	114.8	$	111.3	$	103.3	$	3.5	$	8.0
Commercial	99.7		95.1		88.3		4.6		6.8
Industrial	15.0		13.1		13.4		1.9		(0.3		)
Other	58.4		52.1		45.1		6.3		7.0
	$	287.9	$	271.6	$	250.1	$	16.3	$	21.5
Average consumers (thousands) (1)	238.2		235.1		233.0		3.1		2.1

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

The following table shows TNMP GWh sales by retail tariff consumers class:

	Year Ended December 31,			Change
	2014	2013	2012	2014/2013		2013/2012
	(Gigawatt hours)
Residential	2,802.8	2,796.7	2,714.5	6.1		82.2
Commercial	2,564.8	2,451.3	2,353.1	113.5		98.2
Industrial	2,727.1	2,598.4	2,727.1	128.7		(128.7	)
Other	102.1	104.5	103.9	(2.4	)	0.6
	8,196.7	7,950.9	7,898.6	245.9		52.3

Implementation of rate increases in March 2013, September 2013, March 2014, and September 2014 increased revenues and margins by $6.3 million in 2014 compared to 2013. See Note 17. Higher weather normalized load increased revenues and margin by $0.9 million in 2014 compared to 2013. TNMP's weather normalized retail KWh sales increased 3.2% for the year ended 2014 compared to 2013. Milder weather in 2014 compared to 2013, decreased revenues and margins by $2.0 million. Cooling degree days were 2.2% lower than 2013 and heating degree days were 2.0% higher than in 2013. Due to the climate in TNMP’s service territories, variances in cooling degree days have a much larger impact than variances in heating degree days. TNMP experienced average customer growth of 1.3% in 2014, increasing revenues and margins by $1.7 million. Rate increases implemented in September 2012, March 2013, and September 2013 increased revenues and margins by $4.8 million in 2013 compared to 2012. Higher weather normalized and leap-year adjusted usage per customer increased margin $2.0 million in 2013. TNMP's weather normalized and leap-year adjusted retail KWh sales increased 2.6% in 2013. Customer growth in TNMP’s service areas increased revenues and margin $1.5 million in 2013. Milder weather in 2013 compared to 2012, decreased revenues and margins by $0.7 million.

Differences between revenues and costs charged by third-party transmission providers are deferred and recovered through a transmission cost recovery factor. Higher transmission cost of energy resulting from rate increases from other transmission service providers within ERCOT increased cost of energy $10.3 million in 2014 and $11.4 million in 2013. These increases in cost of energy resulted in TNMP rate increases for the recovery of third party transmission costs increasing revenue $10.3 million in 2014 and $11.8 million in 2013.

On August 11, 2011, TNMP implemented a surcharge for its AMS deployment. The surcharge will recover TNMP’s investment in AMS over a 12 year period. The surcharge has a true-up mechanism, which allows TNMP to match revenues collected against the expenses incurred and allows for a return to be earned on its investments. AMS revenues increased by $4.0 million in 2014 and $2.7 million in 2013, which offset increases in operating expenses and depreciation.

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Increased revenues and margins from demand based customers of $3.6 million in 2013 compared to 2012 primarily resulting from TNMP, under a PUCT approved tariff, lowering the power factor billing threshold from 700 KW to 300 KW. Such revenues and margins decreased slightly in 2014. In 2012, TNMP received a $1.6 million settlement related to ERCOT transmission rates charged from the fourth quarter of 1999, which did not recur in 2014 or 2013.

TNMP earned energy efficiency incentive bonuses for having achieved demand savings for the 2013 and 2012 program years that exceeded its goals. These incentives were approved by the PUCT on September 11, 2014 for the 2013 program year and November 4, 2013 for the 2012 program year, which increased revenues and margin by $0.8 million in 2014 and $0.5 million in 2013.

The CTC surcharge increased revenues and margin by $0.3 million in 2014 compared to 2013, but decreased $3.4 million in 2013 compared to 2012 due to a rate rider decrease implemented in January 2013. The Hurricane Ike surcharge decreased revenues and margin by $4.8 million in 2014 and $0.6 in 2013. The Hurricane Ike surcharge was terminated in November of 2013 due to full recovery of costs associated with this item. Other changes in revenue include recovery of current energy efficiency program costs collected through the energy efficiency cost recovery factor surcharge and rate case expenses collected through the rate case expense surcharge. Changes in revenues and margins from these surcharges are offset by changes in operating expenses and depreciation and amortization.

Operating expenses decreased $7.2 million in 2014 compared to 2013. Lower employee healthcare claims of $2.1 million decreased operating expense in 2014. Higher capitalization of administrative and general expenses related to higher levels of construction expenditures decreased operating expenses by $2.9 million further decrease operating expenses in 2014. Lower energy efficiency program expenses of $0.3 million and lower rate case expense amortization of $0.7 million decreased operating expense in 2014, which amounts are offset by decreases in revenue under TNMP’s energy efficiency and rate case expense surcharges. Other decreases to operating expenses include both a $0.5 million write-off of costs incurred in exploring the possibility of securitizing the remaining CTC costs and the allocation of the contributions to the PNM Resources Foundation of $0.7 million in 2013, which did not recur in 2014.

Operating expenses increased $4.5 million in 2013 compared to 2012. Higher energy efficiency program costs of $1.5 million increased operating expenses, which are offset by increases in revenue under TNMP’s energy efficiency cost recovery factor. Increased property and sales taxes of $1.1 million, primarily due to increased utility plant in service and higher assessed values, higher expenses for incentive compensation of $0.9 million, higher employee healthcare claims of $0.8 million and higher pension and retiree medical expense of $0.8 million increased operating expenses in 2013 compared to 2012. These increases and the increases due CTC securitization and allocated contributions discussed above were offset by lower vegetation management expenses of $1.1 million in 2013 due to additional vegetation management expenditures in 2012 and the 2012 lease abandonment loss of $1.2 million, which did not recur in 2013.

Depreciation expense associated with AMS deployment, which is recovered through the AMS surcharge, increased $2.2 million in 2014. Increases in utility plant in service and amortization expense associated with the CTC regulatory asset increased depreciation and amortization $1.6 million and $0.7 million in 2014. These increases were offset by lower amortization of Hurricane Ike costs of $4.7 million compared to 2013. In 2013, depreciation and amortization expense increased due to higher utility plant in service and AMS deployment, which was partially offset by lower amortization of the CTC regulatory asset.

Other income (deductions) increased in 2014 primarily due to an increase in contributions in aid of construction. Other income (deductions) decreased in 2013 due to higher AFUDC on equity funds of $0.6 million in 2012 and a gain on the sale of property of $0.3 million in 2012, which did not recur in 2013.

Interest charges were flat in 2014 compared to 2013. The issuance of $80.0 million of long-term debt under the TNMP 2013 Bond Purchase Agreement on June 27, 2014 increased interest charges $2.0 million, which is offset by lower interest charges due to the maturity of $50.0 million of debt under the TNMP 2011 Term Loan Agreement and 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. Interest charges in 2013 decreased compared to 2012 primarily due to this First Mortgage Bond exchange.

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Corporate and Other

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

	Year Ended December 31,									Change
	2014			2013			2012			2014/2013			2013/2012
				(In millions)
Electric operating revenues	$	—		$	—		$	—		$	—		$	—
Cost of energy	—			—			—			—			—
Margin	—			—			—			—			—
Operating expenses	(14.5		)	(18.3		)	(17.9		)	3.8			(0.4		)
Depreciation and amortization	13.1			12.8			17.5			0.3			(4.7		)
Operating income	1.4			5.5			0.3			(4.1		)	5.2
Gain on sale of First Choice	—			—			1.0			—			(1.0		)
Other income (deductions)	(2.4		)	(13.7		)	(8.1		)	11.3			(5.6		)
Interest charges	(12.8		)	(14.9		)	(16.6		)	2.1			1.7
Segment earnings (loss) before income taxes	(13.8		)	(23.1		)	(23.4		)	9.3			0.3
Income (taxes) benefit	5.4			6.9			11.2			(1.5		)	(4.3		)
Segment earnings (loss)	$	(8.4	)	$	(16.2	)	$	(12.2	)	$	7.8		$	(4.0	)

Corporate and Other operating expenses shown above are net of amounts allocated to PNM and TNMP under shared services agreements. The amounts allocated include certain expenses shown as depreciation and amortization and other income (deductions) in the table above. The operating income (loss) of $5.5 million in 2013 reflects the allocation of $4.0 million of the Company’s contributions to the PNM Resources Foundation and financial support to the PNM Good Neighbor Fund, recorded in other income (deductions), which were allocated to PNM and TNMP reducing operating expenses. Such contributions did not occur in 2014 or 2012.

Depreciation expense decreased in 2013 from 2012 due to accelerated amortization of leasehold improvements for a portion of the Company’s corporate headquarters abandoned during 2012. PNM and TNMP deferred their allocations of the accelerated amortization of related leasehold improvements as regulatory assets to be recovered through rates. Substantially all depreciation and amortization expense is offset in operating expenses as a result of allocation of these costs to other business segments.

The year-over-year changes in other income (deductions) are primarily due to losses of $3.3 million recognized in 2013 on the repurchase of $23.8 million of PNMR’s 9.25% senior unsecured notes (Note 6), the $4.0 million in contributions discussed above, and a $3.6 million decrease in amortization related to corporate investments that became fully amortized in 2013.

Interest charges decreased year-over-year in 2014 and 2013 primarily due to the repurchase of 9.25% senior unsecured notes. In addition, interest charges decreased due to lower borrowings and lower interest rates on short-term borrowings.

In 2014 and 2013, income tax benefits were reduced by $1.9 million and $3.9 million due to impairments of net operating loss carryforwards and New Mexico wind energy production tax credit carryforwards. The impaired carryforwards are not expected to be utilized prior to their expiration due to the Company’s net operating loss position and the extension of fifty percent bonus depreciation. Additional income tax expense of $0.2 million and $1.2 million was recognized in 2014 and 2013 due to reductions in Corporate and Other’s deferred tax assets resulting from legislation, which reduced future New Mexico corporate income tax rates. The settlement of an IRS examination in 2014 resulted in an income tax benefit of $1.3 million in Corporate and Other. An additional income tax expense of $1.1 million reflected in the PNM segment offsets this amount. See Note 11.

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LIQUIDITY AND CAPITAL RESOURCES

Statements of Cash Flows

The information concerning PNMR’s cash flows is summarized as follows:

	Year Ended December 31,									Change
	2014			2013			2012			2014/2013			2013/2012
	(In millions)
Net cash flows from:
Operating activities	$	414.9		$	386.6		$	281.3		$	28.3		$	105.2
Investing activities	(485.3		)	(331.4		)	(285.9		)	(153.9		)	(45.6		)
Financing activities	96.2			(61.6		)	(1.6		)	157.8			(60.0		)
Net change in cash and cash equivalents	$	25.7		$	(6.5	)	$	(6.1	)	$	32.2		$	(0.3	)

The changes in PNMR’s cash flows from operating activities primarily relate to income tax refunds received of $2.6 million in 2014 compared to refunds received of $95.3 million in 2013 and income taxes paid of $5.3 million in 2012 and rate increases at TNMP and PNM. Contributions to the PNM and TNMP pension and other postretirement benefit plans of $5.4 million in 2014 compared to $66.5 million in 2013 and $88.5 million in 2012 also contributed to operating cash flow changes. In addition, changes in assets and liabilities resulting from normal operations impact operating cash flows. These increases were offset by refunds of $15.2 million made to customers related to the settlement of PNM’s transmission rate case in 2013, as well as governmental grants received by PNM of $21.6 million in 2012 and lower retail load at PNM in 2014 and 2013.

Cash flows from investing activities were driven primarily by increases in plant additions of $112.6 million in 2014 compared to 2013 and $39.1 million in 2013 compared to 2012. At PNM, total utility plant additions were $76.9 million higher in 2014 compared to 2013, including increases in generation additions of $40.0 million, transmission and distribution additions of $33.5 million and nuclear fuel purchases of $4.8 million offset by a decrease in renewable additions of $1.4 million. PNM utility plant additions were $43.1 million higher in 2013 compared to 2012, including $35.7 million related to solar projects and increases in transmission and distribution additions of $22.7 million, offset by lower generation additions of $9.5 million and lower nuclear fuel purchases of $5.8 million. TNMP utility plant additions increased by $38.1 million in 2014 compared to 2013, including increases in distribution additions of $18.7 million, transmission additions of $17.8 million, and AMS additions of $1.6 million. TNMP utility plant additions decreased $3.9 million in 2013 compared to 2012, including an increase in AMS additions of $2.5 million, offset by a decrease in other transmission and distribution additions of $6.4 million. Cash flows from investing activities were also affected by the $36.2 million acquisition of Rio Bravo in 2014 as discussed in Note 9 and proceeds from the sale of First Choice of $4.0 million in 2012.

The changes in PNMR’s cash flows from financing activities include reductions in net short-term borrowings of $34.1 million in 2014 compared to 2013 and $85.5 million in 2013 compared to 2012. Long-term borrowings in 2014 include the $175.0 million PNM 2014 Term Loan agreement and $100.0 million of the $125.0 million PNM Multi-draw Term Loan, which were used to repay amounts under the existing PNM 2013 Term Loan Agreement and other short-term borrowings. In addition, 2014 includes the issuance of $80.0 million in long-term debt at TNMP, which was used to repay amounts under the existing TNMP 2011 Term Loan Agreement and other short-term borrowings. Long-term borrowings in 2013 include the $75.0 million PNM 2013 Term Loan Agreement. In 2013, $13.0 million was paid in connection with TNMP’s debt exchange and $26.9 million was paid by PNMR to repurchase $23.8 million of its outstanding 9.25% Senior Unsecured Notes, Series A, due 2015. Borrowings in 2012 include the $100.0 million PNMR Term Loan Agreement, which was used to repay borrowings under the PNMR Revolving Credit Facility. PNM also refinanced $20.0 million of PCRBs in 2012.

Financing Activities

See Note 6 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

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• Conditions in the financial markets

• Credit ratings

The $100.0 million PNMR Term Loan Agreement, the $175.0 million PNM 2014 Term Loan Agreement, and the $125.0 million PNM Multi-draw Term Loan, as well as the credit facilities discussed under Liquidity below, each contain 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 leases as debt. At December 31, 2014, interest rates on outstanding borrowings were 1.02% for the PNMR Term Loan Agreement, 1.11% for the PNM 2014 Term Loan Agreement, and 0.75% for the PNM Multi-draw Term Loan.

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 for 2015-2019 are:    

	2015		2016-2019		Total
	(In millions)
Construction expenditures	$	569.2	$	1,638.1	$	2,207.3
Dividends on PNMR common stock	63.7		254.9		318.6
Dividends on PNM preferred stock	0.5		2.1		2.6
Total capital requirements	$	633.4	$	1,895.1	$	2,528.5

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 $70.7 million related to environmental upgrades at SJGS to address regional haze and $268.4 million related to the identified sources of replacement capacity under the revised plan for compliance described in Note 16. 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 $80.0 million, and the purchase of the leased portion of the EIP, and the purchase of the assets underlying three of the PVNGS Unit 2 leases at the expiration of those leases. Expenditures for the SJGS and Four Corners environmental upgrades are estimated to be $72.1 million in 2015. See Note 16 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 describes regulatory and contractual restrictions on the payment of dividends by PNM and TNMP.

During the year ended December 31, 2014, PNMR met its capital requirements and construction expenditures through cash generated from operations, as well as its liquidity arrangements and borrowings under term loans and the TNMP 2013 Bond Purchase 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. PNMR’s 9.25% senior unsecured notes mature on May 15, 2015; $39.3 million of PNM’s senior unsecured notes, pollution control revenue bonds, are subject to mandatory tender for remarketing on June 1, 2015; and the $175.0 million PNM 2014 Term Loan Agreement matures on September 4, 2015. Note 6 contains additional information about the maturities of long-term debt. Also, the $100.0 million PNMR Term Loan Agreement matures on December 21, 2015 and the $125.0 million PNM Multi-draw Term Loan matures on June 21, 2016. PNMR and PNM anticipate that funds to repay the long-term debt maturities and term loans will come from entering into new arrangements similar to the existing agreements, borrowing under their revolving credit facilities, issuance of new long-term debt, or a combination of these sources. The Company has from time to time refinanced or repurchased portions of its outstanding debt before scheduled maturity. Depending on market conditions, the Company may refinance other debt issuances or make additional debt repurchases in the future.

Liquidity

PNMR’s liquidity arrangements include the PNMR Revolving Credit Facility and the PNM Revolving Credit Facility that both currently expire in October 2019 and the TNMP Revolving Credit Facility that expires in September 2018. The PNMR

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Revolving Credit Facility and the PNM Revolving Credit Facility provide for an additional one-year extension option for each facility, subject to approval by a majority of the lenders. The PNMR Revolving 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 these facilities are consistent with those of other investment grade revolving credit facilities in the utility industry.

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 year ended December 31, 2014, zero to $84.0 million during the year ended December 31, 2013, and $14.0 million to $141.0 million during the year ended December 31, 2012. Such borrowings ranged from zero to $0.6 million during the three months ended December 31, 2014. Borrowings under the PNM Revolving Credit Facility ranged from zero to $82.0 million during the year ended December 31, 2014, zero to $130.8 million during the year ended December 31, 2013, and zero to $168.0 million during the year ended December 31, 2012. Such borrowings ranged from zero to $45.0 million during the three months ended December 31, 2014. Borrowings under the PNM New Mexico Credit Facility ranged from zero to $25.0 million during the year ended December 31, 2014 and zero to $15.0 million during the three months ended December 31, 2014. There were no such borrowings in 2013 and 2012. Borrowings under the TNMP Revolving Credit Facility ranged from zero to $30.0 million during the year ended December 31, 2014 and from zero to $40.0 million during the year ended December 31, 2013. There were no such borrowings in 2012. Such borrowings ranged from zero to $5.0 million during the three months ended December 31, 2014. At December 31, 2014, the interest rates on outstanding borrowings were 1.67% for the PNMR Revolving Credit Facility and 1.17% for the TNMP Revolving Credit Facility. The PNM Revolving Credit Facility and the PNM New Mexico Credit Facility had no borrowings outstanding at December 31, 2014.

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 could 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 2015-2019 period. This could include new debt issuances and/or new equity.

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 corporate credit ratings outlook to positive from stable for PNMR, PNM, and TNMP. Currently, all of the credit ratings issued by both Moody’s and S&P on the Company’s debt are investment grade. As of February 20, 2015, 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	*
* 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 as of February 20, 2015 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 February 20, 2015:
Revolving credit facility	$	0.8	$	10.0	$	20.0	$	30.8
PNM New Mexico Credit Facility	—		15.0		—		15.0
Letters of credit	7.7		3.2		0.1		11.0
Total short term-debt and letters of credit	8.5		28.2		20.1		56.8
Remaining availability as of February 20, 2015	$	291.5	$	421.8	$	54.9	$	768.2
Invested cash as of February 20, 2015	$	1.9	$	42.5	$	—	$	44.4

The above table excludes intercompany debt. 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. The availability amounts do not include remaining capacity of $25.0 million available under the PNM Multi-draw Term Loan at February 20, 2015.

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 $500.0 million of senior unsecured notes that expires in May 2017.

Off-Balance Sheet Arrangements

PNMR’s off-balance sheet arrangements include PNM’s operating leases for portions of PVNGS Units 1 and 2 and the EIP transmission line.

In 1985 and 1986, PNM consummated sale and leaseback transactions for its interest in PVNGS Units 1 and 2. The original purpose of the sale-leaseback financing was to lower revenue requirements and to levelize the ratemaking impact of PVNGS being placed in-service. The lease payments reflected lower capital costs as the equity investors were able to capitalize the investment with greater leverage than PNM and because the sale transferred tax benefits that PNM could not fully utilize. Under traditional ratemaking, the capital costs of ownership of a major rate base addition, such as a nuclear plant, are front-end loaded. The revenue requirements are high in the initial years and decline over the life of the plant as depreciation occurs. By contrast, the lease payments are level over the lease term. The leases, which were scheduled to expire in 2015 and 2016, contained options to renew the leases at a fixed price or to purchase the property for fair market value.

As discussed in Note 7, PNM and the lessors under each of the PVNGS Unit 1 leases entered into amendments to those leases that renew the leases from their original expiration on January 15, 2015 through January 15, 2023. In addition, PNM entered into an amendment with the lessor under one of the PVNGS Unit 2 leases that extended that lease from its original expiration on January 15, 2016 through January 15, 2024. PNM has entered into agreements with the lessors under the other three PVNGS Unit 2 leases under which PNM will exercise its option to purchase the assets underlying the leases at the agreed to fair market values aggregating $163.3 million at the expiration of the leases on January 15, 2016. The semiannual renewal payments aggregate $8.3 million under the PVNGS Unit 1 leases and are $0.8 million for the one renewed PVNGS Unit 2 lease. See Sources of Power in Part I, Item 1, Investments in Note 1, and Note 7 for additional information.

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The future lease payments shown below for the PVNGS leases have been reduced by amounts that will be returned to PNM through its ownership in related lessor notes and include the renewals described above.

	PVNGS Units 1&2
	(In thousands)
2015	$	25,319
2016	20,589
2017	18,139
2018	18,139
2019	18,139
Thereafter	65,124
Total	$	165,449

For reasons similar to the PVNGS sale and leaseback transactions, PNM built the EIP transmission line and sold it in sale and leaseback transactions in 1985. PNM currently owns 60% and operates the other 40% of the EIP line under the terms of a lease agreement. The lease expires on April 1, 2015 and contained fixed-rate and fair market value renewal options and a fair market value purchase option. PNM has agreed to exercise its option to purchase the leased assets at expiration of the lease at the agreed to fair market value of $7.7 million. See Note 7.

Commitments and Contractual Obligations

The following table sets forth PNMR’s long-term contractual obligations as of December 31, 2014. See Note 7 for further details about the Company’s significant leases:

	Payments Due
Contractual Obligations	2015		2016-2017		2018-2019		2020 and Thereafter		Total
	(In thousands)
Long-term debt (a)	$	333,066	$	157,000	$	622,327	$	842,743	$	1,955,136
Interest on long-term debt (b)	107,233		200,081		124,432		637,984		1,069,730
Operating leases (c)	36,350		54,077		50,397		134,068		274,892
Transmission reservation payments	14,422		23,922		21,073		31,935		91,352
Coal contracts (d)	89,740		172,087		55,456		392,171		709,454
Coal mine decommissioning (e)	2,627		2,685		1,039		144,408		150,759
Nuclear decommissioning funding requirements (f)	2,637		5,274		5,274		—		13,185
Outsourcing	5,325		6,861		1,380		—		13,566
Pension and retiree medical (g)	35,463		23,435		20,218		—		79,116
Construction expenditures (h)	569,203		957,910		680,177		—		2,207,290
Total (i)	$	1,196,066	$	1,603,332	$	1,581,773	$	2,183,309	$	6,564,480

(a) Represents total long-term debt, excluding unamortized discounts of $1.9 million and unamortized premiums of $21.9 million

(b) Represents interest payments during the period

(c) The operating lease amounts include payments under the PVNGS leases through the expiration of the leases, including renewal periods for leases for which PNM has agreed to renew; the amounts in the above table are net of amounts to be returned to PNM as payments on its investments in related PVNGS lessor notes; see Off-Balance Sheet Arrangements above, Investments in Note 1, Note 7, and Note 9

(d) Represents only certain minimum payments that may be required under the coal contracts if no deliveries are made

(e) Includes funding of the trust established for post-term reclamation related to the mines serving SJGS (Note 16)

(f) These obligations represent funding based on the current rate of return on investments

(g) The Company only forecasts funding for its pension and retiree medical plans for the next five years

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(h) Represents forecasted construction expenditures, including nuclear fuel, under which substantial commitments have been made (Note 14); the Company only forecasts capital expenditures for the next five years; the construction expenditures include 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; see Capital Requirements above and Note 7

(i) PNMR is unable to reasonably estimate the timing of liability for uncertain income tax positions (Note 11) in individual years due to uncertainties in the timing of the effective settlement of tax positions. Therefore, PNMR’s liability of $15.0 million is not reflected in this table. Amounts PNM is obligated to pay Valencia are not included above since Valencia is consolidated by PNM in accordance with GAAP. See Note 9. No amounts are included above for the New Mexico Wind, Lightning Dock Geothermal, and Red Mesa Wind PPAs since there are no minimum payments required under those agreements.

Contingent Provisions of Certain Obligations

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 most significant consequences resulting from these contingent requirements are detailed in the discussion below.

The PNMR Revolving Credit Facility, PNM Revolving Credit Facility, PNM New Mexico Credit Facility, and TNMP Revolving Credit Facility contain “ratings triggers,” for pricing purposes only. If PNMR, PNM, or TNMP is downgraded or upgraded by the ratings agencies, the result would be an increase or decrease in interest cost. In addition, these facilities, as well as the PNMR Term Loan Agreement, PNM 2014 Term Loan Agreement, and PNM Multi-draw Term Loan each contain a covenant requiring the maintenance of debt-to-capital ratios of not more than 65%. For PNMR and PNM, the present value of payments under the PVNGS leases are considered debt. If that ratio were to exceed 65%, the entity could be required to repay all borrowings under its facility, be prevented from borrowing on the unused capacity under the facility, and be required to provide collateral for all outstanding letters of credit issued under the facility.

If a contingent requirement were to be triggered under the PNM facilities resulting in an acceleration of the repayment of outstanding loans, a cross-default provision in the PVNGS leases could occur if the accelerated amount is not paid. If a cross-default provision is triggered, the PVNGS lessors have the ability to accelerate their rights under the leases, including acceleration of all future lease payments. The Company’s revolving credit facilities and term loan agreements also include cross-default provisions.

PNM’s standard purchase agreement for the procurement of gas for its fuel needs contains a contingent requirement that could require PNM to provide collateral for its gas purchase obligations if the seller were to reasonably believe that PNM was unable to fulfill its payment obligations under the agreement.

The master agreement for the sale of electricity in the WSPP contains a contingent requirement that could require PNM to provide collateral if the credit ratings on its debt falls below investment grade. The WSPP agreement also contains a contingent requirement, commonly called a material adverse change provision, which could require PNM to provide collateral if a material adverse change in its financial condition or operations were to occur. Additionally, PNM utilizes standard derivative contracts to financially hedge and trade energy. These agreements contain contingent requirements that require PNM to provide security if the credit rating on its debt falls below investment grade.

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.

	December 31,
PNMR	2014		2013
PNMR common equity	46.4	%	48.8	%
Preferred stock of subsidiary	0.3	%	0.3	%
Long-term debt	53.3	%	50.9	%
Total capitalization	100.0	%	100.0	%
PNM
PNM common equity	45.7	%	48.2	%
Preferred stock	0.4	%	0.4	%
Long-term debt	53.9	%	51.4	%
Total capitalization	100.0	%	100.0	%
TNMP
Common equity	58.9	%	59.9	%
Long-term debt	41.1	%	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 2014, GHG associated with PNM’s interests in its generating plants were approximately 6.8 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 17. 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. In 2014, PNM added an additional 23 MW of utility-scale solar generation. PNM’s 2015 renewable energy procurement includes the construction of an additional 40 MW of PNM-owned solar PV facilities by December 31, 2015. Since 2003, PNM has purchased the entire output of New Mexico Wind, which has an aggregate capacity of 204 MW, and began purchasing the full output of Red Mesa Wind, which has an aggregate capacity of 102 MW, 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 capacity 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 39 MW at the end of 2014 and is expected to grow to over 45 MW by the end of 2015. Once fully subscribed, the distributed solar programs will reduce PNM’s annual production from fossil-fueled electricity generation by about 120 GWh. PNM offers its customers a comprehensive portfolio of energy efficiency and load management programs, with a 2014 budget of $22.5 million and anticipated program costs of $25.8 million for the program year beginning in June 2015. PNM estimates these programs saved approximately 75 GWh of electricity in 2014. Over the next 20 years, PNM projects the expanded energy efficiency and load management programs will provide the equivalent of approximately 13,000 GWh of electricity, which will avoid at least 6.5 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.

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

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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, 2014, approximately 71.2% 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 16, 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% at SJGS. That agreement also contemplates that gas-fired generation would be built to partially replace the retired capacity. Although replacement power strategies include some gas-fired generation, the reduction in GHG from the retirement of the coal-fired generation would be far greater than the increase in GHG from replacement generation. In September 2013, the EIB approved a RSIP submitted by NMED that encompassed the February 15, 2013 agreement and the RSIP was submitted to EPA for approval on October 18, 2013. Final rules approving the RSIP and withdrawing the FIP were published in the Federal Register on October 9, 2014 and became effective on November 10, 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 any such costs through rates, the timing and outcome of proceedings for cost recovery are uncertain. In addition, to the extent that any additional costs are recovered through rates, customers may reduce their usage, relocate facilities to other areas with lower energy costs, or take other actions that ultimately 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 was to “tailor” the applicability of two programs, PSD and Title V operating permit programs, to avoid impacting millions of small GHG emitters. The rule focused on the largest sources of GHG, including fossil-fueled electric generating units. This program covered 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 would be subject to PSD permitting requirements, even if they did not significantly increase emissions of any other pollutant. As a result, PNM’s fossil-fueled generating plants were more likely to trigger PSD permitting requirements because of the magnitude of GHG. However as discussed below, a recent court case has now limited the extent of 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 would review 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 dealt with whether EPA’s determination that regulation of GHG from motor vehicles required EPA to regulate stationary sources under the PSD and

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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 June 23, 2014, the United States Supreme Court issued its opinion on the above case. The Supreme Court largely reversed the D.C. Circuit. First, the Supreme Court found the CAA does not compel or permit EPA to adopt an interpretation of the act that requires a source to obtain a PSD or Title V permit on the sole basis of its potential GHG. Second, EPA had argued that even if it was not required to regulate GHGs under the PSD and Title V programs, the Tailoring Rule was nonetheless justified on the grounds that it was a reasonable interpretation of the CAA. The Supreme Court rejected this argument. Third, the Supreme Court found EPA lacked authority to "tailor" the CAA's unambiguous numerical thresholds of 100 or 250 tons per year. Fourth, the Supreme Court found that it would be reasonable for EPA to interpret the CAA to limit the PSD program for GHGs to "anyway" sources – those sources that have to comply with the PSD program for other non-GHG pollutants. The Supreme Court said that EPA needed to establish a de minimis level below which BACT would not be required for "anyway" sources.

On March 27, 2012, EPA issued its proposed carbon pollution standards, under Section 111(b) of the CAA, for GHG from new 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.

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 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’s reproposed GHG NSPS for new sources applies only to new fossil-fired EGUs. The reproposed standards, based on the size of the unit, 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 coal-fired facilities would only be able to meet the standard by using partial carbon capture and sequestration technology. 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.

The Presidential Memorandum directed EPA to issue the proposed GHG NSPS for modified and existing EGUs by June 1, 2014 and to issue the final rule by June 1, 2015. On June 2, 2014, EPA released the proposed rule under Section 111(d) of the CAA to establish GHG performance standards for existing EGUs. The proposed existing source rule would require state-specific CO₂ emission reduction goals based on EPA’s finding of the best system of emissions reductions (“BSER”). States would be required to meet both an interim goal from 2020 to 2029 and a final goal beginning in 2030. The proposed BSER is based on four “building blocks”: 1) a 6% heat rate improvement to coal-fired generation units; 2) a shift in electrical generation from coal-fired and oil/gas-fired EGUs to natural gas combined cycle units (“NGCCs”) such that the NGCCs are at a 70% utilization rate; 3) substitution of fossil fuel generation with renewable resources and new nuclear facilities, and extension of life of about 6% of existing nuclear plants that may be retired; and 4) increases to demand-side energy efficiency programs. States would be required to develop SIPs to reach the CO₂ emission reduction goals. The SIPs would need to include enforceable CO₂ emission limits that apply to the affected EGUs within the state. EPA is proposing to allow flexibility in how each state achieves the goal including an option to use either a rate-based or mass-based standard and to develop multi-state compliance plans. State SIPs would be due thirteen months after the date that the final rule is published in the Federal Register with the possibility of a one year extension if a state needs additional time or a two year extension if states choose to enter a multi-state approach. Comments on the proposed

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rule were originally due on or before October 16, 2014, which was extended to December 1, 2014. PNM submitted comments by the deadline.

Also on June 2, 2014, EPA proposed carbon pollution standards for modified and reconstructed EGUs. Under the proposed rule there are two alternatives for EGUs: 1) a CO₂ emission limit based on the unit’s best historic annual CO₂ emissions plus an additional 2% reduction or 2) an emission limit dependent on when the unit is modified. Sources modified before becoming subject to a section 111(d) plan would be required to meet an emission limit determined by the unit’s best historical annual CO₂ emission rate plus an additional 2% emission reduction. Units modified after becoming subject to a section 111(d) plan would be required to meet a unit-specific emission limit determined by the section 111(b) implementing authority.

On October 28, 2014, EPA issued a supplemental rule proposing CO₂ emission rates for U.S. territories and areas of Indian country with existing fossil fuel-fired EGUs, as well as guidelines for plans to achieve those rates.  The supplemental proposal would apply to Four Corners, which is located on the Navajo Nation.  With respect to this plant, EPA applied the four building blocks described in its June 18, 2014 CAA Section 111(d) proposal to establish interim and final goals, expressed as CO₂ emission rates.  APS has indicated that if the rule is finalized as proposed, it is unlikely that additional emission reductions would be required as a result of the plant’s past and future actions to comply with the requirements for BART.

On January 7, 2015, EPA announced their intention to propose a federal plan to meet the requirements of the section 111(d) rule, to be released in the summer of 2015 and finalized in summer 2016.  EPA also announced changes to the schedule for issuing the final GHG rule regulations for new, modified/reconstructed, and existing EGUs in "Summer 2015."  As a result, deadlines for compliance in subsequent years for section 111(d) actions will shift from “June” to “Summer.”  EPA initially proposed to issue a final rule for new EGUs by January 8, 2015 and had previously planned to finalize its modified/reconstructed and existing source rules in June 2015. 

EPA regulation of GHG from large stationary sources will impact PNM’s fossil-fueled EGUs. Impacts could involve investments in additional renewables, 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 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. 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 NSPS requirements, are in draft form and existing power plants will be regulated by state plans that will not be finalized for several years. PNM estimates that implementation of the RSIP 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 the RSIP and the retirement of SJGS Units 2 and 3 by the end of 2017, should provide a significant step towards compliance with Section 111(d). PNM is currently reviewing the proposed Section 111(d) rule and is unable to predict the impact of this rule on its fossil fueled generation.

Federal Legislation

Prospects for enactment of legislation imposing a new or enhanced regulatory program to address climate change in Congress are unlikely in 2015.  Instead, EPA continues to be the primary venue for GHG regulation in the near future, especially for coal-fired EGUs. PNM has assessed, and continues to assess, the impacts of potential climate change legislation or regulation on its business.  This assessment is ongoing and future changes arising out of the legislative or regulatory process could impact the assessment significantly.  PNM’s assessment includes assumptions regarding the specific GHG limits, the timing of implementation of these limits, the possibility of a cap and trade or tax 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 16.  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.

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State and Regional Activity

Pursuant to New Mexico law, each utility must submit an IRP to the NMPRC every three years to evaluate renewable energy, energy efficiency, load management, distributed generation, and conventional supply-side resources on a consistent and comparable basis.  The IRP is required to take into consideration risk and uncertainty of fuel supply, price volatility, and costs of anticipated environmental regulations when evaluating resource options to meet supply needs of the utility’s customers.  The NMPRC requires that New Mexico utilities factor a standardized cost of carbon emissions into their IRPs using prices ranging between $8 and $40 per metric ton of CO₂ emitted and escalating these costs by 2.5% per year.  Under the NMPRC order, each utility must analyze these standardized prices as projected operating costs.  Reflecting the 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 1, 2014 showed that consideration of carbon emissions costs impacted the projected in-service dates of some of the identified resources.  

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. 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 28, 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 United Nations Framework Convention on Climate Change (“UNFCCC”) is an international environmental treaty that was produced at the United Nations Conference on Environment and Development (informally known as the Earth Summit). Since the UNFCCC entered into force in March 1994, the parties, including the United States, have been meeting annually in Conferences of the Parties (“COP”) to assess progress in dealing with climate change and, beginning in the mid-1990s, to negotiate the Kyoto Protocol to establish legally binding obligations for developed countries to reduce their GHG. Specifically, the objective is to “stabilize greenhouse gas concentrations in the atmosphere at a level that would prevent dangerous anthropogenic interference with the climate system.” The Company monitors the proceedings of the UNFCCC, including the annual COP meetings, to determine potential impacts to its business activities.  At the COP meeting in 2011, participating nations, including the United States, agreed that in 2015, they would sign an international treaty requiring all nations to begin reducing carbon emissions by 2020. Known as the Durban Platform for Enhanced Action, the new treaty would supplant the Kyoto Protocol, which was adopted in 1997, that targeted only industrialized nations for mandatory climate emission reductions. The Obama administration released its goals in November of 2014 and other nations are expected to release their proposed goals in the first half of 2015. The 2015 COP will be held in December. The objective of the conference is to achieve a legally binding agreement on climate from all nations. PNM will continue to monitor the United States participation in international accords. However, the Company believes that the Obama administration’s target for the electric utility industry will be based on EPA’s current proposals to regulate carbon and that implementation of the RSIP for BART at SJGS should provide a significant step towards compliance with the requirements.

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

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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. On June 19, 2014, FERC issued a NOPR to approve a new reliability standard. 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. MOD-001-2 will replace multiple existing reliability standards and will remove the risk of reduced TTC for PNM and other western 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 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 their regional 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 their cost allocation and inter-regional coordination plan compliance filing between WestConnect and other regions.

On September 18, 2014, PNM along with the other WestConnect FERC jurisdictional entities received a FERC order on their respective September 20, 2013 compliance filings with respect to FERC Order 1000 concerning regional planning and cost allocation. The FERC order required the West Connect entities to make another compliance filing to change certain aspects of their respective Attachment K of their respective transmission tariffs and to hold a single year “abbreviated planning process for year 2015.” The order also required the WestConnect entities to file the WestConnect “Planning Participation Agreement.” Of significant concern to the FERC jurisdictional entities in this most recent order was FERC’s ruling that the non-jurisdictional entities would not be required to participate in cost allocation on regional projects, which the jurisdictional entities believed does not comport with FERC’s Order 1000 position on the “cost causation principle” and could create a “free rider-ship” issue for certain participants in the planning process.

The jurisdictional entities filed compliance filings regarding the September 18, 2014 FERC order on November 17, 2014, making several adjustments to the language in their respective Attachment K. The jurisdictional entities also filed, as a separate document an unsigned version of the proposed final version of the Planning Participation Agreement on November 17, 2014. Several entities have intervened and some have protested aspects of these filings.

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The jurisdictional entities jointly filed a request for re-hearing or clarification of the FERC order on October 20, 2014, specifically citing the cost allocation issue. Filings to preserve rights to appeal have been made at the United States Court of Appeals for the Fifth Circuit and at the Federal District Court level on behalf of the jurisdictional entities.

On December 18, 2014, FERC issued an order conditionally accepting the WestConnect jurisdictional entities May 10, 2013 compliance filings regarding transmission coordination and cost allocation planning process at the inter-regional transmission level. The order will require some minor changes to each of the WestConnect jurisdictional entities respective Attachment K language, to comply with requirements of the December 18, 2014 FERC order.

Financial Reform Legislation

The Dodd-Frank Wall Street Reform and Consumer Protection Act (“Dodd-Frank Reform Act”), enacted in July 2010, includes provisions that will require certain over-the-counter derivatives, or swaps, to be centrally cleared and executed through an exchange or other approved trading facility. It also includes provisions related to swap transaction reporting and record keeping and may impose margin requirements on swaps that are not centrally cleared. The 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 in compliance with the Dodd-Frank Reform Act and related rules within the time frames required by the CFTC. However, as a result of implementing and complying with the Dodd-Frank Reform Act and related rules, PNM’s swap activities could be subject to increased costs, including from higher margin requirements. At this time, PNM cannot predict the ultimate impact the Dodd-Frank Reform Act may have on PNM’s financial condition, results of operations, cash flows, or liquidity.

Other Matters

See Notes 16 and 17 for a discussion of commitments and contingencies and rate and regulatory matters. See Note 1 for a discussion of accounting pronouncements that have been issued, but are not yet effective and have not been adopted by the Company.

CRITICAL ACCOUNTING POLICIES AND ESTIMATES

The preparation of financial statements in accordance with GAAP requires management to apply accounting policies and to make estimates and judgments that best provide the framework to report the results of operations and financial position for PNMR, PNM, and TNMP. As a result, there exists the likelihood that materially different amounts would be reported under different conditions or using different assumptions. Management has identified the following accounting policies that it deems critical to the portrayal of the financial condition and results of operations and that involve significant subjectivity. The following discussion provides information on the processes utilized by management in making judgments and assumptions as they apply to its critical accounting policies.

Unbilled Revenues

The Company records unbilled revenues representing management’s assessment of the estimated amount of revenue earned from customers for services rendered between the meter-reading dates in a particular month and the end of that month. Management estimates unbilled revenues based on daily generation volumes, estimated customer usage by class, weather factors, line losses, and applicable customer rates reflecting historical trends and experience. The estimate requires the use of various judgments and assumptions; significant changes to these judgments and assumptions could have a material impact to the Company’s results of operations.

Regulatory Accounting

The Company is subject to the provisions of GAAP for rate-regulated enterprises and records assets and liabilities resulting from the effects of the ratemaking process, which would not be recorded under GAAP for non-regulated entities. Additional information concerning regulatory assets and liabilities is contained in Note 4.

The Company continually evaluates the probability that regulatory assets and liabilities will impact future rates and makes various assumptions in those analyses. The expectations of future rate impacts are generally based on orders issued by regulatory commissions or historical experience, as well as discussions with applicable regulatory authorities. If future recovery or refund ceases to be probable, the Company would be required to write-off the portion that is not recoverable or refundable in current period earnings.

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The Company has made adjustments to regulatory assets and liabilities that affected its results of operations in the past due to changes in various factors and conditions impacting future cost recovery. Based on its current evaluation, the Company believes that future recovery of its regulatory assets are probable.

Impairments

Tangible long-lived assets are evaluated for impairment when events and circumstances indicate that the assets might be impaired in accordance with GAAP. These potential impairment indicators include management’s assessment of fluctuating market conditions as a result of planned and scheduled customer purchase commitments; future market penetration; changing environmental requirements; fluctuating market prices resulting from factors including changing fuel costs and other economic conditions; weather patterns; and other market trends. The amount of impairment recognized, if any, is the difference between the fair value of the asset and the carrying value of the asset and would reduce both the asset and current period earnings. Variations in the assessment of potential impairment or in the assumptions used to calculate an impairment could result in different outcomes, which could lead to significant effects on the Consolidated Financial Statements.

Goodwill is evaluated for impairment at least annually, or more frequently if events and circumstances indicate that the goodwill might be impaired. GAAP allows impairment testing to be performed based on either a qualitative analysis or quantitative analysis. Note 21 contains information on the impairment testing performed by the Company on goodwill. For 2014, the Company utilized a qualitative analysis for the TNMP reporting unit and a quantitative analysis for the PNM reporting unit. No impairments were indicated in the Company’s annual goodwill testing, which was performed as of April 1, 2014. Since the annual evaluation, there have been no indications that the fair values of the reporting units with recorded goodwill have decreased below the carrying values. The annual testing was based on certain critical estimates and assumptions. Changes in the estimates or the use of different assumptions could affect the determination of fair value and the conclusion of impairment for each reporting unit.

Application of the qualitative goodwill impairment test requires evaluating various events and circumstances to determine whether it is not more likely than not that the fair value of a reporting unit is less than its carrying amount. As a part of the Company’s goodwill qualitative testing process for a reporting unit, various factors that are specific to the reporting unit as well as industry and macroeconomic factors are evaluated in order to determine whether these factors are reasonably likely to have a material impact on the fair value of the reporting unit. Examples of the factors that were considered in the qualitative testing of the goodwill include the results of the most recent quantitative impairment test, current and long-term forecasted financial results, regulatory environment, credit rating, changes in the interest rate environment, and operating strategy for the reporting unit. Based on the qualitative analysis performed in 2014 for the TNMP reporting unit, the Company concluded that there were no changes that were reasonably likely to cause the fair value of the reporting unit to be less than the carrying value and determined that there was no impairment of goodwill. Although the Company believes all relevant factors were considered in the qualitative impairment analysis to reach the conclusion that goodwill is not impaired, significant changes in any one of the assumptions could produce a significantly different result potentially leading to the recording of an impairment that could have significant impacts on the results of operations and financial position of the Company.

Application of the quantitative impairment test requires judgment, including assignment of assets and liabilities to reporting units and the determination of the fair value of a reporting unit. A discounted cash flow methodology is primarily used by the Company to estimate the fair value of a reporting unit. This analysis requires significant judgments, including estimation of future cash flows, which is dependent on internal forecasts, estimation of long-term growth rates for the business and determination of appropriate WACC for each reporting unit.

In determining the fair value of a reporting unit under the quantitative approach, the WACC is a significant factor. The Company considers many factors in selecting a WACC, including the market view of risk for each individual reporting unit, the appropriate capital structure based on that used in the ratemaking process, and the borrowing rate appropriate for a reporting unit. The Company considers available market-based information and may consult with third parties to help determine the WACC. The selection of a WACC is subjective and modifications to this rate could significantly increase or decrease the fair value of a reporting unit.

The other primary factor impacting the determination of the fair value of a reporting unit is the estimation of future cash flows. The Company considers budgets, long-term forecasts, historical trends, and expected growth rates in order to estimate future cash flows. Any forecast contains a degree of uncertainty and modifications to these cash flows could significantly increase or decrease the fair value of a reporting unit. For the PNM and TNMP reporting units, which are subject to rate-regulation, a fair recovery of and return on costs prudently incurred to serve customers is assumed. Should the regulators not allow recovery of certain costs or not allow these reporting units to earn a fair rate of return on invested capital, the fair value of the reporting units could decrease.

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The Company believes that the WACC and cash flow projections utilized in the 2014 quantitative testing appropriately reflected the fair value of the PNM reporting unit. Since any cash flow projection contains uncertainty, the WACC used by the Company was adjusted to reflect that uncertainty. The Company does not believe that there are indications of goodwill impairment in any of its reporting units, but this analysis is highly subjective. As of the impairment testing for April 1, 2014, the fair value of the PNM reporting unit, which had goodwill of $51.6 million, exceeded its carrying value by approximately 30%. An increase of 0.5% in the expected return on equity capital utilized in calculating the WACC used to discount the forecasted cash flows, would have reduced the excess of PNM’s fair value over carrying value to approximately 23% at April 1, 2014. The April 1, 2012 quantitative evaluation of fair value of the TNMP reporting unit, which had goodwill of $226.7 million, exceeded its carrying value by approximately 26%. Due to the subjectivity and sensitivities of the assumptions and estimates underlying the impairment analysis, there can be no assurance that future analyses, which will be based on the appropriate assumptions and estimates at that time, will not result in impairments.

Decommissioning and Reclamation Costs

Accounting for decommissioning costs for nuclear and fossil-fuel generation involves significant estimates related to costs to be incurred many years in the future after plant closure. Decommissioning costs are based on site-specific estimates, which are updated periodically and involve numerous judgments and assumptions, including estimates of future decommissioning costs at current price levels, inflation rates, and discount rates. Changes in these estimates could significantly impact PNMR’s and PNM’s financial position, results of operations and cash flows. PNM owns and leases nuclear and fossil-fuel generation facilities. In accordance with GAAP, PNM is only required to recognize and measure decommissioning liabilities for tangible long-lived assets for which a legal obligation exists. Nuclear decommissioning costs are based on estimates of the costs for removing all radioactive and other structures at PVNGS. AROs, including nuclear decommissioning costs, are discussed in Note 15. Nuclear decommissioning costs represent approximately 84% of PNM’s ARO liability. A 10% increase in the estimates of future decommissioning costs at current price levels would have increased the ARO liability by $9.4 million at December 31, 2014. PVNGS Units 1 and 2 are included in PNM’s retail rates while PVNGS Unit 3 is excluded although PNM has requested Unit 3 be included. PNM collects a provision for ultimate decommissioning of PVNGS Units 1 and 2 and its fossil-fuel generation facilities in its rates and recognizes a corresponding expense and liability for these amounts. PNM believes that it will continue to be able to collect in rates for its legal asset retirement obligations for nuclear generation activities included in the ratemaking process.

In connection with both the SJGS coal agreement and the Four Corners fuel agreement, the owners are required to reimburse the mining companies for the cost of contemporaneous reclamation as well as the costs for final reclamation of the coal mines.  The reclamation costs are based on periodic site-specific studies that estimate the costs to be incurred in the future and are dependent upon numerous assumptions, including estimates of future reclamation costs at current price levels, inflation rates, and discount rates. A 10% increase in the estimates of future reclamation costs at current price levels would have increased the mine reclamation liability by $3.4 million at December 31, 2014. PNM considers the contemporaneous reclamation costs part of the cost of its delivered coal costs.  The NMPRC has capped the amount that can be collected from ratepayers for final reclamation of the surface mines. If future estimates increase the liability for surface mine reclamation, the excess would be expensed at that time. See Note 16 for discussion of the final reclamation costs.

Derivatives

The Company follows the provisions set forth in GAAP to account for derivatives. These provisions establish accounting and reporting standards requiring derivative instruments to be recorded in the balance sheet as either an asset or liability measured at their fair value. GAAP also requires that changes in the derivatives’ fair value be recognized currently in earnings unless specific hedge accounting or normal purchase and sale criteria are met. 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. Although the Company uses its best judgment in estimating the fair value of these instruments, there are inherent limitations in any estimate technique. Changes in the assumptions used in the fair value determinations could have significant impacts on the results of operations and financial position of the Company. Note 8 contains additional information on commodity derivatives, including the volumes covered by derivative contracts.

Pension and Other Postretirement Benefits

The Company maintains qualified defined benefit pension plans, postretirement benefit plans providing medical and dental benefits, and executive retirement programs. The net periodic benefit cost or income and the calculation of the projected benefit obligations are recognized in the Company’s financial statements and depend on expected investment performance, the level of contributions made to the plans, and employee demographics. They both require the use of a number of actuarial assumptions and estimates. The most critical of the actuarial assumptions are the expected long-term rate of return, the discount rate, and

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projected health care cost trend rates. The Company reviews and evaluates its actuarial assumptions annually and adjusts them as necessary. Changes in the pension and OPEB assets and liabilities associated with these factors are not immediately recognized as net periodic benefit cost or income in results of operations, but are recognized in future years, generally, over the remaining life of the plan. However, these factors could have a significant impact on the financial position of the company. Note 12 contains additional information about pension and OPEB obligations, including assumptions utilized in the calculations and impacts of changes in certain of those assumptions.

Accounting for Contingencies

The financial results of the Company may be affected by judgments and estimates related to loss contingencies. Contingencies related to litigation and claims, as well as environmental and regulatory matters, also require the use of significant judgment and estimation. The Company attempts to take into account all known factors regarding the future outcome of contingent events and records an accrual for any contingent events that are both probable and reasonably estimated based upon current available information. However the actual outcomes can vary from any amounts accrued which could have a material effect on the results of operations and financial position of the Company. See Note 16 and Note 17.

Income Taxes

The Company’s income tax expense and related balance sheet amounts involve significant judgment and use of estimates. Amounts of deferred income tax assets and liabilities, current and noncurrent accruals, and determination of uncertain tax positions involve judgment and estimates related to timing and probability of the recognition of income and deductions by taxing authorities. In addition, some temporary differences are accorded flow-through treatment by the Company’s regulators and impact the Company’s effective tax rate. In assessing the likelihood of the realization of deferred tax assets, management considers the estimated amount and character of future taxable income. Significant changes in these judgments and estimates could have a material impact on the results of operations and financial position of the Company. Actual income taxes could vary from estimated amounts due to the future impacts of various items, including changes in income tax laws, the Company’s forecasted financial condition and results of operations in future periods, and the final review from taxing authorities. See Note 11.

Market Risk

See Part II, Item 7A. Quantitative and Qualitative Disclosure About Market Risk for discussion regarding the Company’s accounting policies and sensitivity analysis for the Company’s financial instruments and derivative energy and other derivative contracts.

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.

ITEM 7A. 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:

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

• Approving of 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

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• 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 8, including a summary of the fair values of mark-to-market energy related derivative contracts included in the Consolidated Balance Sheets. At December 31, 2014 and 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 Consolidated Balance Sheet. The following table details the changes in the net asset or liability balance sheet position for mark-to-market energy transactions.

	Economic Hedges
	PNMR and PNM
	(In thousands)
Sources of fair value gain (loss):
Net fair value at December 31, 2012	$	1,204
Amount realized on contracts delivered during period	(970		)
Changes in fair value	2,836
Net mark-to-market change recorded in earnings	1,866
Net change recorded as regulatory liability	203
Net fair value at December 31, 2013	3,273
Amount realized on contracts delivered during period	1,420
Changes in fair value	5,084
Net mark-to-market change recorded in earnings	6,504
Net change recorded as regulatory liability	(231		)
Net fair value at December 31, 2014	$	9,546

The following table provides the maturity of the 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 December 31, 2014

	Settlement Dates
	2015		2016
PNMR and PNM	(In thousands)
Economic hedges
Prices actively quoted	$	—	$	—
Prices provided by other external sources	10,023		(477		)
Prices based on models and other valuations	—		—
Total	$	10,023	$	(477	)

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

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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 year ended December 31, 2014, the high, low, and average VaR amounts were $2.1 million, $0.6 million, and $0.9 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 December 31, 2014 and December 31, 2013, the VaR amounts for the PNM wholesale portfolio were $1.3 million and $0.6 million.

The VaR limits, which were not exceeded during 2014 or 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 credit exposure by the credit worthiness (credit rating) and concentration of credit risk for counterparties to derivative transactions. All credit exposures at December 31, 2014 will mature in less than two years.

Schedule of Credit Risk Exposure

December 31, 2014

Rating (1)	Credit Risk Exposure(2)		Number of Counter-parties >10%	Net Exposure of Counter-parties >10%
	(Dollars in thousands)
PNMR and PNM
External ratings:
Investment grade	$	6,290	2	$	5,131
Non-investment grade	—		—	—
Internal ratings:
Investment grade	1,003		—	—
Non-investment grade	781		—	—
Total	$	8,074		$	5,131

⁽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 December 31, 2014, PNMR and PNM held $0.2 million of cash collateral to offset their credit exposure.

Net credit risk for PNMR’s and PNM’s largest counterparty as of December 31, 2014 was $7.2 million, which is due from a firm-requirements wholesale customer.

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.

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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 long-term debt instruments for PNMR, PNM, and TNMP would increase by 1.9%, 1.4%, and 4.0%, if interest rates were to decline by 50 basis points from their levels at December 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. At February 20, 2015, PNMR, PNM, and TNMP had $0.8 million, $10.0 million, and $20.0 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 also had borrowings of $15.0 million under the $50.0 million PNM New Mexico Credit Facility at February 20, 2015. The revolving credit facilities, the PNM New Mexico Credit Facility, the $175.0 million PNM 2014 Term Loan, the $125.0 million PNM Multi-draw Term Loan, and the $100.0 million PNMR Term Loan Agreement bear interest at variable rates. On February 20, 2015, interest rates on borrowings averaged 1.67% for the PNMR Revolving Credit Facility, 1.02% for the PNMR 2014 Term Loan Agreement, 0.75% for the PNM Multi-draw Term Loan, 1.42% for the PNM Revolving Credit Facility, 1.42% for the PNM New Mexico Credit Facility, 1.12% for the PNM Term Loan, and 1.17% for the TNMP Revolving Credit Facility. 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, reclamation, pension benefits, and other post-employment benefits had an estimated fair value of $917.3 million at December 31, 2014, of which 57.6% 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 December 31, 2014, the decrease in the fair value of the fixed-rate securities would be 5.8%, or $30.6 million. The securities held by TNMP in trusts for pension and other post-employment benefits had an estimated fair value of $79.4 million at December 31, 2014, of which 59.6% were fixed-rate debt securities that subject TNMP 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 December 31, 2014, the decrease in the fair value of the fixed-rate securities would be 6.4%, or $3.0 million.

PNM and TNMP do not directly recover or return through rates any losses or gains on the securities, including equity and alternative investments discussed below, in the trusts for decommissioning, reclamation, pension benefits, and other post-employment benefits. 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 and TNMP are at risk for shortfalls in funding of obligations due to investment losses, including those from the equity market and alternatives investment 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 and trusts established for PNM’s and TNMP’s pension and post-employment benefits plans include certain equity securities at December 31, 2014. These equity securities expose PNM and TNMP to losses in fair value should the market values of the underlying securities decline. Equity securities comprised 32.8% and 25.5% of the securities held by the various PNM and TNMP trusts as of December 31, 2014. A hypothetical 10% decrease in equity prices would reduce the fair values of these funds by $30.1 million for PNM and $2.0 million for TNMP.

Alternatives Investment Risk

The Company had 11.4% of its pension assets invested in the alternatives asset class as of December 31, 2014. The Company has changed the target for this class to 14%. This includes real estate, private equity, and hedge funds. These investments are limited partner structures that are multi-manager multi-strategy funds. This investment approach gives broad diversification and minimizes risk compared to a direct investment in any one component of the funds. The general partner oversees the selection and monitoring of the underlying managers. The Company’s Corporate Investment Committee, assisted by its investment consultant, monitors the performance of the funds and general partner’s investment process. There is risk associated with these funds due to the nature of the strategies and techniques and the use of investments that do not have readily determinable fair value. A hypothetical 10% decrease in equity prices would reduce the fair values of these funds by $7.5 million.

A- 61

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

INDEX

	Page
Management’s Annual Reports on Internal Control Over Financial Reporting	B- 2
Reports of Independent Registered Public Accounting Firms	B- 5
Financial Statements:
PNM Resources, Inc. and Subsidiaries
Consolidated Statements of Earnings	B- 12
Consolidated Statements of Comprehensive Income	B- 13
Consolidated Statements of Cash Flows	B- 14
Consolidated Balance Sheets	B- 16
Consolidated Statements of Changes in Equity	B- 18
Public Service Company of New Mexico and Subsidiaries
Consolidated Statements of Earnings	B- 19
Consolidated Statements of Comprehensive Income	B- 20
Consolidated Statements of Cash Flows	B- 21
Consolidated Balance Sheets	B- 23
Consolidated Statements of Changes in Equity	B- 25
Texas-New Mexico Power Company and Subsidiaries
Consolidated Statements of Earnings	B- 26
Consolidated Statements of Comprehensive Income	B- 27
Consolidated Statements of Cash Flows	B- 28
Consolidated Balance Sheets	B- 30
Consolidated Statements of Changes in Common Stockholder’s Equity	B- 32
Notes to Consolidated Financial Statements	B- 33
Supplementary Data:
Reports of Independent Registered Public Accounting Firms on Schedules	B- 116
Schedule I - Condensed Financial Information of Parent Company	B- 121
Schedule II - Valuation and Qualifying Accounts	B- 124

B- 1

MANAGEMENT’S ANNUAL REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING

Management of PNM Resources, Inc. and subsidiaries (“PNMR”) is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rule 13a-15(f) under the Securities Exchange Act of 1934, as amended.

Management assessed the effectiveness of PNMR’s internal control over financial reporting based on the Internal Control – Integrated Framework (1992) set forth by the Committee of Sponsoring Organizations of the Treadway Commission. Based on the assessment performed, management concludes that PNMR’s internal control over financial reporting was effective as of December 31, 2014.

KPMG LLP, an independent registered public accounting firm, has issued an attestation report on PNMR’s internal control over financial reporting which is included herein.

/s/ Patricia K. Collawn

Patricia K. Collawn,

Chairman, President, and Chief Executive Officer

/s/ Charles Eldred

Charles Eldred

Executive Vice President and

Chief Financial Officer

B- 2

MANAGEMENT’S ANNUAL REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING

Management of Public Service Company of New Mexico and subsidiaries (“PNM”) is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rule 13a-15(f) under the Securities Exchange Act of 1934, as amended.

Management assessed the effectiveness of PNM’s internal control over financial reporting based on the Internal Control – Integrated Framework (1992) set forth by the Committee of Sponsoring Organizations of the Treadway Commission. Based on the assessment performed, management concludes that PNM’s internal control over financial reporting was effective as of December 31, 2014.

/s/ Patricia K. Collawn

Patricia K. Collawn,

President and Chief Executive Officer

/s/ Charles Eldred

Charles Eldred

Executive Vice President and

Chief Financial Officer

B- 3

MANAGEMENT’S ANNUAL REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING

Management of Texas-New Mexico Power Company and subsidiaries (“TNMP”) is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rule 13a-15(f) under the Securities Exchange Act of 1934, as amended.

Management assessed the effectiveness of TNMP’s internal control over financial reporting based on the Internal Control – Integrated Framework (1992) set forth by the Committee of Sponsoring Organizations of the Treadway Commission. Based on the assessment performed, management concludes that TNMP’s internal control over financial reporting was effective as of December 31, 2014.

/s/ Patricia K. Collawn

Patricia K. Collawn,

Chief Executive Officer

/s/ Thomas G. Sategna

Thomas G. Sategna

Vice President and Controller

B- 4

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

The Board of Directors and Stockholders

PNM Resources, Inc:

We have audited PNM Resources, Inc and subsidiaries (the Company) internal control over financial reporting as of December 31, 2014, based on criteria established in Internal Control - Integrated Framework (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Annual Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audit also included performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

A company’s internal control over financial reporting is a process designed 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. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

In our opinion, PNM Resources, Inc and subsidiaries maintained, in all material respects, effective internal control over financial reporting as of December 31, 2014, based on criteria established in Internal Control - Integrated Framework(1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheets of the Company as of December 31, 2014 and 2013, the related consolidated statements of earnings, consolidated statements of comprehensive income, consolidated statements of changes in equity, and consolidated statements of cash flows for each of the years in the two-year period ended December 31, 2014, and our report dated February 27, 2015 expressed an unqualified opinion on those consolidated financial statements.

/s/ KPMG LLP

Albuquerque, New Mexico

February 27, 2015

B- 5

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

The Board of Directors and Stockholders

PNM Resources, Inc:

We have audited the accompanying consolidated balance sheets of PNM Resources, Inc and subsidiaries (the Company) as of December 31, 2014 and 2013, and the related consolidated statements of earnings, consolidated statements of comprehensive income, consolidated statements of changes in equity, and consolidated statements of cash flows for each of the years in the two-year period ended December 31, 2014. These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of PNM Resources, Inc and subsidiaries as of December 31, 2014 and 2013, and the results of their operations and their cash flows for each of the years in the two-year period ended December 31, 2014, in conformity with U.S. generally accepted accounting principles.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the Company’s internal control over financial reporting as of December 31, 2014, based on criteria established in Internal Control - Integrated Framework(1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO), and our report dated February 27, 2015 expressed an unqualified opinion on the effectiveness of the Company’s internal control over financial reporting.

/s/ KPMG LLP

Albuquerque, New Mexico

February 27, 2015

B- 6

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Stockholders of

PNM Resources, Inc.

Albuquerque, New Mexico

We have audited the accompanying consolidated statements of earnings, comprehensive income, changes in equity, and cash flows of PNM Resources, Inc. and subsidiaries (the "Company") for the year ended December 31, 2012. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.

In our opinion, such consolidated financial statements present fairly, in all material respects, the results of operations and cash flows of PNM Resources, Inc. and subsidiaries for the year ended December 31, 2012, in conformity with accounting principles generally accepted in the United States of America.

/s/ DELOITTE & TOUCHE LLP

Phoenix, Arizona

March 1, 2013

B- 7

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

The Board of Directors and Stockholders

Public Service Company of New Mexico:

We have audited the accompanying consolidated balance sheets of Public Service Company of New Mexico and subsidiaries (the Company) as of December 31, 2014 and 2013, and the related consolidated statements of earnings, consolidated statements of comprehensive income, consolidated statements of changes in equity, and consolidated statements of cash flows for each of the years in the two-year period ended December 31, 2014. These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2014 and 2013, and the results of their operations and their cash flows for each of the years in the two-year period ended December 31, 2014, in conformity with U.S. generally accepted accounting principles.

/s/ KPMG LLP

Albuquerque, New Mexico

February 27, 2015

B- 8

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Stockholders of

Public Service Company of New Mexico

Albuquerque, New Mexico

We have audited the accompanying consolidated statements of earnings, comprehensive income, changes in equity, and cash flows of Public Service Company of New Mexico and subsidiaries (the "Company") for the year ended December 31, 2012. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audit included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company's internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.

In our opinion, such consolidated financial statements present fairly, in all material respects, the results of operations and cash flows of Public Service Company of New Mexico and subsidiaries for the year ended December 31, 2012, in conformity with accounting principles generally accepted in the United States of America.

/s/ DELOITTE & TOUCHE LLP

Phoenix, Arizona

March 1, 2013

B- 9

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

The Board of Directors and Stockholder

Texas-New Mexico Power Company:

We have audited the accompanying consolidated balance sheets of Texas-New Mexico Power Company and subsidiaries (the Company) as of December 31, 2014 and 2013, and the related consolidated statements of earnings, consolidated statements of comprehensive income, consolidated statements of changes in common stockholder’s equity, and consolidated statements of cash flows for each of the years in the two-year period ended December 31, 2014. These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2014 and 2013, and the results of their operations and their cash flows for each of the years in the two-year period ended December 31, 2014, in conformity with U.S. generally accepted accounting principles.

/s/ KPMG LLP

Albuquerque, New Mexico

February 27, 2015

B- 10

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Stockholder of

Texas-New Mexico Power Company

Lewisville, Texas

We have audited the accompanying consolidated statements of earnings, comprehensive income, changes in common stockholder’s equity, and cash flows of Texas-New Mexico Power Company and subsidiaries (the "Company") for the year ended December 31, 2012. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audit included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company's internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.

In our opinion, such consolidated financial statements present fairly, in all material respects, the results of operations and cash flows of Texas-New Mexico Power Company and subsidiaries for the year ended December 31, 2012, in conformity with accounting principles generally accepted in the United States of America.

/s/ DELOITTE & TOUCHE LLP

Phoenix, Arizona

March 1, 2013

B- 11

PNM RESOURCES, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF EARNINGS

	Year Ended December 31,
	2014			2013			2012
	(In thousands, except per share amounts)
Electric Operating Revenues	$	1,435,853		$	1,387,923		$	1,342,403
Operating Expenses:
Cost of energy	471,556			432,316			399,850
Administrative and general	171,111			179,210			187,740
Energy production costs	185,638			175,819			185,417
Regulatory disallowances	1,062			12,235			—
Depreciation and amortization	172,634			166,881			164,173
Transmission and distribution costs	66,571			70,124			71,125
Taxes other than income taxes	67,584			64,496			60,377
Total operating expenses	1,136,156			1,101,081			1,068,682
Operating income	299,697			286,842			273,721
Other Income and Deductions:
Interest income	8,483			10,043			13,072
Gains on available-for-sale securities	10,527			10,612			12,965
Other income	12,048			10,572			12,746
Gain on sale of First Choice	—			—			1,012
Other (deductions)	(10,481		)	(21,552		)	(17,636		)
Net other income and deductions	20,577			9,675			22,159
Interest Charges	119,627			121,448			120,845
Earnings before Income Taxes	200,647			175,069			175,035
Income Taxes	69,738			59,513			54,910
Net Earnings	130,909			115,556			120,125
(Earnings) Attributable to Valencia Non-controlling Interest	(14,127		)	(14,521		)	(14,050		)
Preferred Stock Dividend Requirements of Subsidiary	(528		)	(528		)	(528		)
Net Earnings Attributable to PNMR	$	116,254		$	100,507		$	105,547
Net Earnings Attributable to PNMR per Common Share:
Basic	$	1.46		$	1.26		$	1.32
Diluted	$	1.45		$	1.25		$	1.31

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

B- 12

PNM RESOURCES, INC. AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Net Earnings	$	130,909		$	115,556		$	120,125
Other Comprehensive Income:
Unrealized Gain on Available-for-Sale Securities:
Unrealized holding gains arising during the period, net of income tax (expense) of $(6,812), $(10,855), and $(15,262)	10,661			16,564			23,286
Reclassification adjustment for (gains) included in net earnings, net of income tax expense of $5,461, $4,734, and $14,755	(8,401		)	(7,222		)	(22,514		)
Pension Liability Adjustment:
Experience gain (loss), net of income tax (expense) benefit of $6,024, $(6,781) and $11,910	(9,258		)	10,355			(18,174		)
Reclassification adjustment for amortization of experience (gain) loss recognized as net periodic benefit cost, net of income tax expense (benefit) of $(2,032), $(2,524) and $(1,825)	3,120			3,840			2,786
Fair Value Adjustment for Designated Cash Flow Hedges:
Change in fair market value, net of income tax (expense) benefit of $53, $98, and $153	(100		)	(181		)	(275		)
Reclassification adjustment for (gains) losses included in net earnings, net of income tax expense (benefit) of $(195), $(73), and $(65)	363			134			117
Total Other Comprehensive Income (Loss)	(3,615		)	23,490			(14,774		)
Comprehensive Income	127,294			139,046			105,351
Comprehensive (Income) Attributable to Valencia Non-controlling Interest	(14,127		)	(14,521		)	(14,050		)
Preferred Stock Dividend Requirements of Subsidiary	(528		)	(528		)	(528		)
Comprehensive Income Attributable to PNMR	$	112,639		$	123,997		$	90,773

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

B- 13

PNM RESOURCES, INC. AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF CASH FLOWS
	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Cash Flows From Operating Activities:
Net earnings	$	130,909		$	115,556		$	120,125
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	209,867			208,173			206,499
Deferred income tax expense	72,481			60,430			56,243
(Gain) on sale of First Choice	—			—			(1,012		)
Net unrealized (gains) on derivatives	(6,504		)	(1,866		)	(1,598		)
Realized (gains) on available-for-sale securities	(10,527		)	(10,612		)	(12,965		)
Loss on reacquired debt	—			3,253			—
Abandonment of leased premises	—			—			7,411
Stock based compensation expense	5,931			5,320			3,585
Regulatory disallowances	1,062			12,235			—
Other, net	(1,518		)	(1,647		)	(798		)
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	(4,975		)	(7,562		)	(2,547		)
Materials, supplies, and fuel stock	5,504			(7,580		)	(5,412		)
Other current assets	(30,436		)	8,577			(2,598		)
Other assets	290			(12,801		)	(30,778		)
Accounts payable	(2,311		)	4,484			14,020
Accrued interest and taxes	2,040			91,537			255
Other current liabilities	(2,453		)	(19,648		)	(19,905		)
Proceeds from governmental grants	—			—			21,567
Other liabilities	45,516			(61,262		)	(70,743		)
Net cash flows from operating activities	414,876			386,587			281,349
Cash Flows From Investing Activities:
Additions to utility and non-utility plant	(460,658		)	(348,039		)	(308,909		)
Proceeds from sales of available-for-sale securities	117,989			271,140			167,330
Purchases of available-for-sale securities	(127,016		)	(282,000		)	(176,748		)
Proceeds from sale of First Choice	—			—			4,034
Return of principal on PVNGS lessor notes	20,758			23,357			23,455
Purchase of Rio Bravo	(36,235		)	—			—
Other, net	(167		)	4,096			4,943
Net cash flows from investing activities	(485,329		)	(331,446		)	(285,895		)

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

B- 14

PNM RESOURCES, INC. AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF CASH FLOWS
	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Cash Flows From Financing Activities:
Short-term loan	—			—			100,000
Revolving credit facilities borrowings (repayments), net	(43,600		)	(9,500		)	(24,000		)
Long-term borrowings	355,000			75,000			20,000
Repayment of long-term debt	(125,000		)	(29,468		)	(22,387		)
Cash paid in debt exchange	—			(13,048		)	—
Proceeds from stock option exercise	6,999			4,618			11,684
Purchases to satisfy awards of common stock	(17,319		)	(13,807		)	(25,168		)
Dividends paid	(59,468		)	(51,508		)	(45,137		)
Valencia’s transactions with its owner	(17,610		)	(18,335		)	(15,630		)
Other, net	(2,808		)	(5,545		)	(922		)
Net cash flows from financing activities	96,194			(61,593		)	(1,560		)
Change in Cash and Cash Equivalents	25,741			(6,452		)	(6,106		)
Cash and Cash Equivalents at Beginning of Year	2,533			8,985			15,091
Cash and Cash Equivalents at End of Year	$	28,274		$	2,533		$	8,985
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	$	108,741		$	110,768		$	113,265
Income taxes paid (refunded), net	$	(2,597	)	$	(95,327	)	$	5,302
Supplemental schedule of noncash investing and financing activities:
Changes in accrued plant additions	$	3,089		$	6,006		$	(17,983	)
Premium on long-term debt incurred in connection with debt exchange				$	36,297

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

B- 15

PNM RESOURCES, INC. AND SUBSIDIARIES CONSOLIDATED BALANCE SHEETS
	December 31,
	2014		2013
	(In thousands)
ASSETS
Current Assets:
Cash and cash equivalents	$	28,274	$	2,533
Accounts receivable, net of allowance for uncollectible accounts of $1,466 and $1,423	87,038		90,251
Unbilled revenues	63,719		58,806
Other receivables	39,857		53,909
Materials, supplies, and fuel stock	63,628		67,223
Regulatory assets	47,855		24,416
Commodity derivative instruments	11,232		4,064
Income taxes receivable	6,360		7,066
Current portion of accumulated deferred income taxes	26,383		58,681
Other current assets	58,471		34,590
Total current assets	432,817		401,539
Other Property and Investments:
Investment in PVNGS lessor notes	9,538		32,200
Available-for-sale securities	250,145		226,855
Other investments	1,762		1,835
Non-utility property	3,406		4,353
Total other property and investments	264,851		265,243
Utility Plant:
Plant in service and plant held for future use	5,941,581		5,563,061
Less accumulated depreciation and amortization	1,939,760		1,838,832
	4,001,821		3,724,229
Construction work in progress	190,389		132,080
Nuclear fuel, net of accumulated amortization of $44,507 and $47,347	77,796		77,602
Net utility plant	4,270,006		3,933,911
Deferred Charges and Other Assets:
Regulatory assets	491,007		523,955
Goodwill	278,297		278,297
Commodity derivative instruments	—		3,002
Other deferred charges	92,347		94,263
Total deferred charges and other assets	861,651		899,517
	$	5,829,325	$	5,500,210

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

B- 16

PNM RESOURCES, INC. AND SUBSIDIARIES CONSOLIDATED BALANCE SHEETS
	December 31,
	2014			2013
	(In thousands, except share information)
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current Liabilities:
Short-term debt	$	105,600		$	149,200
Current installments of long-term debt	333,066			75,000
Accounts payable	110,029			109,666
Customer deposits	12,555			13,456
Accrued interest and taxes	53,863			49,600
Regulatory liabilities	1,703			1,081
Commodity derivative instruments	1,209			2,699
Dividends declared	16,063			14,864
Other current liabilities	70,194			77,105
Total current liabilities	704,282			492,671
Long-term Debt	1,642,024			1,670,420
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	891,111			827,263
Regulatory liabilities	466,143			460,649
Asset retirement obligations	104,170			96,135
Accrued pension liability and postretirement benefit cost	110,738			80,046
Commodity derivative instruments	477			1,094
Other deferred credits	103,759			109,805
Total deferred credits and other liabilities	1,676,398			1,574,992
Total liabilities	4,022,704			3,738,083
Commitments and Contingencies (See Note 16)
Cumulative Preferred Stock of Subsidiary
without mandatory redemption requirements ($100 stated value; 10,000,000 shares authorized; issued and outstanding 115,293 shares)	11,529			11,529
Equity:
PNMR common stockholders’ equity:
Common stock (no par value; 120,000,000 shares authorized; issued and outstanding 79,653,624 shares)	1,173,845			1,178,369
Accumulated other comprehensive income (loss), net of income taxes	(61,755		)	(58,140		)
Retained earnings	609,456			553,340
Total PNMR common stockholders’ equity	1,721,546			1,673,569
Non-controlling interest in Valencia	73,546			77,029
Total equity	1,795,092			1,750,598
	$	5,829,325		$	5,500,210

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

B- 17

PNM RESOURCES, INC. AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
	Attributable to PNMR												Non- controlling Interest in Valencia
	PNMR Common Stockholders’ Equity
	Common Stock			AOCI			Retained Earnings			Total						Total Equity
	(In thousands)
Balance at December 31, 2011	$	1,193,191		$	(66,856	)	$	447,650		$	1,573,985		$	82,423		$	1,656,408
Proceeds from stock option exercise	11,684			—			—			11,684			—			11,684
Purchases to satisfy awards of common stock	(25,168		)	—			—			(25,168		)	—			(25,168		)
Excess tax (shortfall) from stock-based payment arrangements	(473		)	—			—			(473		)	—			(473		)
Stock based compensation expense	3,585			—			—			3,585			—			3,585
Valencia’s transactions with its owner	—			—			—			—			(15,630		)	(15,630		)
Net earnings before subsidiary preferred stock dividends	—			—			106,075			106,075			14,050			120,125
Subsidiary preferred stock dividends	—			—			(528		)	(528		)	—			(528		)
Total other comprehensive income (loss)	—			(14,774		)	—			(14,774		)	—			(14,774		)
Dividends declared on common stock	—			—			(46,199		)	(46,199		)	—			(46,199		)
Balance at December 31, 2012	1,182,819			(81,630		)	506,998			1,608,187			80,843			1,689,030
Proceeds from stock option exercise	4,618			—			—			4,618			—			4,618
Purchases to satisfy awards of common stock	(13,807		)	—			—			(13,807		)	—			(13,807		)
Excess tax (shortfall) from stock-based payment arrangements	(581		)	—			—			(581		)	—			(581		)
Stock based compensation expense	5,320			—			—			5,320			—			5,320
Valencia’s transactions with its owner	—			—			—			—			(18,335		)	(18,335		)
Net earnings before subsidiary preferred stock dividends	—			—			101,035			101,035			14,521			115,556
Subsidiary preferred stock dividends	—			—			(528		)	(528		)	—			(528		)
Total other comprehensive income	—			23,490			—			23,490			—			23,490
Dividends declared on common stock	—			—			(54,165		)	(54,165		)	—			(54,165		)
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	6,999			—			—			6,999			—			6,999
Purchases to satisfy awards of common stock	(17,319		)	—			—			(17,319		)	—			(17,319		)
Excess tax (shortfall) from stock-based payment arrangements	(135		)	—			—			(135		)	—			(135		)
Stock based compensation expense	5,931			—			—			5,931			—			5,931
Valencia’s transactions with its owner	—			—			—			—			(17,610		)	(17,610		)
Net earnings before subsidiary preferred stock dividends	—			—			116,782			116,782			14,127			130,909
Subsidiary preferred stock dividends	—			—			(528		)	(528		)	—			(528		)
Total other comprehensive income	—			(3,615		)	—			(3,615		)	—			(3,615		)
Dividends declared on common stock	—			—			(60,138		)	(60,138		)	—			(60,138		)
Balance at December 31, 2014	$	1,173,845		$	(61,755	)	$	609,456		$	1,721,546		$	73,546		$	1,795,092

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

B- 18

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC. CONSOLIDATED STATEMENTS OF EARNINGS
	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Electric Operating Revenues	$	1,147,914		$	1,116,312		$	1,092,264
Operating Expenses:
Cost of energy	403,626			374,710			353,649
Administrative and general	152,645			157,144			169,285
Energy production costs	185,638			175,819			185,403
Regulatory disallowances	1,062			12,235			—
Depreciation and amortization	109,524			103,826			97,291
Transmission and distribution costs	43,128			45,936			46,039
Taxes other than income taxes	39,578			37,457			34,715
Total operating expenses	935,201			907,127			886,382
Operating income	212,713			209,185			205,882
Other Income and Deductions:
Interest income	8,557			10,182			13,243
Gains on available-for-sale securities	10,527			10,612			12,965
Other income	8,949			7,650			8,126
Other (deductions)	(7,218		)	(6,974		)	(7,801		)
Net other income and deductions	20,815			21,470			26,533
Interest Charges	79,442			79,175			76,101
Earnings before Income Taxes	154,086			151,480			156,314
Income Taxes	52,633			48,804			50,713
Net Earnings	101,453			102,676			105,601
(Earnings) Attributable to Valencia Non-controlling Interest	(14,127		)	(14,521		)	(14,050		)
Net Earnings Attributable to PNM	87,326			88,155			91,551
Preferred Stock Dividends Requirements	(528		)	(528		)	(528		)
Net Earnings Available for PNM Common Stock	$	86,798		$	87,627		$	91,023

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

B- 19

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC. CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Net Earnings	$	101,453		$	102,676		$	105,601
Other Comprehensive Income:
Unrealized Gain on Available-for-Sale Securities:
Unrealized holding gains arising during the period, net of income tax (expense) of $(6,812), $(10,855), and $(15,262)	10,661			16,564			23,286
Reclassification adjustment for (gains) included in net earnings, net of income tax expense of $5,461, $4,734, and $14,755	(8,401		)	(7,222		)	(22,514		)
Pension Liability Adjustment:
Experience gain (loss), net of income tax (expense) benefit of $6,024, $(6,781) and $11,910	(9,258		)	10,355			(18,174		)
Reclassification adjustment for amortization of experience (gain) loss recognized as net periodic benefit cost, net of income tax expense (benefit) of $(2,032), $(2,524) and $(1,825)	3,120			3,840			2,786
Total Other Comprehensive Income (Loss)	(3,878		)	23,537			(14,616		)
Comprehensive Income	97,575			126,213			90,985
Comprehensive (Income) Attributable to Valencia Non-controlling Interest	(14,127		)	(14,521		)	(14,050		)
Comprehensive Income Attributable to PNM	$	83,448		$	111,692		$	76,935

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

B- 20

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC. CONSOLIDATED STATEMENTS OF CASH FLOWS
	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Cash Flows From Operating Activities:
Net earnings	$	101,453		$	102,676		$	105,601
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	143,303			136,732			129,514
Deferred income tax expense	55,787			50,043			65,479
Net unrealized (gains) losses on derivatives	(6,504		)	(1,866		)	(1,598		)
Realized (gains) on available-for-sale securities	(10,527		)	(10,612		)	(12,965		)
Regulatory disallowances	1,062			12,235			—
Other, net	(1,391		)	(1,614		)	(170		)
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	(5,919		)	(3,021		)	(4,756		)
Materials, supplies, and fuel stock	5,570			(7,730		)	(5,268		)
Other current assets	(29,146		)	8,556			(3,014		)
Other assets	7,150			(13,363		)	(27,338		)
Accounts payable	212			2,807			11,028
Accrued interest and taxes	(3,599		)	72,740			47,666
Other current liabilities	(659		)	(27,376		)	(2,539		)
Proceeds from governmental grants	—			—			21,567
Other liabilities	42,325			(59,753		)	(54,787		)
Net cash flows from operating activities	299,117			260,454			268,420
Cash Flows From Investing Activities:
Utility plant additions	(316,800		)	(239,906		)	(196,800		)
Proceeds from sales of available-for-sale securities	117,989			271,140			167,330
Purchases of available-for-sale securities	(127,016		)	(282,000		)	(176,748		)
Return of principal on PVNGS lessor notes	20,758			23,357			23,455
Purchase of Rio Bravo	(36,235		)	—			—
Other, net	(363		)	3,843			2,406
Net cash flows from investing activities	(341,667		)	(223,566		)	(180,357		)

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

B- 21

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC. CONSOLIDATED STATEMENTS OF CASH FLOWS
	Year ended December 31,
	2014			2013			2012
	(In thousands)
Cash Flows From Financing Activities:
Short-term borrowings (repayments), net	(49,200		)	28,100			(44,900		)
Short-term borrowings (repayments) - affiliate, net	(32,500		)	32,500			—
Long-term borrowings	275,000			75,000			20,000
Repayment of long-term debt	(75,000		)	—			(20,000		)
Valencia’s transactions with its owner	(17,610		)	(18,335		)	(15,630		)
Dividends paid	(30,791		)	(155,556		)	(34,961		)
Other, net	(1,890		)	(2,534		)	(921		)
Net cash flows from financing activities	68,009			(40,825		)	(96,412		)
Change in Cash and Cash Equivalents	25,459			(3,937		)	(8,349		)
Cash and Cash Equivalents at Beginning of Year	21			3,958			12,307
Cash and Cash Equivalents at End of Year	$	25,480		$	21		$	3,958
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	$	73,787		$	71,306		$	73,036
Income taxes paid (refunded), net	$	(228	)	$	(77,434	)	$	(63,113	)
Supplemental schedule of noncash investing activities:
Changes in accrued plant additions	$	1,616		$	7,921		$	(19,732	)

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

B- 22

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC. CONSOLIDATED BALANCE SHEETS
	December 31,
	2014		2013
	(In thousands)
ASSETS
Current Assets:
Cash and cash equivalents	$	25,480	$	21
Accounts receivable, net of allowance for uncollectible accounts of $1,466 and $1,423	67,622		70,126
Unbilled revenues	54,140		48,992
Other receivables	37,622		52,964
Affiliate receivables	8,853		10,054
Materials, supplies, and fuel stock	60,859		64,520
Regulatory assets	43,980		19,394
Commodity derivative instruments	11,232		4,064
Income taxes receivable	6,105		4,030
Current portion of accumulated deferred income taxes	12,418		43,827
Other current assets	53,095		30,510
Total current assets	381,406		348,502
Other Property and Investments:
Investment in PVNGS lessor notes	9,538		32,200
Available-for-sale securities	250,145		226,855
Other investments	397		445
Non-utility property	96		976
Total other property and investments	260,176		260,476
Utility Plant:
Plant in service and plant held for future use	4,581,066		4,314,016
Less accumulated depreciation and amortization	1,486,406		1,402,531
	3,094,660		2,911,485
Construction work in progress	169,673		107,344
Nuclear fuel, net of accumulated amortization of $44,507 and $47,347	77,796		77,602
Net utility plant	3,342,129		3,096,431
Deferred Charges and Other Assets:
Regulatory assets	357,045		384,217
Goodwill	51,632		51,632
Commodity derivative instruments	—		3,002
Other deferred charges	81,264		83,356
Total deferred charges and other assets	489,941		522,207
	$	4,473,652	$	4,227,616

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

B- 23

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC. CONSOLIDATED BALANCE SHEETS
	December 31,
	2014			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	214,300			75,000
Accounts payable	86,055			84,643
Affiliate payables	18,232			20,498
Customer deposits	12,555			13,456
Accrued interest and taxes	29,298			27,665
Regulatory liabilities	1,703			1,081
Commodity derivative instruments	1,209			2,699
Dividends declared	132			132
Other current liabilities	52,053			50,392
Total current liabilities	415,537			357,266
Long-term Debt	1,276,357			1,215,618
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	715,814			677,094
Regulatory liabilities	425,481			414,611
Asset retirement obligations	103,182			95,225
Accrued pension liability and postretirement benefit cost	102,850			76,611
Commodity derivative instruments	477			1,094
Other deferred credits	86,023			91,340
Total deferred credits and liabilities	1,433,827			1,355,975
Total liabilities	3,125,721			2,928,859
Commitments and Contingencies (See Note 16)
Cumulative Preferred Stock
without mandatory redemption requirements ($100 stated value; 10,000,000 shares authorized; issued and outstanding 115,293 shares)	11,529			11,529
Equity:
PNM common stockholder’s equity:
Common stock (no par value; 40,000,000 shares authorized; issued and outstanding 39,117,799 shares)	1,061,776			1,061,776
Accumulated other comprehensive income (loss), net of income tax	(61,755		)	(57,877		)
Retained earnings	262,835			206,300
Total PNM common stockholder’s equity	1,262,856			1,210,199
Non-controlling interest in Valencia	73,546			77,029
Total equity	1,336,402			1,287,228
	$	4,473,652		$	4,227,616

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

B- 24

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC. CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
	Attributable to PNM
	Common Stock		AOCI			Retained Earnings			Total PNM Common Stockholder’s Equity			Non- controlling Interest in Valencia			Total Equity
	(In thousands)
Balance at December 31, 2011	$	1,061,776	$	(66,798	)	$	217,111		$	1,212,089		$	82,423		$	1,294,512
Valencia’s transactions with its owner	—		—			—			—			(15,630		)	(15,630		)
Net earnings	—		—			91,551			91,551			14,050			105,601
Total other comprehensive income (loss)	—		(14,616		)	—			(14,616		)	—			(14,616		)
Dividends declared on preferred stock	—		—			(528		)	(528		)	—			(528		)
Dividends declared on common stock	—		—			(34,433		)	(34,433		)	—			(34,433		)
Balance at December 31, 2012	1,061,776		(81,414		)	273,701			1,254,063			80,843			1,334,906
Valencia’s transactions with its owner	—		—			—			—			(18,335		)	(18,335		)
Net earnings	—		—			88,155			88,155			14,521			102,676
Total other comprehensive income	—		23,537			—			23,537			—			23,537
Dividends declared on preferred stock	—		—			(528		)	(528		)	—			(528		)
Dividends declared on common stock	—		—			(155,028		)	(155,028		)	—			(155,028		)
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	—		—			—			—			(17,610		)	(17,610		)
Net earnings	—		—			87,326			87,326			14,127			101,453
Total other comprehensive income (loss)	—		(3,878		)	—			(3,878		)	—			(3,878		)
Dividends declared on preferred stock	—		—			(528		)	(528		)	—			(528		)
Dividends declared on common stock	—		—			(30,263		)	(30,263		)	—			(30,263		)
Balance at December 31, 2014	$	1,061,776	$	(61,755	)	$	262,835		$	1,262,856		$	73,546		$	1,336,402

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

B- 25

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC. CONSOLIDATED STATEMENTS OF EARNINGS
	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Electric Operating Revenues	$	287,939		$	271,611		$	250,140
Operating Expenses:
Cost of energy	67,930			57,606			46,201
Administrative and general	36,982			44,635			40,775
Depreciation and amortization	50,056			50,219			49,340
Transmission and distribution costs	23,443			24,188			25,086
Taxes other than income taxes	23,940			22,778			21,218
Total operating expenses	202,351			199,426			182,620
Operating income	85,588			72,185			67,520
Other Income and Deductions:
Interest income	—			—			1
Other income	2,865			2,377			4,698
Other (deductions)	(727		)	(458		)	(1,959		)
Net other income and deductions	2,138			1,919			2,740
Interest Charges	27,396			27,393			28,161
Earnings Before Income Taxes	60,330			46,711			42,099
Income Taxes	22,523			17,621			15,352
Net Earnings	$	37,807		$	29,090		$	26,747

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

B- 26

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC. CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Net Earnings	$	37,807		$	29,090		$	26,747
Other Comprehensive Income (Loss):
Fair Value Adjustment for Designated Cash Flow Hedge:
Change in fair value, net of income tax (expense) benefit of $53, $98, and $153	(100		)	(181		)	(275		)
Reclassification adjustment for losses included in net earnings, net of income tax expense (benefit) of $(195), $(73), and $(65)	363			134			117
Total Other Comprehensive Income (Loss)	263			(47		)	(158		)
Comprehensive Income	$	38,070		$	29,043		$	26,589

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

B- 27

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC. CONSOLIDATED STATEMENTS OF CASH FLOWS
	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Cash Flows From Operating Activities:
Net earnings	$	37,807		$	29,090		$	26,747
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	52,847			54,395			54,396
Deferred income tax expense	20,549			20,662			4,378
Other, net	(10		)	(30		)	(889		)
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	944			(4,542		)	2,208
Materials and supplies	(66		)	150			(143		)
Other current assets	380			(1,137		)	(3,515		)
Other assets	(6,607		)	941			(3,145		)
Accounts payable	2,514			3,709			(666		)
Accrued interest and taxes	4,796			(6,713		)	9,825
Other current liabilities	(203		)	(3,197		)	(2,106		)
Other liabilities	3,112			460			4,311
Net cash flows from operating activities	116,063			93,788			91,401
Cash Flows From Investing Activities:
Utility plant additions	(127,191		)	(89,117		)	(92,973		)
Net cash flows from investing activities	(127,191		)	(89,117		)	(92,973		)

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

B- 28

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC. CONSOLIDATED STATEMENTS OF CASH FLOWS
	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Cash Flow From Financing Activities:
Short-term borrowings (repayments), net	5,000			—			—
Short-term borrowings (repayments) – affiliate, net	(6,700		)	1,100			27,600
Long-term borrowings	80,000			—			—
Repayment of long-term debt	(50,000		)	—			—
Cash paid in debt exchange	—			(13,048		)	—
Equity contribution from parent	—			13,800			—
Dividends paid	(16,336		)	(3,726		)	(26,028		)
Other, net	(836		)	(2,797		)	—
Net cash flows from financing activities	11,128			(4,671		)	1,572
Change in Cash and Cash Equivalents	—			—			—
Cash and Cash Equivalents at Beginning of Year	1			1			1
Cash and Cash Equivalents at End of Year	$	1		$	1		$	1
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	$	22,803		$	25,436		$	25,360
Income taxes paid, (refunded) net	$	(355	)	$	4,484		$	1,848
Supplemental schedule of noncash investing and financing activities:
Changes in accrued plant additions	$	(854	)	$	141		$	(2,749	)
Premium on long-term debt incurred in connection with debt exchange				$	36,297

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

B- 29

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC. CONSOLIDATED BALANCE SHEETS
	December 31,
	2014		2013
	(In thousands)
ASSETS
Current Assets:
Cash and cash equivalents	$	1	$	1
Accounts receivable	19,416		20,125
Unbilled revenues	9,579		9,814
Other receivables	2,063		1,246
Materials and supplies	2,769		2,703
Regulatory assets	3,875		5,022
Current portion of accumulated deferred income taxes	6,398		6,501
Other current assets	938		980
Total current assets	45,039		46,392
Other Property and Investments:
Other investments	242		245
Non-utility property	2,240		2,240
Total other property and investments	2,482		2,485
Utility Plant:
Plant in service and plant held for future use	1,182,112		1,074,193
Less accumulated depreciation and amortization	375,407		352,105
	806,705		722,088
Construction work in progress	16,538		16,790
Net utility plant	823,243		738,878
Deferred Charges and Other Assets:
Regulatory assets	133,962		139,738
Goodwill	226,665		226,665
Other deferred charges	8,850		8,273
Total deferred charges and other assets	369,477		374,676
	$	1,240,241	$	1,162,431

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

B- 30

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC. CONSOLIDATED BALANCE SHEETS
	December 31,
	2014		2013
	(In thousands, except share information)
LIABILITIES AND STOCKHOLDER’S EQUITY
Current Liabilities:
Short-term debt	$	5,000	$	—
Short-term debt – affiliate	22,700		29,400
Accounts payable	14,203		12,543
Affiliate payables	2,469		3,181
Accrued interest and taxes	28,574		23,778
Other current liabilities	2,271		8,999
Total current liabilities	75,217		77,901
Long-term Debt	365,667		336,036
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	217,945		190,197
Regulatory liabilities	40,662		46,038
Asset retirement obligations	848		782
Accrued pension liability and postretirement benefit cost	7,888		3,435
Other deferred credits	7,349		5,111
Total deferred credits and other liabilities	274,692		245,563
Total liabilities	715,576		659,500
Commitments and Contingencies (See Note 16)
Common Stockholder’s Equity:
Common stock ($10 par value; 12,000,000 shares authorized; issued and outstanding 6,358 shares)	64		64
Paid-in-capital	404,166		404,166
Accumulated other comprehensive income (loss), net of income tax	—		(263		)
Retained earnings	120,435		98,964
Total common stockholder’s equity	524,665		502,931
	$	1,240,241	$	1,162,431

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

B- 31

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC.

CONSOLIDATED STATEMENTS OF CHANGES IN COMMON STOCKHOLDER’S EQUITY

	Common Stock		Paid-in Capital			AOCI			Retained Earnings			Total Common Stockholder’s Equity
						(In thousands)
Balance at December 31, 2011	$	64	$	416,394		$	(58	)	$	46,853		$	463,253
Net earnings	—		—			—			26,747			26,747
Total other comprehensive income (loss)	—		—			(158		)	—			(158		)
Dividends declared on common stock	—		(26,028		)	—			—			(26,028		)
Balance at December 31, 2012	64		390,366			(216		)	73,600			463,814
Net earnings	—		—			—			29,090			29,090
Total other comprehensive income (loss)	—		—			(47		)	—			(47		)
Equity contributions from parent	—		13,800			—			—			13,800
Dividends declared on common stock	—		—			—			(3,726		)	(3,726		)
Balance at December 31, 2013	64		404,166			(263		)	98,964			502,931
Net earnings	—		—			—			37,807			37,807
Total other comprehensive income	—		—			263			—			263
Dividends declared on common stock	—		—			—			(16,336		)	(16,336		)
Balance at December 31, 2014	$	64	$	404,166		$	—		$	120,435		$	524,665

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

B- 32

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

(1) Summary of the Business and Significant Accounting Policies

Nature of Business

PNMR is an investor-owned holding company of energy and energy-related businesses. PNMR’s primary subsidiaries are PNM and TNMP. PNM is a public utility with regulated operations primarily engaged in the generation, transmission, and distribution of electricity. TNMP is a wholly owned subsidiary of TNP, which is a holding company that is wholly owned by PNMR. TNMP provides regulated transmission and distribution services in Texas. PNMR’s common stock trades on the New York Stock Exchange under the symbol PNM.

Financial Statement Preparation and Presentation

The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could ultimately differ from those estimated.

The Notes to Consolidated Financial Statements include disclosures for PNMR, PNM, and TNMP. For discussion purposes, this report uses the term “Company” when discussing matters of common applicability to PNMR, PNM, and TNMP. Discussions regarding only PNMR, PNM, or TNMP are so indicated.

Certain amounts in the 2013 and 2012 Consolidated Financial Statements and Notes thereto have been reclassified to conform to the 2014 financial statement presentation.

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

Principles of Consolidation

The Consolidated Financial Statements of each of PNMR, PNM, and TNMP include their accounts and those of subsidiaries in which that entity owns a majority voting interest. PNM also consolidates the PVNGS Capital Trust and Valencia (Note 9). 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.

PNMR shared services’ administrative and general expenses, which represent costs that are primarily driven by corporate level activities, are charged to the business segments. These services are billed at cost. Other significant intercompany transactions between PNMR, PNM, and TNMP include interest and income tax sharing payments, as well as equity transactions. All intercompany transactions and balances have been eliminated. See Note 18.

Accounting for the Effects of Certain Types of Regulation

The Company maintains its accounting records in accordance with the uniform system of accounts prescribed by FERC and adopted by the NMPRC and PUCT.

Certain of the Company’s operations are regulated by the NMPRC, PUCT, and FERC and the provisions of GAAP for rate-regulated enterprises are applied to the regulated operations. Regulators may assign costs to accounting periods that differ from accounting methods applied by non-regulated utilities.  When it is probable that regulators will permit recovery of costs through future rates, costs that otherwise would be expensed are deferred as regulatory assets.  Likewise, regulatory liabilities are recognized when it is probable that regulators will require refunds through future rates or when revenue is collected for expenditures that have not yet been incurred.  Regulatory assets and liabilities are amortized into earnings over the authorized recovery period. Accordingly, the Company has deferred certain costs and recorded certain liabilities pursuant to the rate actions of the NMPRC, PUCT, and FERC. Information on regulatory assets and regulatory liabilities is contained in Note 4.

B- 33

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

In some circumstances, regulators allow a requested increase in rates to be implemented, subject to refund, before the regulatory process has been completed and a decision rendered by the regulator. When this occurs, the Company assesses the possible outcomes of the rate proceeding. The Company records a provision for refund to the extent the amounts being collected, subject to refund, exceed the amount the Company determines is probable of ultimately being allowed by the regulator.

Competition Transition Charge

In connection with the adoption of Senate Bill 7 by the Texas Legislature in 1999 that deregulated electric utilities operating within ERCOT, TNMP was allowed to recover its stranded costs through the CTC and to also recover a carrying charge on the CTC. The amounts yet to be collect are recorded as regulatory assets by TNMP. TNMP’s calculation of allowable carrying charges on stranded costs recoverable from its transmission and distribution customers is based on a Texas Supreme Court ruling and the PUCT’s application of that ruling.

Cash and Cash Equivalents

Investments in highly liquid investments with original maturities of three months or less at the date of purchase are considered cash equivalents.

Utility Plant

Utility plant is stated at cost, which includes capitalized payroll-related costs such as taxes, pension, and other fringe benefits, administrative costs, and AFUDC where authorized by rate regulation.

Repairs, including major maintenance activities, and minor replacements of property are expensed when incurred, except as required by regulators for ratemaking purposes. Major replacements are charged to utility plant. Gains or losses resulting from retirements or other dispositions of regulated property in the normal course of business are credited or charged to accumulated depreciation.

Allowance for Funds Used During Construction

As provided by the FERC uniform systems of accounts, AFUDC is charged to regulated utility plant for construction projects. This allowance is a non-cash item designed to enable a utility to capitalize financing costs during periods of construction of property subject to rate regulation. It represents the cost of borrowed funds (allowance for borrowed funds used during construction) and a return on other funds (allowance for equity funds used during construction). The allowance for borrowed funds used during construction is recorded in interest charges and the allowance for equity funds used during construction is recorded in other income on the Consolidated Statements of Earnings.

For the years ended December 31, 2014, 2013, and 2012, PNM recorded $4.2 million, $3.3 million, and $3.5 million of allowance for borrowed funds used during construction and $5.6 million, $4.4 million, and $3.8 million of allowance for equity funds used during construction. TNMP recorded $0.5 million, $0.4 million, and $0.7 million of allowance for borrowed funds used during construction and zero, zero, and $0.6 million of allowance for equity funds used during construction.

Capitalized Interest

The Company capitalizes interest on its construction projects and major computer software projects not subject to the computation of AFUDC. Interest was capitalized at the overall weighted average borrowing rate of 6.6%, 6.9%, and 6.6% for 2014, 2013, and 2012. In 2014, 2013, and 2012, capitalized interest was $1.6 million, $1.5 million, and $1.2 million for PNMR consolidated; $1.1 million, $1.1 million, and $0.8 million for PNM; and $0.1 million, zero, and zero for TNMP.

Materials, Supplies, and Fuel Stock

Materials and supplies relate to transmission, distribution, and generating assets. Materials and supplies are charged to inventory when purchased and are expensed or capitalized as appropriate when issued. Materials and supplies are valued using an average costing method.

Coal is valued using a rolling weighted average costing method that is updated based on the current period cost per ton. Periodic aerial surveys are performed on the coal piles and adjustments are made.

B- 34

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

Inventories consisted of the following at December 31:

	PNMR				PNM				TNMP
	2014		2013		2014		2013		2014		2013
	(In thousands)
Coal	$	17,525	$	24,872	$	17,525	$	24,872	$	—	$	—
Materials and supplies	46,103		42,351		43,334		39,648		2,769		2,703
	$	63,628	$	67,223	$	60,859	$	64,520	$	2,769	$	2,703

Investments

In 1985 and 1986, PNM entered into eleven operating leases for interests in certain PVNGS generation facilities (Note 7). The 10.3% and 10.15% lessor notes that were issued by the owners of the assets subject to these leases were subsequently purchased and held by the PVNGS Capital Trust, which is consolidated by PNM. Eight leases continue and are classified as operating leases. The PVNGS Capital Trust held certain of the lessor notes to their maturity in January 2015 and intends to hold the other lessor notes until their maturity in 2016. The PVNGS lessor notes are carried at amortized cost. Similarly, in 1985, PNM entered into two operating leases for the EIP transmission line for which the owners had issued lessor notes. In 2003, PNM acquired a 60% ownership interest in the EIP, collapsing the lease relating to it. In 2004, PNM purchased the outstanding lessor note relating to the remaining 40% interest. The remaining EIP lessor note bore interest at 10.25% and matured in 2012.

PNM holds investment securities in the NDT for the purpose of funding its share of the decommissioning costs of PVNGS and, beginning in August 2012, a trust for PNM’s share of post-term reclamation costs related to the coal mines serving SJGS (Note 16). All of these investments are classified as available-for-sale. PNM evaluates the securities for impairment on an on-going basis. Since third party investment managers have sole discretion over the purchase and sales of the securities, PNM records a realized loss as an impairment for any security that has a market value that is less than cost at the end of each quarter. For the years ended December 31, 2014, 2013, and 2012, PNM recorded impairment losses on the available-for-sale securities held in the NDT and coal mine reclamation trust of $4.8 million, $3.5 million, and $4.8 million. No gains or losses are deferred as regulatory assets or liabilities. Unrealized gains on these investments, net of related tax effects, are included in OCI and AOCI. The available-for-sale securities are primarily comprised of international, United States, state, and municipal government obligations and corporate debt and equity securities. All investments are held in PNM’s name and are in the custody of major financial institutions. The specific identification method is used to determine the cost of securities disposed of, with realized gains and losses reflected in other income and deductions.

Goodwill

Under GAAP, the Company does not amortize goodwill. Goodwill is evaluated for impairment annually, or more frequently if events and circumstances indicate that the goodwill might be impaired. See Note 21.

Asset Impairment

Tangible long-lived assets are evaluated in relation to the estimated future undiscounted cash flows to assess recoverability when events and circumstances indicate that the assets might be impaired.

Revenue Recognition

Electric operating revenues are recorded in the period of energy delivery, which includes estimated amounts for service rendered but unbilled at the end of each accounting period. The determination of the energy sales to individual customers is based on the reading of their meters, which occurs on a systematic basis throughout the month. At the end of each month, amounts of energy delivered to customers since the date of the last meter reading and the corresponding unbilled revenue are estimated. Unbilled electric revenue is estimated based on the daily generation volumes, estimated customer usage by class, weather factors, line losses, and applicable customer rates reflecting historical trends and experience.

PNM’s wholesale electricity sales are recorded as electric operating revenues and the wholesale electricity purchases are recorded as costs of energy sold. In accordance with GAAP, derivative contracts that are net settled or “booked-out” are recorded

B- 35

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

net in earnings. A book-out is the planned or unplanned netting of off-setting purchase and sale transactions. A book-out is a transmission mechanism to reduce congestion on the transmission system or administrative burden. For accounting purposes, a book-out is the recording of net revenues upon the settlement of a derivative contract.

Unrealized gains and losses on contracts that do not qualify for the normal purchases or normal sales exception or are not designated for hedge accounting are classified as economic hedges. Economic hedges are defined as derivative instruments, including long-term power and fuel supply agreements, used to hedge generation assets and purchased power costs. Changes in the fair value of economic hedges are reflected in results of operations, with changes related to economic hedges on sales included in operating revenues and changes related to economic hedges on purchases included in cost of energy sold.

Accounts Receivable and Allowance for Uncollectible Accounts

Accounts receivable consists primarily of trade receivables from customers. In the normal course of business, credit is extended to customers on a short-term basis. The Company calculates the allowance for uncollectible accounts based on historical experience and estimated default rates. The accounts receivable balances are reviewed monthly and adjustments to the allowance for uncollectible accounts and bad debt expense are made as necessary. Amounts that are deemed uncollectible are written off.

Depreciation and Amortization

PNM’s provision for depreciation and amortization of utility plant, other than nuclear fuel, is based upon composite straight-line rates approved by the NMPRC. Amortization of nuclear fuel is based on units-of-production. TNMP’s provision for depreciation and amortization of utility plant is based upon straight-line rates approved by the PUCT. Depreciation of non-utility property is computed based on the straight-line method. The provision for depreciation of certain equipment is allocated between operating expenses and construction projects based on the use of the equipment. Average straight-line rates used were as follows:

	Year ended December 31
	2014		2013		2012
PNM
Electric plant	2.26	%	2.27	%	2.25	%
Common, intangible, and general plant	4.64	%	4.87	%	5.35	%
TNMP	3.59	%	3.66	%	3.56	%

Amortization of Debt Acquisition Costs

Discount, premium, and expense related to the issuance of long-term debt are amortized over the lives of the respective issues. Gains and losses incurred upon the early retirement of long-term debt are recognized in other income or other deductions, except for amounts attributable to NMPRC, FERC, or PUCT regulation, which are recorded as regulatory assets or liabilities and amortized over the lives of the respective issues.

Derivatives

The Company records derivative instruments, including energy contracts, other than those designated as normal purchases or normal sales, in the balance sheet as either an asset or liability measured at their fair value. GAAP requires that changes in the derivatives’ fair value be recognized currently in earnings unless specific hedge accounting or normal purchase or normal sale criteria are met. Normal purchases and normal sales are not marked to market and are reflected in results of operations when the underlying transactions settle. For qualifying hedges, an entity must formally document, designate, and assess the effectiveness of transactions that receive hedge accounting. GAAP provides that the effective portion of the gain or loss on a derivative instrument designated and qualifying as a cash flow hedging instrument be reported as a component of AOCI and be reclassified into earnings in the period during which the hedged forecasted transaction affects earnings. The results of hedge ineffectiveness and the portion of the change in fair value of a derivative that an entity has chosen to exclude from hedge effectiveness are required to be presented in current earnings. See Note 8.

The Company treats all forward electric purchases and sales contracts subject to unplanned netting or book-out by the transmission provider as derivative instruments subject to mark-to-market accounting, unless the contract qualifies for the normal exception by meeting the definition of a capacity contract. Under this definition, the contract cannot permit net settlement, the

B- 36

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

seller must have the resources to serve the contract, and the buyer must be a load serving entity. GAAP provides guidance on whether realized gains and losses on derivative contracts not held for trading purposes should be reported on a net or gross basis and concludes such classification is a matter of judgment that depends on the relevant facts and circumstances. 

Decommissioning and Reclamation Costs

PNM owns and leases nuclear and fossil-fuel generating facilities. In accordance with GAAP, PNM is only required to recognize and measure decommissioning liabilities for tangible long-lived assets for which a legal obligation exists. Nuclear decommissioning costs and related accruals are based on periodic site-specific estimates of the costs for removing all radioactive and other structures at PVNGS and are dependent upon numerous assumptions, including estimates of future decommissioning costs at current price levels, inflation rates, and discount rates. PNM’s accruals for PVNGS Units 1, 2, and 3, including portions held under leases, have been made based on such estimates, the guidelines of the NRC, and the extended PVNGS license periods. PVNGS Units 1 and 2 are included in PNM’s retail rates while PVNGS Unit 3 is currently excluded. PNM collects a provision for ultimate decommissioning of PVNGS Units 1 and 2 and its fossil-fueled generation facilities in its rates and recognizes a corresponding expense and liability for these amounts. See Note 15 and Note 16.

In connection with both the SJGS coal agreement and the Four Corners fuel agreement, the owners are required to reimburse the mining companies for the cost of contemporaneous reclamation, as well as the costs for final reclamation of the coal mines. The reclamation costs are based on periodic site-specific studies that estimate the costs to be incurred in the future and are dependent upon numerous assumptions, including estimates of future reclamation costs at current price levels, inflation rates, and discount rates. PNM considers the contemporaneous reclamation costs part of the cost of its delivered coal costs. See Note 16 for a discussion of the final reclamation costs.

Environmental Costs

The normal operations of the Company involve activities and substances that expose the Company to potential liabilities under laws and regulations protecting the environment. Liabilities under these laws and regulations can be material and in some instances may be imposed without regard to fault, or may be imposed for past acts, even though the past acts may have been lawful at the time they occurred.

The Company records its environmental liabilities when site assessments or remedial actions are probable and a range of reasonably likely cleanup costs can be estimated. The Company reviews its sites and measures the liability by assessing a range of reasonably likely costs for each identified site using currently available information and the probable level of involvement and financial condition of other potentially responsible parties. These estimates are based on assumptions regarding the costs for site investigations, remediation, operations and maintenance, monitoring, and site closure. The ultimate cost to clean up the Company’s identified sites may vary from its recorded liability due to numerous uncertainties inherent in the estimation process. Amounts recorded for environmental expense in the years ended December 31, 2014, 2013, and 2012, as well as the amounts of environmental liabilities at December 31, 2014 and 2013 were insignificant.

Pension and Other Postretirement Benefits

See Note 12 for a discussion of pension and postretirement benefits expense, including a discussion of the actuarial assumptions.

Stock-Based Compensation

See Note 13 for a discussion of stock-based compensation expense.

Income Taxes

Income taxes are recognized using the asset and liability method of accounting for income taxes. Deferred tax assets and liabilities are recognized for the estimated future tax consequences attributable to differences between the financial statement carrying value of existing assets and liabilities and their respective tax basis. Current NMPRC, FERC, and PUCT approved rates include the tax effects of the majority of these differences. GAAP requires that rate-regulated enterprises record deferred income taxes for temporary differences accorded flow-through treatment at the direction of a regulatory commission. The resulting deferred tax assets and liabilities are recorded at the expected cash flow to be reflected in future rates. Because the NMPRC, FERC, and

B- 37

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

the PUCT have consistently permitted the recovery of tax effects previously flowed-through earnings, the Company has established regulatory liabilities and assets offsetting such deferred tax assets and liabilities. The Company recognizes only the impact of tax positions that, based on their merits, are more likely than not to be sustained upon an IRS audit. The Company defers investment tax credits related to rate regulated assets and amortizes them over the estimated useful lives of those assets. See Note 11.

The Company makes an estimate of its anticipated effective tax rate for the year as of the end of each quarterly period within its fiscal year. Year-to-date income tax expense is then calculated by applying the anticipated annual effective tax rate to year-to-date earnings before taxes, which includes the earnings attributable to the Valencia non-controlling interest. GAAP also provides that certain unusual or infrequently occurring items, as well as adjustments due to enactment of new tax laws, be excluded from the estimated annual effective tax rate calculation.

Excise Taxes

The Company pays certain fees or taxes which are either considered to be an excise tax or similar to an excise tax. Substantially all of these taxes are recorded on a net basis in the Consolidated Statements of Earnings.

New Accounting Pronouncements

Information concerning recently issued accounting pronouncements that have not been adopted by the Company is presented below.

Accounting Standards Update 2014-09 – Revenue from Contracts with Customers (Topic 606)

On May 28, 2014, the FASB issued ASU No. 2014-09. The core principle of the guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The new standard will replace most existing revenue recognition guidance in GAAP when it becomes effective. The new standard is effective for the Company beginning on January 1, 2017. Early adoption is not permitted. The standard permits the use of either the retrospective or cumulative effect transition method. The Company is analyzing the impacts this new standard will have on its consolidated financial statements and related disclosures. The Company has not yet selected a transition method nor has it determined the effect of the standard on its ongoing financial reporting.

Accounting Standards Update 2014-15 – Presentation of Financial Statements – Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern

On August 27, 2014, the FASB issued ASU No. 2014-15, which requires management to evaluate whether there is substantial doubt about a company’s ability to continue as a going concern in connection with the preparation of financial statements for each annual and interim reporting period. Disclosure requirements associated with management’s evaluation are also outlined in the new guidance. The new standard is effective for the Company for reporting periods ending after December 15, 2016, with early adoption permitted. The Company is in the process of analyzing the impacts of this new standard.

(2) Segment Information

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

PNM

PNM includes the retail electric utility operations of PNM that are subject to traditional rate regulation by the NMPRC. PNM provides integrated electricity services that include the generation, transmission, and distribution of electricity for retail electric customers in New Mexico. PNM also includes the generation and sale of electricity into the wholesale market, as well as providing transmission services to third parties. The sale of electricity includes the asset optimization of PNM’s jurisdictional assets as well as the capacity excluded from retail rates. FERC has jurisdiction over wholesale and transmission rates.

B- 38

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

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

2014	PNM			TNMP			Corporate and Other			Consolidated
	(In thousands)
Electric operating revenues	$	1,147,914		$	287,939		$	—		$	1,435,853
Cost of energy	403,626			67,930			—			471,556
Margin	744,288			220,009			—			964,297
Other operating expenses	422,051			84,365			(14,450		)	491,966
Depreciation and amortization	109,524			50,056			13,054			172,634
Operating income	212,713			85,588			1,396			299,697
Interest income	8,557			—			(74		)	8,483
Other income (deductions)	12,258			2,138			(2,302		)	12,094
Interest charges	(79,442		)	(27,396		)	(12,789		)	(119,627		)
Segment earnings (loss) before income taxes	154,086			60,330			(13,769		)	200,647
Income taxes (benefit)	52,633			22,523			(5,418		)	69,738
Segment earnings (loss)	101,453			37,807			(8,351		)	130,909
Valencia non-controlling interest	(14,127		)	—			—			(14,127		)
Subsidiary preferred stock dividends	(528		)	—			—			(528		)
Segment earnings (loss) attributable to PNMR	$	86,798		$	37,807		$	(8,351	)	$	116,254
Gross property additions	$	316,800		$	127,191		$	16,667		$	460,658
At December 31, 2014:
Total Assets	$	4,473,652		$	1,240,241		$	115,432		$	5,829,325
Goodwill	$	51,632		$	226,665		$	—		$	278,297

B- 39

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

2013	PNM			TNMP			Corporate and Other			Consolidated
Electric operating revenues	$	1,116,312		$	271,611		$	—		$	1,387,923
Cost of energy	374,710			57,606			—			432,316
Margin	741,602			214,005			—			955,607
Other operating expenses	428,591			91,601			(18,308		)	501,884
Depreciation and amortization	103,826			50,219			12,836			166,881
Operating income	209,185			72,185			5,472			286,842
Interest income	10,182			—			(139		)	10,043
Other income (deductions)	11,288			1,919			(13,575		)	(368		)
Interest charges	(79,175		)	(27,393		)	(14,880		)	(121,448		)
Segment earnings (loss) before income taxes	151,480			46,711			(23,122		)	175,069
Income taxes (benefit)	48,804			17,621			(6,912		)	59,513
Segment earnings (loss)	102,676			29,090			(16,210		)	115,556
Valencia non-controlling interest	(14,521		)	—			—			(14,521		)
Subsidiary preferred stock dividends	(528		)	—			—			(528		)
Segment earnings (loss) attributable to PNMR	$	87,627		$	29,090		$	(16,210	)	$	100,507
Gross property additions	$	239,906		$	89,117		$	19,016		$	348,039
At December 31, 2013:
Total Assets	$	4,227,616		$	1,162,431		$	110,163		$	5,500,210
Goodwill	$	51,632		$	226,665		$	—		$	278,297

B- 40

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

2012	PNM			TNMP			Corporate and Other			Consolidated
Electric operating revenues	$	1,092,264		$	250,140		$	(1	)	$	1,342,403
Cost of energy	353,649			46,201			—			399,850
Margin	738,615			203,939			(1		)	942,553
Other operating expenses	435,442			87,079			(17,862		)	504,659
Depreciation and amortization	97,291			49,340			17,542			164,173
Operating income	205,882			67,520			319			273,721
Interest income	13,243			1			(172		)	13,072
Gain on sale of First Choice	—			—			1,012			1,012
Other income (deductions)	13,290			2,739			(7,954		)	8,075
Interest charges	(76,101		)	(28,161		)	(16,583		)	(120,845		)
Segment earnings (loss) before income taxes	156,314			42,099			(23,378		)	175,035
Income taxes (benefit)	50,713			15,352			(11,155		)	54,910
Segment earnings (loss)	105,601			26,747			(12,223		)	120,125
Valencia non-controlling interest	(14,050		)	—			—			(14,050		)
Subsidiary preferred stock dividends	(528		)	—			—			(528		)
Segment earnings (loss) attributable to PNMR	$	91,023		$	26,747		$	(12,223	)	$	105,547
Gross property additions	$	196,800		$	92,973		$	19,136		$	308,909
At December 31, 2012:
Total Assets	$	4,163,907		$	1,086,229		$	122,447		$	5,372,583
Goodwill	$	51,632		$	226,665		$	—		$	278,297

Major Customers

No individual customer accounted for more than 10% of the electric operating revenues of PNMR or PNM. The acquiror of First Choice, including the former First Choice operations, accounted for 15% and 17% of TNMP’s electric operating revenues in 2014 and 2013. Two other unaffiliated customers of TNMP accounted for revenues of 15% in 2014, 16% in 2013, and 17% in 2012 and 11% in 2014, 10% in 2013, and 10% in 2012.

(3) Sale of First Choice

PNMR completed the sale of First Choice, which was also a subsidiary of TNP, on November 1, 2011. First Choice was a competitive REP operating in Texas. The amount received was subject to adjustment based on the actual amounts of the components of working capital at October 31, 2011. In 2012, PNMR received an additional amount and recorded a pre-tax gain of $1.0 million, which is included in Other income in the Consolidated Statements of Earnings. PNMR Services Company continued to provide certain services at cost to First Choice for a transitional period through August 1, 2012. Because PNMR continues to have direct cash flows resulting from transmission and distribution services provided by TNMP to First Choice, First Choice is not reflected as discontinued operations.

(4)     Regulatory Assets and Liabilities

The operations of PNM and TNMP are regulated by the NMPRC, PUCT, and FERC and the provisions of GAAP for rate-regulated enterprises are applied to its regulated operations. Regulatory assets represent probable future recovery of previously incurred costs that will be collected from customers through the ratemaking process. Regulatory liabilities represent probable future reductions in revenues associated with amounts that are to be credited to customers through the ratemaking process. Regulatory assets and liabilities reflected in the Consolidated Balance Sheets are presented below.

B- 41

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

PNM

	December 31,
	2014			2013
Assets:	(In thousands)
Current:
FPPAC	$	43,980		$	19,394
Non-Current:
Coal mine reclamation costs	34,224			40,144
Deferred income taxes	63,645			61,850
Loss on reacquired debt	25,439			27,490
Pension and OPEB	222,545			206,691
FPPAC	—			25,386
Renewable energy costs	5,263			13,311
Other	5,929			9,345
	357,045			384,217
Total regulatory assets	$	401,025		$	403,611
Liabilities:
Current:
Other	$	(1,703	)	$	(1,081	)
Non-Current:
Cost of removal	(277,148		)	(266,075		)
Deferred income taxes	(75,941		)	(80,495		)
AROs	(35,834		)	(37,567		)
Renewable energy tax benefits	(24,854		)	(26,011		)
Other	(11,704		)	(4,463		)
	(425,481		)	(414,611		)
Total regulatory liabilities	$	(427,184	)	$	(415,692	)

B- 42

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

TNMP

	December 31,
	2014			2013
Assets:	(In thousands)
Current:
Transmission cost recovery factor	$	2,482		$	4,250
Other	1,393			772
	3,875			5,022
Non-Current:
CTC, including carrying charges	55,292			63,606
Deferred income taxes	10,556			10,868
Pension	23,803			19,938
Loss on reacquired debt	36,703			38,616
AMS retirement costs	6,453			5,083
Other	1,155			1,627
	133,962			139,738
Total regulatory assets	$	137,837		$	144,760
Liabilities:
Non-Current:
Cost of removal	$	(29,391	)	$	(30,863	)
Deferred income taxes	(3,923		)	(4,563		)
AMS surcharge	(5,227		)	(7,251		)
OPEB	(2,121		)	(3,361		)
Total regulatory liabilities	$	(40,662	)	$	(46,038	)

The Company’s regulatory assets and regulatory liabilities are reflected in rates charged to customers or have been addressed in a regulatory proceeding. The Company does not receive or pay a rate of return on the following regulatory assets and regulatory liabilities (and their remaining amortization periods): coal mine reclamation costs (through 2020); deferred income taxes (over the remaining life of the taxable item, up to the remaining life of utility plant); pension and OPEB costs (through 2033); and AROs (to be determined in a future regulatory proceeding). In addition, TNMP does not receive a return on substantially all of its loss on reacquired debt (through 2043).

The Company is permitted, under rate regulation, to accrue and record a regulatory liability for the estimated cost of removal and salvage associated with certain of its assets through depreciation expense. Under GAAP, actuarial losses and prior service costs for pension plans are required to be recorded in AOCI; however, to the extent authorized for recovery through the regulatory process these amounts are recorded as regulatory assets or liabilities. Based on prior regulatory approvals, the amortization of these amounts will be included in the Company’s rates.

Based on a current evaluation of the various factors and conditions that are expected to impact future cost recovery, the Company believes that future recovery of its regulatory assets are probable.

(5) Stockholders’ Equity

Common Stock and Equity Contributions

PNMR, PNM, and TNMP did not issue any common stock during the three year period ended December 31, 2014. PNMR funded a cash equity contribution of $13.8 million to TNMP in 2013. PNMR offers shares of PNMR common stock through the PNMR Direct Plan. PNMR utilizes shares of its common stock purchased on the open market, by an independent agent, rather than issuing additional shares to satisfy subscriptions under the PNMR Direct Plan. The shares of PNMR common stock utilized in the PNMR Direct Plan are offered under a SEC shelf registration statement that expires in August 2015.

B- 43

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

Dividends on Common Stock

The declaration of common dividends by PNMR is dependent upon a number of factors, including the ability of PNMR’s subsidiaries to pay dividends. PNMR’s primary sources of dividends are its operating subsidiaries.

PNM declared and paid cash dividends to PNMR of $30.3 million, $155.0 million, and $34.4 million in 2014, 2013, and 2012. TNMP paid cash dividends to PNMR of $16.3 million, $3.7 million, and $26.0 million in 2014, 2013, and 2012. TNMP recorded dividends paid in 2012 as reductions of paid-in-capital.

The NMPRC has placed certain restrictions on the ability of PNM to pay dividends to PNMR, including the restriction that PNM cannot pay dividends that cause its debt rating to fall below investment grade. The NMPRC provisions allow PNM to pay dividends from equity contributions previously made by PNMR and current earnings, determined on a rolling four quarter basis, without prior NMPRC approval. The Federal Power Act also imposes certain restrictions on dividends by public utilities. Each of the PNMR Revolving Credit Facility, PNMR Term Loan Agreement, PNM Revolving Credit Facility, PNM New Mexico Credit Facility, PNM 2014 Term Loan Agreement, PNM Multi-draw Term Loan, and TNMP Revolving Credit Facility contain a covenant requiring the maintenance of debt-to-capital ratios of not more than 65%, which could limit amounts of dividends that could be paid. For PNMR and PNM, these ratios reflect the present value of payments under the PVNGS leases as debt. PNM also has other financial covenants that limit the transfer of assets, through dividends or other means, including a requirement to obtain approval of certain financial counterparties to transfer more than five percent of PNM’s assets. As of December 31, 2014, none of the numerical tests would restrict the payment of dividends from the retained earnings of PNMR, PNM, or TNMP, except that PNM would not be able to distribute amounts in excess of approximately $223 million and TNMP would not be able to distribute amounts in excess of approximately $203 million without approval of regulators or financial counterparties.

In addition, the ability of PNMR to declare dividends is dependent upon the extent to which cash flows will support dividends, the availability of retained earnings, financial circumstances and performance, current and future regulatory decisions, Congressional and legislative acts, and economic conditions. Conditions imposed by the NMPRC or PUCT, future growth plans and related capital requirements, and business considerations may also affect PNMR’s ability to pay dividends.

Preferred Stock

PNM’s cumulative preferred shares outstanding bear dividends at 4.58% per annum. PNM preferred stock does not have a mandatory redemption requirement but may be redeemed, at PNM’s option, at 102% of the stated value plus accrued dividends. The holders of the PNM preferred stock are entitled to payment before the holders of common stock in the event of any liquidation or dissolution or distribution of assets of PNM. In addition, PNM’s preferred stock is not entitled to a sinking fund and cannot be converted into any other class of stock of PNM.

PNMR and TNMP have no preferred stock outstanding. The authorized shares of PNMR and TNMP preferred stock are 10 million shares and 1 million shares.

(6) Financing

Financing Activities

PNMR

In the year ended December 31, 2013, PNMR purchased $23.8 million aggregate principal amount of its outstanding 9.25% Senior Unsecured Notes, Series A, due 2015, through several open-market purchases, for $26.9 million plus accrued and unpaid interest. PNMR recognized losses of $3.3 million on these purchases, including transaction costs and write-off of the proportionate amount of the deferred costs of the original issuance of the notes, which are included in Other deductions on the Consolidated Statements of Earnings.

On December 14, 2012, PNMR entered into a $100.0 million Term Loan Agreement (as amended and restated, the “PNMR Term Loan Agreement”) among PNMR, the lenders identified therein, and JPMorgan Chase Bank, N.A., as Administrative Agent. On December 27, 2012, PNMR borrowed $100.0 million under the agreement and used the funds to repay $100.0 million in borrowings made under the PNMR Revolving Credit Facility. On December 27, 2013, PNMR entered into an agreement that amended and restated the PNMR Term Loan Agreement extending the maturity date to December 26, 2014 from December 27,

B- 44

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

2013. On December 22, 2014, PNMR entered into another agreement that amends and restates the PNMR Term Loan Agreement extending the maturity date to December 21, 2015. The PNMR 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 PNMR Term Loan Agreement has a cross default provision and a change of control provision.

PNM

In September 2012, PNM participated in the issuance of $20.0 million of new PCRBs by the City of Farmington, New Mexico, which bear interest at 2.54% and mature September 1, 2042, with a mandatory tender on June 1, 2017. The new PCRBs refunded a $20.0 million series of PCRBs, which bore interest at 5.15% and matured in 2037, that were redeemed at par and retired.

On April 22, 2013, PNM entered into a $75.0 million Term Loan Agreement (the “PNM 2013 Term Loan Agreement”) among PNM, the lenders identified therein, and Union Bank, N.A., as Administrative Agent. Funding of the PNM 2013 Term Loan Agreement occurred on April 22, 2013, at which time the funds were used to repay $75.0 million in borrowings made under 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 the PNM 2013 Term Loan Agreement. PNM also used the funds to repay other short-term amounts outstanding. The PNM 2013 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 2013 Term Loan Agreement. The PNM 2014 Term Loan Agreement bears interest at a variable rate, which was 1.11% at December 31, 2014, must be repaid on or before September 4, 2015, and is reflected in current maturities of long-term debt on the Consolidated Balance Sheets. The PNM 2014 Term Loan Agreement includes customary covenants, including requirements to not exceed a maximum consolidated debt-to-capital ratio and customary events of default. The PNM 2014 Term Loan Agreement has a cross default provision and a change of control provision.

On December 22, 2014, PNM entered into a new multi-draw term loan facility (the “PNM Multi-draw Term Loan”) with JPMorgan Chase Bank, N.A., as Lender and Administrative Agent. The $125.0 million facility has a maturity date of June 21, 2016. At December 31, 2014, outstanding borrowings under the PNM Multi-draw Term Loan were $100.0 million and remaining capacity was $25.0 million. The PNM Multi-draw Term Loan bears interest at a variable rate, which was 0.75% at December 31, 2014. The PNM Multi-draw Term Loan includes customary covenants, including requirements to not exceed a maximum consolidated debt-to-consolidated capitalization ratio and customary events of default. The PNM Multi-draw Term Loan Agreement has a cross default provision and a change of control provision.

PNM has a shelf registration statement for the issuance of up to $500.0 million of senior unsecured notes that will expire in May 2017.

TNMP

On September 30, 2011, TNMP entered into the TNMP 2011 Term Loan Agreement and borrowed $50.0 million under it. Borrowings under the TNMP 2011 Term Loan Agreement were due by June 30, 2014. TNMP entered into hedging agreements whereby it effectively established fixed interest rates for such borrowing over the life of the debt. This hedge was accounted for as a cash-flow hedge and had a fair value loss of $0.2 million at December 31, 2013, using Level 2 inputs under GAAP determined using forward LIBOR curves under the mid-market convention to discount cash flows over the remaining term of the swap agreements.

On March 6, 2013, TNMP commenced an offer to exchange any and all of TNMP’s $265.5 million aggregate principal amount outstanding 9.50% First Mortgage Bonds, due 2019, Series 2009A, for a new series of 6.95% First Mortgage Bonds, due 2043, Series 2013A, and up to $140 in cash for each $1,000 of bonds exchanged. Settlement of the exchange offer occurred on April 3, 2013. Upon settlement, TNMP issued $93.2 million of 6.95% First Mortgage Bonds and paid an aggregate of $13.0 million in cash in exchange for $93.2 million of 9.50% First Mortgage Bonds, in addition to payment of accrued and unpaid interest on the exchanged bonds. The exchange resulted in a premium on the 6.95% First Mortgage Bonds reflecting the contractual interest rate being in excess of the market rate of interest on the date of the exchange. The premium amounted to $23.2 million, after reduction for the cash paid in the exchange. A regulatory asset was recorded offsetting the premium, including the cash consideration paid in the exchange.

B- 45

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

On December 9, 2013, TNMP entered into an agreement (the “TNMP 2013 Bond Purchase Agreement”), which provided that TNMP would issue $80.0 million aggregate principal amount of 4.03% first mortgage bonds, due 2024 (the “Series 2014A Bonds”) on or about June 27, 2014, subject to satisfaction of certain conditions. TNMP issued the Series 2014A Bonds on June 27, 2014. TNMP used $50.0 million of the proceeds to repay the full outstanding amount of the TNMP 2011 Term Loan Agreement and used the remaining $30.0 million of proceeds to reduce short-term debt. In accordance with GAAP, borrowings under the TNMP 2011 Term Loan Agreement were reflected as being long-term in the Consolidated Balance Sheet at December 31, 2013 since the TNMP 2013 Bond Purchase Agreement demonstrated TNMP’s ability and intent to re-finance the TNMP 2011 Term Loan Agreement on a long-term basis.

Short-term Debt

The PNMR Revolving Credit Facility has a financing capacity of $300.0 million and the PNM Revolving Credit Facility has a financing capacity of $400.0 million. In December 2014, both of these facilities were amended to extend their maturity from October 31, 2018 to October 31, 2019. In addition, the amendments provide for an additional one-year extension option for each facility, subject to approval by a majority of the lenders. The TNMP Revolving Credit Facility is a $75.0 million revolving credit facility secured by $75.0 million aggregate principal amount of TNMP first mortgage bonds. The TNMP Revolving Credit Facility matures on September 18, 2018. Each of these 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 leases as debt.

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.

At December 31, 2014, interest rates on outstanding borrowings were 1.02% for the PNMR Term Loan Agreement (discussed under Financing Activities above), 1.67% for the PNMR Revolving Credit Facility, and 1.17% for the TNMP Revolving Credit Facility. The PNM Revolving Credit Facility and the PNM New Mexico Credit Facility had no borrowings outstanding at December 31, 2014. Short-term debt outstanding consists of:

	December 31,
Short-term Debt	2014		2013
	(In thousands)
PNM:
Revolving Credit Facility	$	—	$	49,200
PNM New Mexico Credit Facility	—		—
TNMP Revolving Credit Facility	5,000		—
PNMR
Revolving Credit Facility	600		—
PNMR Term Loan Agreement	100,000		100,000
	$	105,600	$	149,200

In addition to the above borrowings, PNMR, PNM, and TNMP had letters of credit outstanding of $7.7 million, $3.2 million, and $0.1 million at December 31, 2014 that reduce the available capacity under their respective revolving credit facilities.

At February 20, 2015, PNMR, PNM, and TNMP had $291.5 million, $386.8 million, and $54.9 million of availability under their respective revolving credit facilities, including reductions of availability due to outstanding letters of credit, and PNM had $35.0 million of availability under the PNM New Mexico Credit Facility. Total availability at February 20, 2015, on a consolidated basis, was $768.2 million for PNMR. At February 20, 2015, PNMR had invested cash of $1.9 million, PNM had invested cash of $42.5 million, and TNMP had no invested cash. The above availability does not include remaining capacity of $25.0 million available under the PNM Multi-draw Term Loan at February 20, 2015.

B- 46

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

Long-Term Debt

Information concerning long-term debt outstanding is as follows:

	December 31,
Long-term Debt	2014			2013
	(In thousands)
PNM Debt
Senior Unsecured Notes, Pollution Control Revenue Bonds:
4.875% due 2033	$	146,000		$	146,000
6.25% due 2038	36,000			36,000
4.75% due 2040, mandatory tender at June 1, 2017	37,000			37,000
5.20% due 2040, mandatory tender at June 1, 2020	40,045			40,045
5.90% due 2040	255,000			255,000
6.25% due 2040	11,500			11,500
2.54% due 2042, mandatory tender at June 1, 2017	20,000			20,000
4.00% due 2043, mandatory tender at June 1, 2015	39,300			39,300
5.20% due 2043, mandatory tender at June 1, 2020	21,000			21,000
Senior Unsecured Notes:
7.95% due 2018	350,000			350,000
7.50% due 2018	100,025			100,025
5.35% due 2021	160,000			160,000
PNM Term Loan Agreement due 2014	—			75,000
PNM Term Loan Agreement due 2015	175,000			—
PNM Multi-draw Term Loan due 2016	100,000			—
Unamortized premiums (discounts)	(213		)	(252		)
	1,490,657			1,290,618
Less current maturities	214,300			75,000
	1,276,357			1,215,618
TNMP Debt
First Mortgage Bonds:
2011 Term Loan Agreement, due 2014	—			50,000
9.50% due 2019, Series 2009A	172,302			172,302
6.95% due 2043, Series 2013A	93,198			93,198
4.03% due 2024, Series 2014A	80,000			—
Unamortized premiums (discounts)	20,167			20,536
	365,667			336,036
Less current maturities	—			—
	365,667			336,036
PNMR Debt
Senior unsecured notes, 9.25% due 2015	118,766			118,766
Less current maturities	118,766			—
	—			118,766
Total Consolidated PNMR Debt	1,975,090			1,745,420
Less current maturities	333,066			75,000
	$	1,642,024		$	1,670,420

B- 47

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

Reflecting mandatory tender dates, long-term debt matures as follows:

	PNMR		PNM		TNMP		PNMR Consolidated
	(In thousands)
2015	$	118,766	$	214,300	$	—	$	333,066
2016	—		100,000		—		100,000
2017	—		57,000		—		57,000
2018	—		450,025		—		450,025
2019	—		—		172,302		172,302
Thereafter	—		669,545		173,198		842,743
Total	$	118,766	$	1,490,870	$	345,500	$	1,955,136

Borrowing Arrangements Between PNMR and its Subsidiaries

PNMR has one-year intercompany loan agreements with its subsidiaries. Individual subsidiary loan agreements vary in amount up to $100.0 million and have either reciprocal or non-reciprocal terms. Interest charged to the subsidiaries is equivalent to interest paid by PNMR on its short-term borrowings. As of December 31, 2014 and 2013, PNM had outstanding borrowings of zero and $32.5 million and TNMP had outstanding borrowings of $22.7 million and $29.4 million from PNMR. At February 20, 2015, PNM and TNMP had borrowings of zero and $17.3 million from PNMR.

(7) 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. Many of PNM’s electric transmission and distribution facilities are located on lands that require the grant of rights-of-way from governmental entities, Native American tribes, or private parties. PNM has completed several renewals of rights-of-way, the largest of which is a renewal with the Navajo Nation, and has no significant rights-of-way that will expire within the next five years. PNM is obligated to pay the Navajo Nation annual payments of $6.0 million, subject to adjustment each year based on the Consumer Price Index, through 2029. All of the Company’s leases, including the Navajo Nation rights-of-way agreement, are accounted for as operating leases.

The PVNGS leases were entered into in 1985 and 1986 and were scheduled to expire on January 15, 2015 for the four Unit 1 leases and January 15, 2016 for the four Unit 2 leases. Each of the leases provided PNM with an option to purchase the leased assets at fair market value at the end of the leases, but PNM does not have a fixed price purchase option. In addition, the leases provided PNM with options to renew the leases at fixed rates set forth in each of the leases for two years beyond the termination of the original lease terms. The option periods on certain leases could be further extended for up to an additional six years (the “Maximum Option Period”) if the appraised remaining useful lives and fair value of the leased assets are greater than parameters set forth in the leases. The rental payments during the fixed renewal option periods would be 50% of the amounts during the original terms of the leases. Gross annual lease payments, before considering the impacts of amounts returned to PNM through ownership of the lessor notes, aggregate $33.0 million for the Unit 1 leases and $23.7 million for the Unit 2 leases. For leases that are extended, the leases provide PNM with the option to purchase the leased assets at fair market value at the end of the extended lease terms.

Each lease provided that no later than three years prior to the expiration of the lease, PNM was required to give notice to the lessor if it would “retain” the leased assets (but without specifying whether it would purchase the leased assets or extend the lease) or “return” the leased assets to the lessor. Furthermore, each lease provided that, if PNM gave notice to “retain” the leased assets, PNM was required to give notice as to which of the purchase or renewal options it would exercise no later than two years prior to the expiration of the lease. The election made under each of the leases was independent of the elections made under the other 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

B- 48

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

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 January 15, 2024. The annual payments during the renewal periods aggregate $16.5 million for the PVNGS Unit 1 leases and $1.6 million for the Unit 2 lease. The table of future lease payments as of December 31, 2014 shown below includes payments during the renewal periods for those leases that will be extended at the end of their original terms.

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 31.25 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 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 was $79.9 million on June 1, 2014, $81.8 million on December 31, 2014, and escalates 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 was $5.8 million on June 1, 2014, $4.5 million on December 31, 2014, and declines to $1.2 million on January 14, 2016. PNMR and PNM are unable to predict whether or not the early purchase will occur.

Covenants in PNM’s PVNGS Units 1 and 2 lease agreements limit PNM’s ability, without consent of the owner participants in the lease transactions, (i) to enter into any merger or consolidation, or (ii) except in connection with normal dividend policy, to convey, transfer, lease or dividend more than 5% of its assets in any single transaction or series of related transactions. PNM is exposed to losses under the PVNGS lease arrangements upon the occurrence of certain events that PNM does not consider to be reasonably likely to occur. Under certain circumstances (for example, the NRC issuing specified violation orders with respect to PVNGS or the occurrence of specified nuclear events), PNM would be required to make specified payments to the equity participants, and take title to the leased interests. If such an event had occurred as of December 31, 2014, PNM could have been required to pay the equity participants up to approximately $122.2 million on January 15, 2015 in addition to the scheduled lease payments due on January 15, 2015. In such event, PNM would record the acquired assets at the lower of their fair value or the aggregate of the amount paid and PNM’s carrying value of its investment in PVNGS lessor notes. Exercise of renewal options under the leases requires that amounts payable to equity participants under the circumstances described above would increase to the fair market value as of the renewal date. Reflecting the lease renewals that were effective on January 15, 2015, if such an event were to occur, amounts payable to equity participants under the circumstances described above would be up to $217.3 million on July 15, 2015 in addition to the scheduled lease payments due on July 15, 2015.

PNM owns 60% of the EIP and leases the other 40%, under a lease that expires on April 1, 2015. The lease provides PNM the option, with 24 months advance notice, of purchasing the leased assets at the end of the lease for fair market value, as well as options to renew the lease. On November 1, 2012, PNM and the lessor entered into a definitive agreement for PNM to exercise the option to purchase on April 1, 2015 the leased capacity at fair market value, which the parties agreed would be $7.7 million. The lease remains in existence and PNM will record the purchase at the termination of the lease on April 1, 2015. The definitive agreement sets forth the terms and conditions under which PNM would also assume responsibility for scheduling long-term transmission service on the leased capacity.

PNMR leases a building that was used as part of its corporate headquarters, as well as housing certain support functions for the utility operations of PNM and TNMP. The lease expires on November 30, 2015 and provides for annual rents of $1.9

B- 49

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

million, which are included in the tables below. PNMR is also obligated to pay taxes, insurance, and utilities applicable to the building. In November 2011, PNMR notified the lessor of its intent to vacate the building by the end of 2012 and made a settlement offer to terminate the lease. A termination agreement was not reached with the lessor. As of December 31, 2012, PNMR completed the abandonment of this building, as well as the partial abandonment of another leased building. In accordance with GAAP, PNMR recorded an abandonment expense of $7.4 million at December 31, 2012. PNM was allocated $6.2 million and TNMP was allocated $1.2 million of the abandonment expense for the period ended December 31, 2012, which is reflected as administrative and general expense.

Operating lease expense, including the PVNGS and EIP leases, was:

	PNMR		PNM		TNMP
	(In thousands)
2014	$	82,756	$	76,745	$	3,932
2013	$	82,882	$	78,306	$	2,663
2012	$	84,794	$	78,483	$	2,871

As discussed under Investments in Note 1, the PVNGS Capital Trust, which is consolidated by PNM, acquired the lessor notes that were issued by the PVNGS lessors. Future minimum operating lease payments at December 31, 2014 shown below have been reduced by payments on the PVNGS lessor notes of $24.0 million in 2015 and $9.0 million in 2016 that will be returned in cash to PNM:

	PNMR		PNM		TNMP
	(In thousands)
2015	$	36,350	$	33,144	$	1,186
2016	28,892		27,986		636
2017	25,185		24,907		—
2018	25,194		24,907		—
2019	25,203		24,907		—
Later years	134,068		133,842		—
Total minimum lease payments	$	274,892	$	269,693	$	1,822

(8) 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. PNM’s operations are managed primarily through a net asset-backed strategy, whereby PNM’s aggregate net open forward contract position is covered by its forecasted excess generation capabilities or market purchases. PNM could be exposed to market risk if its generation capabilities were to be disrupted or if its load requirements were to be greater than anticipated. If all or a portion of load requirements were required to be covered as a result of such unexpected situations, commitments would have to be met through market purchases.

Commodity Risk

Marketing and procurement of energy often involve market risks associated with managing energy commodities and establishing open positions in the energy markets, primarily on a short-term basis. PNM routinely enters into various derivative

B- 50

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

instruments such as forward contracts, option agreements, and price basis swap agreements to economically hedge price and volume risk on power commitments and fuel requirements and to minimize the effect of market fluctuations in wholesale portfolios. PNM monitors the market risk of its commodity contracts using VaR calculations to maintain total exposure within management-prescribed limits in accordance with approved risk and credit policies.

Accounting for Derivatives

Under derivative accounting and related rules for energy contracts, the Company accounts for its various derivative instruments for the purchase and sale of energy based on the Company’s intent. During the years ended December 31, 2014 and 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
	December 31,
	2014			2013
	(In thousands)
PNM and PNMR
Current assets	$	11,232		$	4,064
Deferred charges	—			3,002
	11,232			7,066
Current liabilities	(1,209		)	(2,699		)
Long-term liabilities	(477		)	(1,094		)
	(1,686		)	(3,793		)
Net	$	9,546		$	3,273

Included in the above table are $3.0 million of current assets at December 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 December 31, 2014 and 2013.

At December 31, 2014 and 2013, PNMR and PNM had no amounts recognized for the legal right to reclaim cash collateral. In addition, at December 31, 2014 and 2013, amounts posted as cash collateral under margin arrangements were $3.8 million and

B- 51

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

$2.8 million for both PNMR and PNM. At December 31, 2014 and 2013, obligations to return cash collateral were $0.2 million and $0.2 million for both PNMR and PNM. Cash collateral amounts are included in other current assets and other current liabilities on the Consolidated Balance Sheets.

PNM has a NMPRC approved hedging plan to manage fuel and purchased power costs related to customers covered by its FPPAC. The table above includes $0.4 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 Consolidated Balance Sheets. At December 31, 2014, there were no hedges in place under this plan.

The following table presents the effect of mark-to-market commodity derivative instruments on earnings, excluding income tax effects. Commodity derivatives had no impact on OCI for the periods presented.

	Economic Hedges
	Year Ended December 31,
	2014		2013		2012
	(In thousands)
PNMR and PNM
Electric operating revenues	$	4,491	$	1,727	$	6,168
Cost of energy	593		1,109		(460		)
Total gain	$	5,084	$	2,836	$	5,708

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
December 31, 2014
PNMR and PNM	650,000	(1,919,000	)
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.

B- 52

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

Contingent Feature – Credit Rating Downgrade	Contractual Liability		Existing Cash Collateral		Net Exposure
	(In thousands)
December 31, 2014
PNMR and PNM	$	1,686	$	—	$	167
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 currently 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 December 31, 2014, PNM had contracted to sell 100% of PVNGS Unit 3 output through 2015, at market price plus a premium.  Through hedging arrangements that are accounted for as economic hedges, PNM has established fixed rates, which average approximately $37 per MWh, for substantially all of these sales.

Non-Derivative Financial Instruments

The carrying amounts reflected on the Consolidated Balance Sheets approximate fair value for cash, receivables, and payables due to the short period of maturity. Available-for-sale securities are carried at fair value. Available-for-sale securities for PNMR and PNM consist of PNM assets held in the NDT for its share of decommissioning costs of PVNGS and, beginning in August 2012, a trust for PNM’s share of post-term reclamation costs related to the coal mines serving SJGS (Note 16). The fair value and gross unrealized gains of investments in available-for-sale securities are presented in the following table. At December 31, 2014 and 2013, the fair value of available-for-sale securities included $244.6 million and $222.5 million for the NDT and $5.5 million and $4.4 million for the mine reclamation trust.

	December 31, 2014				December 31, 2013
	Unrealized  Gains		Fair Value		Unrealized  Gains		Fair Value
PNMR and PNM			(In thousands)
Cash and cash equivalents	$	—	$	8,276	$	—	$	3,356
Equity securities:
Domestic value	17,418		45,340		14,523		39,460
Domestic growth	21,354		74,053		25,656		76,292
International and other	156		16,599		1,040		16,633
Fixed income securities:
U.S. Government	903		22,563		158		21,941
Municipals	5,851		68,973		1,018		58,568
Corporate and other	666		14,341		207		10,605
	$	46,348	$	250,145	$	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 . Gross realized losses shown below exclude the change in realized impairment losses of $(0.7) million, $0.6 million, and $5.2 million.

B- 53

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Proceeds from sales	$	117,989		$	271,140		$	167,330
Gross realized gains	$	15,162		$	14,308		$	15,907
Gross realized (losses)	$	(3,964	)	$	(4,298	)	$	(8,170	)

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 December 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	$	3,946	$	8,019	$	8,019
After 1 year through 5 years	20,275		25,430		24,817
After 5 years through 10 years	13,422		—		—
After 10 years through 15 years	10,367		—		—
After 15 years through 20 years	11,539		—		—
After 20 years	46,328		—		—
	$	105,877	$	33,449	$	32,836

Fair Value Disclosures

The Company determines the fair values of its derivative and other financial instruments based on the hierarchy established in GAAP, which requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. GAAP describes three levels of inputs that may be used to measure fair value. Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities that the reporting entity has the ability to access at the measurement date. Level 2 inputs are inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly. Level 3 inputs are unobservable inputs for the asset or liability. Level 3 inputs used in determining fair values for the Company consist of internal valuation models. The Company records any transfers between fair value hierarchy levels as of the end of each calendar quarter. There were no transfers between levels during the years ended December 31, 2014 and 2013.

For available-for-sale securities, Level 2 fair values are provided by the trustee utilizing a pricing service. The pricing provider predominantly uses the market approach using bid side market value based upon a hierarchy of information for specific securities or securities with similar characteristics. For commodity derivatives, Level 2 fair values are determined based on market observable inputs, which are validated using multiple broker quotes, including forward price, volatility, and interest rate curves to establish expectations of future prices. Credit valuation adjustments are made for estimated credit losses based on the overall exposure to each counterparty. For the Company’s long-term debt, Level 2 fair values are provided by an external pricing service. The pricing service primarily utilizes quoted prices for similar debt in active markets when determining fair value. For investments categorized as Level 3, primarily the PVNGS lessor notes and certain items in other investments, fair values were determined by discounted cash flow models that take into consideration discount rates that are observable for similar types of assets and liabilities. Management of the Company independently verifies the information provided by pricing services.

B- 54

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

Items recorded at fair value on the Consolidated Balance Sheets are presented below by level of the fair value hierarchy. There were no Level 3 fair value measurements at December 31, 2014 and 2013 for items recorded at fair value.

				GAAP Fair Value Hierarchy
	Total			Quoted Prices in Active Market for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)
December 31, 2014				(In thousands)
PNMR and PNM
Available-for-sale securities
Cash and cash equivalents	$	8,276		$	8,276	$	—
Equity securities:
Domestic value	45,340			45,340		—
Domestic growth	74,053			74,053		—
International and other	16,599			16,599		—
Fixed income securities:
U.S. Government	22,563			20,808		1,755
Municipals	68,973			—		68,973
Corporate and other	14,341			4,843		9,498
	$	250,145		$	169,919	$	80,226
Commodity derivative assets	$	11,232		$	—	$	11,232
Commodity derivative liabilities	(1,686		)	—		(1,686		)
Net	$	9,546		$	—	$	9,546

				GAAP Fair Value Hierarchy
	Total			Quoted Prices in Active Market for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)
December 31, 2013				(In thousands)
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

B- 55

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

The carrying amounts and fair values of investments in PVNGS lessor notes, other investments, and long-term debt are presented below:

					GAAP Fair Value Hierarchy
	Carrying Amount		Fair Value		Level 1		Level 2		Level 3
December 31, 2014	(In thousands)
PNMR
Long-term debt	$	1,975,090	$	2,173,117	$	—	$	2,173,117	$	—
Investment in PVNGS lessor notes	$	31,232	$	32,836	$	—	$	—	$	32,836
Other investments	$	1,762	$	2,375	$	639	$	—	$	1,736
PNM
Long-term debt	$	1,490,657	$	1,624,222	$	—	$	1,624,222	$	—
Investment in PVNGS lessor notes	$	31,232	$	32,836	$	—	$	—	$	32,836
Other investments	$	397	$	397	$	397	$	—	$	—
TNMP
Long-term debt	$	365,667	$	427,356	$	—	$	427,356	$	—
Other investments	$	242	$	242	$	242	$	—	$	—
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	$	—	$	—

Investments Held by Employee Benefit Plans

As discussed in Note 12, PNM and TNMP have trusts that hold investment assets for their pension and other postretirement benefit plans. The fair value of the assets held by the trusts impacts the determination of the funded status of each plan, but the assets are not reflected on the Company’s Consolidated Balance Sheets. Both the PNM Pension Plan and the TNMP Pension Plan hold units of participation in the PNM Resources, Inc. Master Trust (the “PNMR Master Trust”), which was established for the investment of assets of the pension plans. Level 2 and Level 3 fair values are provided by fund managers utilizing a pricing service. For level 2 fair values, the pricing provider predominately uses the market approach using bid side market value based upon a hierarchy of information for specific securities or securities with similar characteristics. Level 2 investments in mutual funds are measured at net asset value as year-end. Level 3 investments are comprised of alternative investments, which are measured at net asset value at year-end and include private equity funds, hedge funds, and real estate funds. The private equity funds are not voluntarily redeemable. These investments are realized through periodic distributions occurring over a 10 to 15-year term after the initial investment. The real estate funds and hedge funds may be voluntarily redeemed, but are subject to redemption provisions that may result in the funds not being able to be redeemed in the near term. Audited financial statements are received for each fund and are reviewed by the Company annually.

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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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

The valuation of alternative investments requires significant judgment by the pricing provider due to the absence of quoted market values, changes in market conditions, and the long-term nature of the assets. The significant unobservable inputs include the trading multiples of public companies that are considered comparable to the company being valued, company specific issues, estimates of liquidation value, current operating performance and future expectations of performance, changes in market outlook and the financing environment, capitalization rates, discount rates and cash flows. The fair values of investments held by the employee benefit plans are as follows:

			GAAP Fair Value Hierarchy
	Total		Quoted Prices in Active Market for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
December 31, 2014			(In thousands)
PNM Pension Plan
Participation in PNMR Master Trust Total Plan Investments	$	588,112	$	123,668	$	398,819	$	65,625
TNMP Pension Plan
Participation in PNMR Master Trust Total Plan Investments	$	69,207	$	14,823	$	44,425	$	9,959
PNM OPEB Plan
Cash and cash equivalents	$	1,242	$	1,242	$	—	$	—
Equity securities:
International funds	10,332		—		10,332		—
Domestic value	8,365		8,365		—		—
Domestic growth	5,960		5,960		—		—
Other funds	30,997		—		30,997		—
Fixed income securities:
Mutual funds	22,122		22,122		—		—
	$	79,018	$	37,689	$	41,329	$	—
TNMP OPEB Plan
Cash and cash equivalents	$	168	$	168	$	—	$	—
Equity securities:
International funds	1,277		—		1,277		—
Domestic value	403		403		—		—
Domestic growth	1,024		1,024		—		—
Other funds	3,790		—		3,790		—
Fixed income securities:
Mutual funds	3,549		3,549		—		—
	$	10,211	$	5,144	$	5,067	$	—

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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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

			GAAP Fair Value Hierarchy
	Total		Quoted Prices in Active Market for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
December 31, 2013	(In thousands)
PNM Pension Plan
Participation in PNMR Master Trust	$	557,258	$	145,364	$	330,903	$	80,991
TNMP Pension Plan
Participation in PNMR Master Trust	$	66,285	$	18,657	$	32,620	$	15,008
PNM OPEB Plan
Cash and cash equivalents	$	1,152	$	1,152	$	—	$	—
Equity securities:
International funds	11,634		—		11,634		—
Domestic value	6,388		6,388		—		—
Domestic growth	24,135		7,094		17,041		—
Other funds	14,028		—		14,028		—
Fixed income securities:
Mutual funds	16,796		16,796		—		—
	$	74,133	$	31,430	$	42,703	$	—
TNMP OPEB Plan
Cash and cash equivalents	$	302	$	302	$	—	$	—
Equity securities:
International funds	1,334		—		1,334		—
Domestic value	381		381		—		—
Domestic growth	4,171		1,848		2,323		—
Other funds	1,844		—		1,844		—
Fixed income securities:
Mutual funds	1,702		1,702		—		—
	$	9,734	$	4,233	$	5,501	$	—

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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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

The fair values of investments in the PNMR Master Trust are as follows:

			GAAP Fair Value Hierarchy
	Total		Quoted Prices in Active Market for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
December 31, 2014	(In thousands)
PNMR Master Trust
Cash and cash equivalents	$	15,645	$	15,645	$	—	$	—
Equity securities:
International	23,282		—		23,282		—
Domestic value	41,778		41,778		—		—
Domestic growth	28,370		28,370		—		—
Other funds	29,719		—		29,719		—
Fixed income securities:
Corporate	242,742		—		242,015		727
U.S. Government	106,634		52,537		54,097		—
Municipals	20,156		—		20,156		—
Other funds	74,136		161		73,975		—
Alternative investments:
Private equity funds	37,220		—		—		37,220
Hedge funds	23,876		—		—		23,876
Real estate funds	13,761		—		—		13,761
	$	657,319	$	138,491	$	443,244	$	75,584
December 31, 2013
PNMR Master Trust
Cash and cash equivalents	$	16,281	$	16,281	$	—	$	—
Equity securities:
International	24,471		24,471		—		—
Domestic value	41,451		41,451		—		—
Domestic growth	36,805		36,805		—		—
Other funds	22,522		—		22,522		—
Fixed income securities:
Corporate	202,897		363		202,358		176
U.S. Government	99,748		44,541		55,207		—
Municipals	17,259		—		17,259		—
Other funds	66,286		109		66,177		—
Alternative investments:
Private equity funds	39,122		—		—		39,122
Hedge funds	34,912		—		—		34,912
Real estate funds	21,789		—		—		21,789
	$	623,543	$	164,021	$	363,523	$	95,999

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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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

A reconciliation of the changes in Level 3 fair value measurements is as follows:

	Year Ended December 31,
	2014			2013
Level 3 Fair Value Assets and Liabilities	(In thousands)
PNM Pension	Master Trust			Master Trust
Balance at beginning of period	$	80,991		$	79,017
Actual return on assets sold during the period	10,376			3,303
Actual return on assets still held at period end	(5,731		)	3,361
Purchases	8,832			15,110
Sales	(28,843		)	(19,800		)
Balance at end of period	65,625			80,991
TNMP Pension
Balance at beginning of period	$	15,008		$	14,171
Actual return on assets sold during the period	3,409			1,400
Actual return on assets still held at period end	(1,883		)	1,425
Purchases	2,902			6,408
Sales	(9,477		)	(8,396		)
Balance at end of period	9,959			15,008
Total	$	75,584		$	95,999

Additional information concerning changes in Level 3 fair value measurements for the PNMR Master Trust is as follows:

Level 3 Fair Value Assets and Liabilities

PNMR Master Trust	Private equity funds			Hedge funds			Real estate funds			Fixed income - corporate			Total
				(In thousands)
Balance at December 31, 2012	$	38,212		$	31,277		$	23,699		$	—		$	93,188
Actual return on assets sold during the period	4,677			135			(109		)	1			4,704
Actual return on assets still held at period end	1,162			3,500			123			—			4,785
Purchases	3,117			16,151			2,076			175			21,519
Sales	(8,046		)	(16,151		)	(4,000		)	—			(28,197		)
Balance at December 31, 2013	39,122			34,912			21,789			176			95,999
Actual return on assets sold during the period	5,355			8,667			(236		)	—			13,786
Actual return on assets still held at period end	(296		)	(7,536		)	237			(20		)	(7,615		)
Purchases	3,656			5,500			1,971			608			11,735
Sales	(10,617		)	(17,667		)	(10,000		)	(37		)	(38,321		)
Balance at December 31, 2014	$	37,220		$	23,876		$	13,761		$	727		$	75,584

B- 60

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

(9) 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.

Valencia

PNM has a PPA to purchase all of the electric capacity and energy from Valencia, a 158 MW natural gas-fired power plant near Belen, New Mexico, through May 2028. A third-party built, owns, and operates the facility while PNM is the sole purchaser of the electricity generated. The total construction cost for the facility was $90.0 million. PNM estimates that the plant will typically operate during peak periods of energy demand in summer. PNM is obligated to pay fixed operations and maintenance and capacity charges in addition to variable operation and maintenance charges under this PPA. For the years ended December 31, 2014, 2013, and 2012, PNM paid $19.1 million, $18.9 million, and $18.8 million for fixed charges and $1.2 million, $1.2 million, and $0.9 million for variable charges. PNM does not have any other financial obligations related to Valencia. The assets of Valencia can only be used to satisfy obligations of Valencia and creditors of Valencia do not have any recourse against PNM’s assets.

PNM sources fuel for the plant, controls when the facility operates through its dispatch, and receives the entire output of the plant, which factors directly and significantly impact the economic performance of Valencia. Therefore, PNM has concluded that the third party entity that owns Valencia is a 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. Accordingly, the assets, liabilities, operating expenses, and cash flows of Valencia are included in the consolidated financial statements of PNM although PNM has no legal ownership interest or voting control of the variable interest entity. The assets and liabilities of Valencia set forth below are immaterial to PNM and, therefore, not shown separately on the Consolidated Balance Sheets. The owner’s equity and net income of Valencia are considered attributable to non-controlling interest.

Summarized financial information for Valencia is as follows:

Results of Operations
	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Operating revenues	$	20,247		$	20,166		$	19,585
Operating expenses	(6,120		)	(5,645		)	(5,535		)
Earnings attributable to non-controlling interest	$	14,127		$	14,521		$	14,050

Financial Position
	December 31,
	2014		2013
	(In thousands)
Current assets	$	2,513	$	2,658
Net property, plant and equipment	72,321		75,137
Total assets	74,834		77,795
Current liabilities	1,288		766
Owners’ equity – non-controlling interest	$	73,546	$	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)

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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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

50% of fair market value. On October 8, 2013, PNM notified the owner of Valencia that PNM may exercise the option to purchase 50% of the plant. As provided in the PPA, an appraisal process was initiated since the parties failed to reach agreement on fair market value within 60 days. Under the PPA, results of the appraisal process established the purchase price after which PNM was to determine in its sole discretion whether or not to exercise its option to purchase the 50% interest. The PPA also provides that the purchase price may be adjusted to reflect the period between the determination of the purchase price and the closing. The appraisal process determined the purchase price as of October 8, 2013 to be $85.0 million, prior to any adjustment to reflect the period through the closing date. Approval of the NMPRC and FERC would be required, which process could take up to 15 months. On May 30, 2014, after evaluating its alternatives with respect to Valencia, PNM notified the owner of Valencia that PNM intended to purchase 50% of the plant, subject to certain conditions. PNM’s conditions include: agreeing on the purchase price, adjusted to reflect the period between October 8, 2013 and the closing; approval of the NMPRC, including specified ratemaking treatment, and FERC; approval of the Board and PNM’s board of directors; receipt of other necessary approvals and consents; and other customary closing conditions. PNM received a letter dated June 30, 2014 from the owner of Valencia suggesting that the conditions set forth in PNM’s notification raise issues under the PPA. PNM is discussing these issues with the owner of Valencia. PNM cannot predict whether or not it will reach agreement with the owner of Valencia, if required regulatory and other approvals will be received, or if the purchase will be completed.

PVNGS Leases

PNM is leasing portions of its interests in Units 1 and 2 of PVNGS. There are currently eight separate lease agreements with eight different trusts whose beneficial owners are five different institutional investors. PNM is not the legal or tax owner of the leased assets. The beneficial owners of the trusts possess all of the voting control and pecuniary interests in the trusts. The leases provide PNM with an option to purchase the leased assets at appraised value at the end of the leases, but 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 2 years beyond the termination of the original lease terms. The option periods on certain leases may be further extended for up to an additional 6 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 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 $20.3 million over the remaining original terms of the leases and $145.2 million during the renewal terms of the leases that PNM has elected to renew. Other than as discussed in Note 7, 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 no assets or liabilities recorded on its Consolidated Balance Sheets related to the trusts other than accrued lease payments of $26.0 million at December 31, 2014 and 2013, which are included in other current liabilities on the Consolidated Balance Sheets.

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. The significant factors considered in reaching this conclusion are: the periods covered by fixed price renewal options are significantly shorter than the anticipated remaining useful lives of the assets, particularly since the operating licenses for the plants have been extended for twenty years through 2045 for Unit 1 and 2046 for Unit 2; PNM’s only financial obligation to the trusts is to make the fixed lease payments and the payments do not vary based on the output of the plants or their performance; during the lease terms, the economic performance of the trusts is substantially fixed due to the fixed lease payments; PNM is only one of several participants in PVNGS and is not the operating agent for the plants, so does not significantly influence the day-to-day operations of the plants; furthermore, the operations of the plants, including plans for their decommissioning, are highly regulated by the NRC, leaving little room for the participants to operate the plants in a manner that impacts the economic performance of the trusts; the economic performance of the trusts at the end of the lease terms is dependent upon the fair value and remaining lives of the plants at that time, which are determined by factors such as power prices, outlook for nuclear power, and the impacts of potential carbon legislation or regulation, all which are outside of PNM’s control; and while PNM has some benefit from its renewal options, the vast majority of the value at the end of the leases will accrue to the beneficial owners of the trusts, particularly given increases in the value of existing nuclear generating facilities, which have no GHG, resulting from potential carbon legislation or regulation.

B- 62

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

Rio Bravo, formerly known as Delta

PNM had a 20-year PPA expiring in 2020 covering the entire output of Delta, which was a variable interest under GAAP. PNM also controlled the dispatch of the generating plant, which impacted the variable payments made under the PPA and impacted the economic performance of the entity that owned Delta. This arrangement was entered into prior to December 31, 2003 and PNM was unsuccessful in obtaining the information necessary to determine if it was the primary beneficiary of the entity that owned Delta, or to consolidate that entity if it were determined that PNM was the primary beneficiary. Accordingly, PNM was unable to make those determinations and, as provided in GAAP, accounted for this PPA as an operating lease.

In December 2012, PNM entered into an agreement with the owners of Delta under which PNM would purchase the entity that owned Delta. FERC approved the purchase on February 26, 2013 and the NMPRC approved the purchase on June 26, 2013. Closing was subject to the seller remedying specified operational, NERC compliance, and environmental issues, as well as other customary closing conditions. PNM closed on the purchase on July 17, 2014 and recorded the purchase as of that date. At closing, PNM made a cash payment of $22.8 million, which reflected an adjustment for working capital compared to a targeted working capital and included amounts placed in escrow. Delta had project financing debt, amounting to $14.6 million at closing, which PNM retired. PNM changed the name of the facility to Rio Bravo.

PNM recorded the acquisition as a business combination and reflected the requirements of the FERC Uniform System of Accounts since the purchased assets are subject to traditional rate regulation by the NMPRC and FERC. Accordingly, as of the acquisition date, PNM recorded plant in service of $58.1 million and accumulated depreciation of $23.5 million, reflecting the original cost of the facilities and the estimated economic life to PNM. PNM also recorded current assets of $3.6 million, deferred charges of $3.4 million, current liabilities of $0.3 million, and non-current regulatory liabilities of $3.4 million.

PNM made fixed and variable payments to Delta under the PPA. For the period from January 1, 2014 through July 17, 2014, PNM incurred fixed capacity charges of $3.5 million and variable energy charges of $0.6 million under the PPA. For the years ended December 31, 2013 and 2012, PNM incurred fixed capacity charges of $6.4 million, and $6.2 million and variable energy charges of $1.8 million, and $0.8 million under the PPA. PNM recovered the variable energy charges through its FPPAC.

PNM began consolidating Rio Bravo at the date of the acquisition. Prior to the acquisition, consolidation of Delta would have been immaterial to the Consolidated Balance Sheets of PNMR and PNM. Since all of Delta’s revenues and expenses were attributable to its PPA arrangement with PNM, the primary impact of consolidating Delta to the Consolidated Statements of Earnings of PNMR and PNM would have been to reclassify Delta’s net earnings from operating expenses and reflect such amount as earnings attributable to a non-controlling interest, without any impact to net earnings attributable to PNMR and PNM.

B- 63

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

(10) Earnings and Dividends Per Share

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

	Year Ended December 31,
	2014		2013		2012
	(In thousands, except per share amounts)
Earnings Attributable to PNMR	$	116,254	$	100,507	$	105,547
Average Number of Common Shares:
Outstanding during year	79,654		79,654		79,654
Vested awards of restricted stock	134		191		145
Average Shares – Basic	79,788		79,845		79,799
Dilutive Effect of Common Stock Equivalents (1):
Stock options and restricted stock	491		586		618
Average Shares – Diluted	80,279		80,431		80,417
Net Earnings Per Share of Common Stock:
Basic	$	1.46	$	1.26	$	1.32
Diluted	$	1.45	$	1.25	$	1.31
Dividends Declared per Common Share	$	0.755	$	0.680	0.580

⁽¹⁾  Excludes out-of-the-money options for 254,050 shares of common stock at December 31, 2014. See Note 13.

(11) Income Taxes

PNMR

PNMR’s income taxes consist of the following components:

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Current federal income tax	$	(2,015	)	$	—		$	(1,296	)
Current state income tax	(728		)	(917		)	(37		)
Deferred federal income tax	59,814			50,044			51,559
Deferred state income tax	14,831			12,578			6,921
Amortization of accumulated investment tax credits	(2,164		)	(2,192		)	(2,237		)
Total income taxes	$	69,738		$	59,513		$	54,910

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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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

PNMR’s provision for income taxes differed from the federal income tax computed at the statutory rate for each of the years shown. The differences are attributable to the following factors:

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Federal income tax at statutory rates	$	70,226		$	61,274		$	61,262
Amortization of accumulated investment tax credits	(2,164		)	(2,192		)	(2,237		)
Flow-through of depreciation items	1,344			1,132			1,284
Earnings attributable to non-controlling interest in Valencia	(4,945		)	(5,082		)	(4,918		)
State income tax, net of federal benefit	5,723			3,818			4,646
Impairment of state net operating loss carryforwards	3,129			—			—
Impairment of state production tax credits, net of federal benefit	894			3,880			718
Other	(4,469		)	(3,317		)	(5,845		)
Total income taxes	$	69,738		$	59,513		$	54,910
Effective tax rate	34.76		%	33.99		%	31.37		%

The components of PNMR’s net accumulated deferred income tax liability were:

	December 31,
	2014			2013
	(In thousands)
Deferred tax assets:
Net operating loss	$	153,858		$	134,418
Regulatory liabilities related to income taxes	78,858			83,838
Federal tax credit carryforwards	54,748			40,708
Other	68,566			75,832
Total deferred tax assets	356,030			334,796
Deferred tax liabilities:
Depreciation and plant related	(914,926		)	(814,671		)
Investment tax credit	(36,790		)	(25,855		)
Regulatory assets related to income taxes	(67,910		)	(66,352		)
CTC	(19,352		)	(22,262		)
Pension	(66,498		)	(58,780		)
Other	(115,282		)	(115,458		)
Total deferred tax liabilities	(1,220,758		)	(1,103,378		)
Net accumulated deferred income tax liabilities	(864,728		)	(768,582		)
Current accumulated deferred income tax (asset) liability	(26,383		)	(58,681		)
Non-current accumulated deferred income tax liability	$	(891,111	)	$	(827,263	)

B- 65

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

The following table reconciles the change in PNMR’s net accumulated deferred income tax liability to the deferred income tax benefit included in the Consolidated Statement of Earnings:

	Year Ended
	December 31, 2014
	(In thousands)
Net change in deferred income tax liability per above table	$	96,146
Change in tax effects of income tax related regulatory assets and liabilities	(6,538		)
Tax effect of mark-to-market adjustments	(1,612		)
Tax effect of excess pension liability	3,993
Adjustment for uncertain income tax positions	(4,858		)
Reclassification of unrecognized tax benefits	(15,031		)
Other	381
Deferred income taxes	$	72,481

PNM

PNM’s income taxes consist of the following components:

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Current federal income tax	$	(2,175	)	$	(479	)	$	(12,951	)
Current state income tax	(979		)	(760		)	(1,815		)
Deferred federal income tax	45,890			42,806			56,194
Deferred state income tax	12,061			9,429			11,522
Amortization of accumulated investment tax credits	(2,164		)	(2,192		)	(2,237		)
Total income taxes	$	52,633		$	48,804		$	50,713

PNM’s provision for income taxes differed from the federal income tax computed at the statutory rate for each of the years shown. The differences are attributable to the following factors:

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Federal income tax at statutory rates	$	53,930		$	53,018		$	54,710
Amortization of accumulated investment tax credits	(2,164		)	(2,192		)	(2,237		)
Flow-through of depreciation items	1,325			1,115			1,268
Earnings attributable to non-controlling interest in Valencia	(4,945		)	(5,082		)	(4,918		)
State income tax, net of federal benefit	5,522			6,202			6,500
Impairment of state net operating loss carryforwards	2,145			—			—
Other	(3,180		)	(4,257		)	(4,610		)
Total income taxes	$	52,633		$	48,804		$	50,713
Effective tax rate	34.16		%	32.22		%	32.44		%

B- 66

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

The components of PNM’s net accumulated deferred income tax liability were:

	December 31,
	2014			2013
	(In thousands)
Deferred tax assets:
Net operating loss	$	108,505		$	99,247
Regulatory liabilities related to income taxes	74,293			78,849
Federal tax credit carryforwards	35,259			22,509
Other	35,681			37,008
Total deferred tax assets	253,738			237,613
Deferred tax liabilities:
Depreciation and plant related	(733,519		)	(661,239		)
Investment tax credit	(36,790		)	(25,855		)
Regulatory assets related to income taxes	(57,637		)	(55,844		)
Pension	(58,474		)	(52,104		)
Other	(70,714		)	(75,838		)
Total deferred tax liabilities	(957,134		)	(870,880		)
Net accumulated deferred income tax liabilities	(703,396		)	(633,267		)
Current accumulated deferred income tax (asset) liability	(12,418		)	(43,827		)
Non-current accumulated deferred income tax liability	$	(715,814	)	$	(677,094	)

The following table reconciles the change in PNM’s net accumulated deferred income tax liability to the deferred income tax benefit included in the Consolidated Statement of Earnings:

	Year Ended
	December 31, 2014
	(In thousands)
Net change in deferred income tax liability per above table	$	70,129
Change in tax effects of income tax related regulatory assets and liabilities	(6,349		)
Tax effect of mark-to-market adjustments	(1,470		)
Tax effect of excess pension liability	3,993
Adjustment for uncertain income tax positions	1,155
Reclassification of unrecognized tax benefits	(12,228		)
Other	557
Deferred income taxes	$	55,787

B- 67

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

TNMP

TNMP’s income taxes consist of the following components:

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Current federal income tax	$	35		$	(4,957	)	$	9,152
Current state income tax	1,939			1,916			1,822
Deferred federal income tax	20,577			20,688			4,406
Deferred state income tax	(28		)	(26		)	(28		)
Total income taxes	$	22,523		$	17,621		$	15,352

TNMP’s provision for income taxes differed from the federal income tax computed at the statutory rate for each of the periods shown. The differences are attributable to the following factors:

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Federal income tax at statutory rates	$	21,115		$	16,349		$	14,735
State income tax, net of federal benefit	1,257			1,247			1,185
Other	151			25			(568		)
Total income taxes	$	22,523		$	17,621		$	15,352
Effective tax rate	37.33		%	37.72		%	36.47		%

The components of TNMP’s net accumulated deferred income tax liability at December 31, were:

	December 31,
	2014			2013
	(In thousands)
Deferred tax assets:
Regulatory liabilities related to income taxes	$	4,565		$	4,988
Other	13,429			23,479
Total deferred tax assets	17,994			28,467
Deferred tax liabilities:
Depreciation and plant related	(174,510		)	(151,581		)
CTC	(19,352		)	(22,262		)
Regulatory assets related to income taxes	(10,197		)	(10,509		)
Loss on reacquired debt	(12,846		)	(13,516		)
Other	(12,636		)	(14,295		)
Total deferred tax liabilities	(229,541		)	(212,163		)
Net accumulated deferred income tax liabilities	(211,547		)	(183,696		)
Current accumulated deferred income tax (asset)	(6,398		)	(6,501		)
Non-current accumulated deferred income tax liability	$	(217,945	)	$	(190,197	)

B- 68

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

The following table reconciles the change in TNMP’s net accumulated deferred income tax liability to the deferred income tax benefit included in the Consolidated Statement of Earnings:

	Year Ended
	December 31, 2014
	(In thousands)
Net change in deferred income tax liability per above table	$	27,851
Change in tax effects of income tax related regulatory assets and liabilities	(111		)
Adjustment for uncertain tax positions	(6,796		)
Other	(395		)
Deferred income taxes	$	20,549

Other Disclosures

GAAP requires that the Company recognize only the impact of tax positions that, based on their technical merits, are more likely than not to be sustained upon an audit by the taxing authority. A reconciliation of unrecognized tax benefits (expenses) is as follows:

	PNMR			PNM			TNMP
	(In thousands)
Balance at December 31, 2011	$	19,580		$	10,752		$	7,701
Additions based on tax positions related to 2012	2,046			1,152			—
Reductions for tax positions of prior years	(2,428		)	(1,522		)	(905		)
Settlement payments	—			—			—
Balance at December 31, 2012	19,198			10,382			6,796
Additions based on tax positions related to 2013	(54		)	(54		)	—
Additions for tax positions of prior years	745			745			—
Settlement payments	—			—			—
Balance at December 31, 2013	19,889			11,073			6,796
Additions based on tax positions related to 2014	623			623			—
Additions (reductions) for tax positions of prior years	(5,481		)	532			(6,796		)
Settlement payments	—			—			—
Balance at December 31, 2014	$	15,031		$	12,228		$	—

Included in the balance at December 31, 2014 are $4.7 million and $1.9 million of unrecognized tax benefits that, if recognized, would affect the effective tax rate for PNMR and PNM. The Company does not anticipate that any unrecognized tax expenses or unrecognized tax benefits will be reduced or settled in 2015.

Estimated interest income related to refunds the Company expects to receive is included in Other Income and estimated interest expense and penalties related to potential cash settlements are included in interest expense in the Consolidated Statements of Earnings (Loss). Interest income (expense) related to income taxes is as follows:

	PNMR		PNM		TNMP
	(In thousands)
2014	$	146	$	148	$	(2	)
2013	$	242	$	251	$	(2	)
2012	$	243	$	244	$	(3	)

B- 69

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

Accumulated accrued interest receivable (payable) related to income taxes is as follows:

	PNMR			PNM			TNMP
	(In thousands)
December 31, 2014:
Accumulated accrued interest receivable	$	3,569		$	3,569		$	—
Accumulated accrued interest payable	$	(1,120	)	$	(24	)	$	(120	)
December 31, 2013:
Accumulated accrued interest receivable	$	4,048		$	4,048		$	—
Accumulated accrued interest payable	$	(1,118	)	$	(24	)	$	(118	)

The Company files a federal consolidated and several consolidated and separate state income tax returns. The tax years prior to 2011 are closed to examination by either federal or state taxing authorities other than Arizona. The tax years prior to 2009 are closed to examination by Arizona taxing authorities. Other tax years are open to examination by federal and state taxing authorities. At December 31, 2014, the Company has $405.7 million of federal net operating loss carryforwards that expire beginning in 2030 and $54.7 million of federal tax credit carryforwards that expire beginning in 2023. State net operating losses expire beginning in 2015 and vary from federal due to differences between state and federal tax law.

PNMR has New Mexico wind energy production tax credit carry forwards with statutory expiration dates beginning in 2014. In 2012, PNMR impaired $0.7 million, after federal tax benefit, of the New Mexico wind energy production tax credit carry forwards that were not expected to be utilized prior to their expiration due to the Company’s net operating loss position. The impairment is reflected in PNMR’s Corporate and Other segment.

On January 3, 2013, the American Taxpayer Relief Act of 2012, which extended fifty percent bonus depreciation for 2013, 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 year ended December 31, 2013. The 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 is being phased in from 2014 to 2018. In accordance with GAAP, PNMR and PNM adjusted accumulated deferred income taxes to reflect the tax rate at which the balances are expected to reverse during the period that includes the date of enactment, which was in the year ended December 31, 2013. At that time, the portion of the adjustment related to PNM's regulated activities was recorded as a reduction in deferred tax liabilities, which was offset by an increase in a regulatory liability, on the assumption that PNM will be required to return the benefit to customers over time. 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 in PNMR’s Corporate and Other segment as a reduction in deferred tax assets and an increase in income tax expense of $1.2 million during the year ended December 31, 2013. 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 year ended December 31, 2014, PNM’s deferred tax liabilities were increased by $4.6 million, which reduced regulatory liabilities. Additionally, deferred tax assets not related to PNM’s regulatory activities were increased by $0.1 million, of which $0.2 million increased income tax expense in PNMR's Corporate and Other segment and $0.3 million decreased income tax expense in PNM.

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 year ended December 31, 2013. This impairment is reflected in PNMR's Corporate and Other segment.

On December 19, 2014, the Tax Increase Prevention Act of 2014, which retroactively extended fifty percent bonus tax depreciation for 2014, was signed into law.  Due to provisions in the act, taxes payable to the State of New Mexico for 2014 were reduced, which resulted in an impairment of New Mexico wind energy production tax credits, which after federal income tax

B- 70

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

benefit, amounted to $0.9 million. The impairment is reflected in PNMR’s Corporate and Other segment. Additionally, the act resulted in an impairment of New Mexico net operating loss carryforwards, which after federal income tax benefit, amounted to $3.1 million. Of this amount, $2.1 million is reflected in PNM and $1.0 million is reflected in PNMR’s Corporate and Other segment. In accordance with GAAP, these impairments were recorded as additional income tax expense during the year ended December 31, 2014. The impairment of the New Mexico net operating loss carryforward is reflected as a valuation allowance against deferred tax assets. No such impairments occurred in prior years. TNMP had no such impairment.

The impairments of the New Mexico wind energy production tax credits discussed above are reflected as a valuation allowance against deferred tax assets. At December 31, 2014, PNMR had a total valuation allowance for these credits of $5.5 million. During the years ended December 31, 2014, 2013, and 2012, the valuation allowance for these credits increased by $0.9 million, $3.9 million, and $0.7 million. PNM and TNMP have no such valuation allowances.

In April 2013, the IRS issued Revenue Procedure 2013-24, which provides a safe harbor method of accounting that taxpayers may use to determine repair costs for electric generation property.  Adoption of the safe harbor method is elective for years ending on or after December 31, 2012.  On July 11, 2013, the IRS issued a directive that suspends most current examination activity related to generation repairs methodology for any company that is eligible for the safe harbor. PNM is evaluating the possible effects of adopting the safe harbor method and the ultimate outcome cannot be determined at this time although the effects are not expected to be material due to PNMR’s net operating loss carryforward position.

In September 2013, the IRS issued final regulations addressing the recovery of amounts paid to acquire, produce, or improve tangible personal property and the accounting for and retirement of depreciable property. Also issued were proposed regulations addressing dispositions of property. Repairs of electric transmission and distribution property and repairs of electric generation property are specifically addressed in other Revenue Procedures issued by the IRS. The effects of the remainder of regulations are being evaluated by the Company and cannot be determined at this time. However, due to PNMR's net operating loss carryforward position for income tax purposes, the effects are not expected to be material.

In May 2013, PNMR received a refund of federal income taxes paid in prior years, which primarily was due to bonus tax depreciation and changes in the Company's method of accounting for repairs expense for income tax purposes. The total refund was $96.2 million of which $77.4 million was attributable to PNM.

In 2013, the FASB issued Accounting Standards Update 2013-11, which requires entities to present liabilities for uncertain tax positions 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 those liabilities upon settlement.  The Company adopted the change for 2014.  Had the Company applied the update at December 31, 2013, the effect would have been decreases in net operating loss 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 uncertain tax positions. There was no impact to earnings from adopting the update.

In June 2014, the Company settled the IRS examination of income tax years 2003 and 2005 through 2008. As a result of the settlement, the Company received net federal tax refunds of $2.0 million. The IRS examination resulted in the settlement of certain issues for which the Company had previously reflected liabilities related to uncertain tax positions. The settlement of the IRS examination, including the uncertain tax position matters, resulted in PNMR recording an income tax benefit of $0.2 million on a consolidated basis in the year ended December 31, 2014. PNM recorded an income tax expense of $1.1 million, TNMP reflected no impact, and an income tax benefit of $1.3 million was recorded in PNMR’s Corporate and Other segment.

B- 71

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

(12) Pension and Other Postretirement Benefits

PNMR and its subsidiaries maintain qualified defined benefit pension plans, postretirement benefit plans providing medical and dental benefits, and executive retirement programs (collectively, the “PNM Plans” and “TNMP Plans”). PNMR maintains the legal obligation for the benefits owed to participants under these plans. The periodic costs or income of the PNM Plans and TNMP Plans are included in regulated rates to the extent attributable to regulated operations. PNM receives a regulated return on the amount it has funded for its pension plan in excess of the periodic cost or income to the extent included in retail rates.

Participants in the PNM Plans include eligible employees and retirees of PNMR and other subsidiaries of PNMR. Participants in the TNMP Plans include eligible employees and retirees of TNMP. The PNM pension plan was frozen at the end of 1997 with regard to new participants, salary levels, and benefits. Through December 31, 2007, additional credited service could be accrued under the PNM pension plan up to a limit determined by age and service. The TNMP pension plan was frozen at December 31, 2005 with regard to new participants, salary levels, and benefits.

GAAP requires a plan sponsor to (a) recognize in its statement of financial position an asset for a plan’s overfunded status or a liability for a plan’s underfunded status; (b) measure a plan’s assets and its obligations that determine its funded status as of the end of the employer’s fiscal year; and (c) recognize changes in the funded status of a defined benefit postretirement plan in the year in which the changes occur.

GAAP requires unrecognized prior service costs and unrecognized gains or losses to be recorded in AOCI and subsequently amortized. The amortization of these incurred costs is included as pension and postretirement benefit periodic cost or income in subsequent years. To the extent the amortization of these items will ultimately be recovered in future rates, PNM and TNMP record the costs as a regulatory asset or regulatory liability.

For the PNM Plans and TNMP Plans, the Company has in place a policy that defines the investment objectives, establishes performance goals of asset managers, and provides procedures for the manner in which investments are to be reviewed. The plans implement investment strategies to achieve the following objectives:

• Maximize the return on assets, commensurate with the risk that the Corporate Investment Committee deems appropriate to meet the obligations of the pension plans and OPEB plans, minimize the volatility of expense, and account for contingencies

• Transition asset mix over time to a higher proportion of high quality fixed income investments as the plans’ funded statuses improve

Management is responsible for the determination of the asset target mix and the expected rate of return. The target asset allocations are determined based on consultations with external investment advisors. The expected long-term rate of return on pension and postretirement plan assets is calculated on the market-related value of assets. GAAP requires that actual gains and losses on pension and postretirement plan assets be recognized in the market-related value of assets equally over a period of not more than five years, which reduces year-to-year volatility. For the PNM Plans and TNMP Plans, the market-related value of assets is equal to the prior year’s market related value of assets adjusted for contributions, benefit payments and investment gains and losses that are within a corridor of plus or minus 4.0% around the expected return on market value. Gains and losses that are outside the corridor are amortized over five years.

B- 72

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

Pension Plans

For defined benefit pension plans, including the executive retirement plans, the PBO represents the actuarial present value of all benefits attributed by the pension benefit formula to employee service rendered prior to that date using assumptions regarding future compensation levels. The ABO represents the PBO without considering future compensation levels. Since the plans are frozen, the PBO and ABO are equal. The following table presents information about the PBO, fair value of plan assets, and funded status of the plans:

	PNM Plan						TNMP Plan
	Year Ended December 31,						Year Ended December 31,
	2014			2013			2014			2013
	(In thousands)
PBO at beginning of year	$	599,537		$	675,549		$	66,159		$	76,640
Service cost	—			—			—			—
Interest cost	30,163			28,142			3,193			3,087
Plan amendment	—			(6,346		)	—			—
Actuarial (gain) loss	72,524			(56,533		)	8,466			(7,820		)
Benefits paid	(44,667		)	(41,275		)	(5,513		)	(5,748		)
PBO at end of year	657,557			599,537			72,305			66,159
Fair value of plan assets at beginning of year	556,353			518,095			66,118			66,540
Actual return on plan assets	76,223			19,533			8,572			4,326
Employer contributions	—			60,000			—			1,000
Benefits paid	(44,667		)	(41,275		)	(5,513		)	(5,748		)
Fair value of plan assets at end of year	587,909			556,353			69,177			66,118
Funded status – asset (liability) for pension benefits	$	(69,648	)	$	(43,184	)	$	(3,128	)	$	(41	)

Effective January 1, 2014, the PNM Pension Plan was amended to allow for all participants, terminating after the effective date, to elect a lump sum payment of benefits. This change is reflected in the above table as of December 31, 2013.

The following table presents pre-tax information about prior service cost and net actuarial (gain) loss in AOCI as of December 31, 2014.

	PNM Plan						TNMP Plan
	December 31, 2014						December 31, 2014
	Prior service cost			Net actuarial (gain) loss			Net actuarial (gain) loss
	(In thousands)
Amounts in AOCI not yet recognized in net periodic benefit cost (income) at beginning of year	$	(2,665	)	$	139,256		$	—
Experience loss (gain)	—			34,345			4,420
Regulatory asset (liability) adjustment	—			(19,920		)	(4,420		)
Amortization recognized in net periodic benefit cost (income)	405			(5,469		)	—
Amounts in AOCI not yet recognized in net periodic benefit cost (income) at end of year	$	(2,260	)	$	148,212		$	—
Amortization expected to be recognized in 2015	$	(405	)	$	6,224		$	—

B- 73

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

The following table presents the components of net periodic benefit cost (income):

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
PNM Plan
Service cost	$	—		$	—		$	—
Interest cost	30,163			28,142			32,232
Expected return on plan assets	(38,044		)	(41,930		)	(41,301		)
Amortization of net (gain) loss	13,020			14,840			10,516
Amortization of prior service cost	(965		)	76			317
Net periodic benefit cost	$	4,174		$	1,128		$	1,764
TNMP Plan
Service cost	$	—		$	—		$	—
Interest cost	3,193			3,087			3,635
Expected return on plan assets	(4,526		)	(4,849		)	(5,324		)
Amortization of net (gain) loss	665			1,049			462
Amortization of prior service cost	—			—			—
Net periodic benefit cost (income)	$	(668	)	$	(713	)	$	(1,227	)

The following significant weighted-average assumptions were used to determine the PBO and net periodic benefit cost (income). Should actual experience differ from actuarial assumptions, the PBO and net periodic benefit cost (income) would be affected.

	Year Ended December 31,
PNM Plan	2014		2013		2012
Discount rate for determining December 31 PBO	4.48	%	5.27	%	4.30	%
Discount rate for determining net periodic benefit cost (income)	5.27	%	4.30	%	5.67	%
Expected return on plan assets	7.20	%	7.65	%	8.25	%
Rate of compensation increase	N/A		N/A		N/A
TNMP Plan
Discount rate for determining December 31 PBO	4.39	%	5.06	%	4.19	%
Discount rate for determining net periodic benefit cost (income)	5.06	%	4.19	%	5.69	%
Expected return on plan assets	7.20	%	7.65	%	8.25	%
Rate of compensation increase	N/A		N/A		N/A

The assumed discount rate for determining the PBO was determined based on a review of long-term high-grade bonds and management’s expectations. Changes in discount rates resulted in an increase in the PNM PBO of $50.6 million at December 31, 2014 and a decrease of $60.9 million at December 31, 2013. Changes in discount rates resulted in an increase in the TNMP PBO of $5.1 million at December 31, 2014 and a decrease of $6.4 million at December 31, 2013. Changes in demographic experience resulted in actuarial losses in the PNM PBO of $0.2 million and $4.4 million at December 31, 2014 and 2013. Changes in demographic experience resulted in actuarial gains in the TNMP PBO of $0.4 million at December 31, 2014 and $1.4 million at December 31, 2013. Changes in other assumptions and experience resulted in actuarial gains in the PNM PBO of $0.2 million at December 31, 2014 and less than $0.1 million at December 31, 2013. Changes in other assumptions and experience resulted in actuarial losses in the TNMP PBO of $1.3 million and less than $0.1 million at December 31, 2014 and 2013. These changes are reflected as actuarial (gain) loss above.

B- 74

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

In late 2014, the Society of Actuaries issued revised mortality tables that include changes in assumptions to reflect increased life expectancy and the corresponding decrease in mortality rates.  This change impacts the Company’s pension plans, as the mortality assumptions are used as the basis for stating the pension obligation in financial statements, determining funding requirements, and making minimum lump-sum calculations.  The actuarial valuation performed as of December 31, 2014 incorporated the impacts of the revised mortality tables.  Utilizing the revised mortality tables increased the PNM PBO by $21.9 million and the TNMP PBO by $2.5 million, which are reflected as the actuarial losses above.

The expected long-term rate of return on plan assets reflects the average rate of earnings expected on the funds invested, or to be invested, to provide for the benefits included in the PBO. Factors that are considered include, but are not limited to, historic returns on plan assets, current market information on long-term returns (e.g., long-term bond rates) and current and target asset allocations between asset categories. If all other factors were to remain unchanged, a 1% decrease in the expected long-term rate of return would cause PNM’s and TNMP’s 2015 net periodic cost to increase $5.8 million and $0.6 million (analogous changes would result from a 1% increase). The actual rate of return for the PNM and TNMP pension plans was 14.3% and 13.5% for the year ended December 31, 2014.

The Company’s long-term pension investment strategy is to invest in assets whose interest rate sensitivity is correlated with the pension liability. The Company has chosen to implement this strategy known as Liability Driven Investing (“LDI”) by increasing the liability matching investments as the funded status of the pension plans improves. These liability matching investments are currently fixed income securities. The pension plans current targeted asset allocation is 21% equities, 65% fixed income, and 14% alternative investments. Equity investments are primarily in domestic securities that include large, mid, and small capitalization companies. The pension plans have a 6% targeted allocation to equities of companies domiciled primarily in developed countries outside of the United States. This category includes actively managed international and domestic equity securities that are benchmarked against a variety of style indices. Fixed income investments are primarily corporate bonds of companies from diversified industries, and government securities. Alternative investments include investments in hedge funds, real estate funds, and private equity funds. The hedge funds and private equity funds are structured as multi-manager multi-strategy fund of funds to achieve a diversified position in these asset classes. The hedge funds pursue various absolute return strategies such as relative value, long-short equity, and event driven. Private equity fund strategies include mezzanine financing, buy-outs, and venture capital. The real estate investment is structured as an open-ended, commingled private real estate portfolio that invests in a diversified portfolio of assets including commercial property and multi-family housing. See Note 8 for fair value information concerning assets held by the pension plans.

The following pension benefit payments are expected to be paid:

	PNM Plan		TNMP Plan
	(In thousands)
2015	$	53,472	$	5,997
2016	53,468		5,667
2017	51,241		5,351
2018	49,640		5,585
2019	48,560		5,188
2020 – 2024	213,759		23,600

Due to declines during the recent recession in the general price levels of marketable equity securities held by the pension plans, PNM and TNMP have been making contributions to the pension plans since 2010. In January 2015, the Company made a contribution of to the PNM pension plan of $30.0 million. The Company does not anticipate making any additional contributions to the pension plans in 2015. Based on current law, including recent amendments to funding requirements, and estimates of portfolio performance, contributions to the pension plan trust for 2016-2019 are estimated to total $22.0 million for PNM and none for TNMP. These anticipated contributions were developed using current funding assumptions with discount rates of 4.8% to 5.5%. Actual amounts to be funded in the future will be dependent on the actuarial assumptions at that time, including the appropriate discount rate.

B- 75

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

Other Postretirement Benefit Plans

For postretirement benefit plans, the APBO is the actuarial present value of all future benefits attributed under the terms of the postretirement benefit plan to employee service rendered to date.

The following table presents information about the APBO, the fair value of plan assets, and the funded status of the plans:

	PNM Plan						TNMP Plan
	Year Ended December 31,						Year Ended December 31,
	2014			2013			2014			2013
	(In thousands)
APBO at beginning of year	$	92,165		$	99,613		$	12,266		$	13,678
Service cost	181			260			237			299
Interest cost	4,630			4,113			619			566
Participant contributions	2,582			2,537			366			373
Actuarial (gain) loss	4,455			(4,566		)	1,639			(1,080		)
Benefits paid	(8,838		)	(9,792		)	(1,057		)	(1,570		)
APBO at end of year	95,175			92,165			14,070			12,266
Fair value of plan assets at beginning of year	73,565			64,464			9,601			8,643
Actual return on plan assets	7,334			12,780			841			1,813
Employer contributions	3,532			3,576			343			342
Participant contributions	2,582			2,537			366			373
Benefits paid	(8,838		)	(9,792		)	(1,057		)	(1,570		)
Fair value of plan assets at end of year	78,175			73,565			10,094			9,601
Funded status – asset (liability)	$	(17,000	)	$	(18,600	)	$	(3,976	)	$	(2,665	)

In the year ended December 31, 2014, actuarial losses of $2.8 million and $1.3 million were recorded in regulatory assets for the PNM Plan and TNMP Plan. There were no prior service costs recorded for the year ended December 31, 2014.

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

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
PNM Plan
Service cost	$	181		$	260		$	217
Interest cost	4,630			4,113			5,293
Expected return on plan assets	(5,638		)	(5,043		)	(4,901		)
Amortization of net (gain) loss	2,225			4,242			3,888
Amortization of prior service credit	(1,343		)	(1,343		)	(1,343		)
Net periodic benefit cost	$	55		$	2,229		$	3,154
TNMP Plan
Service cost	$	237		$	299		$	244
Interest cost	619			566			624
Expected return on plan assets	(534		)	(503		)	(516		)
Amortization of net (gain) loss	(122		)	—			(209		)
Amortization of prior service cost	32			57			57
Net periodic benefit cost	$	232		$	419		$	200

B- 76

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

The following significant weighted-average assumptions were used to determine the APBO and net periodic benefit cost. Should actual experience differ from actuarial assumptions, the APBO and net periodic benefit cost would be affected.

	Year Ended December 31,
PNM Plan	2014		2013		2012
Discount rate for determining December 31 APBO	4.45	%	5.21	%	4.26	%
Discount rate for determining net periodic benefit cost	5.21	%	4.26	%	5.70	%
Expected return on plan assets	8.50	%	8.50	%	8.50	%
Rate of compensation increase	N/A		N/A		N/A
TNMP Plan
Discount rate for determining December 31 APBO	4.45	%	5.21	%	4.26	%
Discount rate for determining net periodic benefit cost	5.21	%	4.26	%	5.70	%
Expected return on plan assets	6.50	%	6.50	%	6.50	%
Rate of compensation increase	N/A		N/A		N/A

The assumed discount rate for determining the APBO was determined based on a review of long-term high-grade bonds and management’s expectations. Changes in the discount rates resulted in an increase in the PNM APBO of $6.7 million at December 31, 2014 and a decrease of $8.8 million at December 31, 2013. Changes in discount rates resulted in an increase in the TNMP APBO of $1.1 million at December 31, 2014 and a decrease of $1.3 million at December 31, 2013. Changes in claims, contributions, medical trends, and demographic experience resulted in an actuarial gain in the PNM plan of $5.4 million at December 31, 2014 and an actuarial loss of $4.2 million at December 31, 2013. Changes in claims, contributions, and demographic experience resulted in actuarial losses in the TNMP plan of less than $0.1 million at December 31, 2014 and $0.2 million at December 31, 2013. These changes are reflected as actuarial (gain) loss above.

The actuarial valuation performed as of December 31, 2014 incorporated the impacts of the revised mortality tables discussed above.  Utilizing the revised mortality tables increased the PNM APBO by $3.2 million and the TNMP APBO by $0.5 million, which are reflected as actuarial losses above.

The expected long-term rate of return on plan assets reflects the average rate of earnings expected on the funds invested, or to be invested, to provide for the benefits included in the APBO. Factors that are considered include, but are not limited to, historic returns on plan assets, current market information on long-term returns (e.g., long-term bond rates), and current and target asset allocations between asset categories. If all other factors were to remain unchanged, a 1% decrease in the expected long-term rate of return would cause PNM’s and TNMP’s 2015 postretirement benefit cost to increase $0.7 million and $0.1 million (analogous changes would result from a 1% increase). The actual rate of return for the PNM and TNMP postretirement benefit plans was 10.2% and 8.9% for the year ended December 31, 2014.

The following table shows the assumed health care cost trend rates for the PNM postretirement benefit plan:

	PNM Plan
	December 31,
	2014		2013
Health care cost trend rate assumed for next year	7.0	%	7.5	%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)	5.0	%	5.0	%
Year that the rate reaches the ultimate trend rate	2023		2019

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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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

The following table shows the impact of a one-percentage-point change in assumed health care cost trend rates:

	PNM Plan
	1-Percentage- Point  Increase		1-Percentage- Point  Decrease
	(In thousands)
Effect on total of service and interest cost	$	350	$	(281	)
Effect on APBO	$	5,305	$	(4,622	)

TNMP’s exposure to cost increases in the postretirement benefit plan is minimized by a provision that limits TNMP’s share of costs under the plan. Costs of the plan in excess of the limit are wholly borne by the participants. TNMP reached the cost limit at the end of 2001. As a result, a one-percentage-point change in assumed health care cost trend rates would have no effect on either the net periodic expense or the year-end APBO.

The Company’s other postretirement benefit plans invest in a portfolio that is diversified by asset class and style strategies. The other postretirement benefit plans generally use the same pension fixed income and equity investment managers and utilize the same overall investment strategy as described above for the pension plans, except there is no allocation to alternative investments. The other postretirement benefit plans have a target asset allocation of 70% equities and 30% fixed income. See Note 8 for fair value information concerning assets held by the other postretirement benefit plans.

The following other postretirement benefit payments, which reflect expected future service, are expected to be paid:

	PNM Plan		TNMP Plan
	(In thousands)
2015	$	6,560	$	801
2016	6,635		822
2017	6,718		838
2018	6,875		860
2019	6,950		882
2020 - 2024	34,585		4,717

PNM expects to make contributions to the PNM postretirement benefit plan totaling $3.5 million in 2015 and $14.0 million for 2016-2019. TNMP expects to make contributions to the TNMP postretirement benefit plan totaling $0.3 million in 2015 and $1.4 million for 2016-2019 .

Executive Retirement Programs

For the executive retirement programs, the following table presents information about the PBO and funded status of the plans:

	PNM Plan						TNMP Plan
	Year Ended December 31,						Year Ended December 31,
	2014			2013			2014			2013
	(In thousands)
PBO at beginning of year	$	16,363		$	17,467		$	823		$	902
Service cost	—			—			—			—
Interest cost	822			720			39			36
Actuarial (gain) loss	2,040			(330		)	110			(21		)
Benefits paid	(1,495		)	(1,494		)	(94		)	(94		)
PBO at end of year – funded status	17,730			16,363			878			823
Less current liability	1,528			1,536			94			94
Non-current liability	$	16,202		$	14,827		$	784		$	729

B- 78

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

The following table presents pre-tax information about net actuarial loss in AOCI as of December 31, 2014.

	December 31, 2014
	PNM Plan			TNMP Plan
	(In thousands)
Amount in AOCI not yet recognized in net periodic benefit cost at beginning of year	$	1,833		$	—
Experience loss (gain)	2,040			(110		)
Regulatory asset (liability) adjustment	(1,183		)	110
Amortization recognized in net periodic benefit cost (income)	(88		)	—
Amount in AOCI not yet recognized in net periodic benefit cost at end of year	$	2,602		$	—
Amortization expected to be recognized in 2015	$	136		$	—

The following table presents the components of net periodic benefit:

	Year Ended December 31,
	2014		2013		2012
	(In thousands)
PNM Plan
Service cost	$	—	$	—	$	—
Interest cost	822		720		876
Amortization of net (gain) loss	210		232		83
Amortization of prior service cost	—		—		—
Net periodic benefit cost	$	1,032	$	952	$	959
TNMP Plan
Service cost	$	—	$	—	$	—
Interest cost	39		36		45
Amortization of net (gain) loss	—		—		—
Amortization of prior service cost	—		—		—
Net periodic benefit cost	$	39	$	36	$	45

The following significant weighted-average assumptions were used to determine the PBO and net periodic benefit cost. Should actual experience differ from actuarial assumptions, the PBO and net periodic benefit cost would be affected.

	Year Ended December 31,
PNM Plan	2014		2013		2012
Discount rate for determining December 31 PBO	4.48	%	5.27	%	4.30	%
Discount rate for determining net periodic benefit cost	5.27	%	4.30	%	5.67	%
Long-term rate of return on plan assets	N/A		N/A		N/A
Rate of compensation increase	N/A		N/A		N/A
TNMP Plan
Discount rate for determining December 31 PBO	4.39	%	5.06	%	4.19	%
Discount rate for determining net periodic benefit cost	5.06	%	4.19	%	5.69	%
Long-term rate of return on plan assets	N/A		N/A		N/A
Rate of compensation increase	N/A		N/A		N/A

The assumed discount rate for determining the PBO was determined based on a review of long-term high-grade bonds and management’s expectations. The impacts of changes in assumptions or experience were not significant.

B- 79

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

The following executive retirement plan payments, which reflect expected future service, are expected:

	PNM Plan		TNMP Plan
	(In thousands)
2015	$	1,528	$	93
2016	1,510		92
2017	1,490		91
2018	1,468		89
2019	1,445		86
2020 – 2024	6,722		384

Other Retirement Plans

PNMR sponsors a 401(k) defined contribution plan for eligible employees, including those of its subsidiaries. PNMR’s contributions to the 401(k) plan consist of a discretionary matching contribution equal to 75% of the first 6% of eligible compensation contributed by the employee on a before-tax basis. PNMR also makes a non-matching contribution ranging from 3% to 10% of eligible compensation based on the eligible employee’s age.

PNMR also provides executive deferred compensation benefits through an unfunded, non-qualified plan. The purpose of this plan is to permit certain key employees of PNMR who participate in the 401(k) defined contribution plan to defer compensation and receive credits without reference to the certain limitations on contributions. Eligible employees are allowed to save on an after-tax basis. This plan has been amended and the after-tax provision will be eliminated on June 30, 2015.

A summary of expenses for these other retirement plans is as follows:

	Year Ended December 31,
	2014		2013		2012
	(In thousands)
PNMR
401(k) plan	$	16,703	$	16,785	$	16,185
Non-qualified plan	$	2,257	$	2,204	$	1,491
PNM
401(k) plan	$	12,745	$	12,952	$	12,427
Non-qualified plan	$	1,722	$	1,691	$	1,143
TNMP
401(k) plan	$	3,958	$	3,953	$	3,739
Non-qualified plan	$	535	$	513	$	327

(13) Stock-Based Compensation Plans

PNMR has various stock-based compensation programs, including stock options, restricted stock, and performance shares granted under the Performance Equity Plan (“PEP”). Although certain PNM and TNMP employees participate in the PNMR plans, PNM and TNMP do not have separate employee stock-based compensation plans. In 2011, the Company changed its approach to awarding stock-based compensation. As a result, no stock options have been granted since 2010 and awards of restricted stock have increased. Certain restricted stock awards are subject to achieving performance or market targets and some of these awards also have time vesting requirements. Other awards of restricted stock are only subject to time vesting requirements.

Performance Equity Plan

The PEP provides for the granting of non-qualified stock options, restricted stock rights, performance shares, performance units, and stock appreciation rights to officers, key employees, and non-employee board members. Restricted stock under the

B- 80

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

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 certain stock awards. The total number of shares of PNMR common stock subject to all awards under the PEP, as approved by PNMR’s shareholders in May 2014, may not exceed 13.5 million shares, subject to adjustment and certain share counting rules set forth in the PEP. This current share pool is charged five shares for each share subject to restricted stock or other full value award. Re-pricing of stock options is prohibited unless specific shareholder approval is obtained.

Source of Shares

The source of shares for exercised stock options and vested restricted stock is shares acquired on the open market by an independent agent, rather than newly issued shares.

Accounting for Stock Awards

The stock-based compensation expense related to 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.

In June 2014, the FASB issued Accounting Standards Update 2014-12 – Compensation – Stock Compensation (Topic 718) Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period, which requires that a performance target that affects vesting and that could be achieved after the requisite service period be treated as a performance condition and should not be reflected in estimating the grant date fair value of the award. The FASB issued ASU 2012-12 to eliminate diversity in practice. The Company currently treats the performance targets covered by the standard as performance conditions, so this ASU has no impact on the Company.

Total compensation expense for stock-based payment arrangements recognized by PNMR for the years ended December 31, 2014, 2013, and 2012 was $5.9 million, $5.3 million, and $3.6 million. Stock compensation expense of $4.2 million, $3.8 million, and $2.7 million was charged to PNM and $1.7 million, $1.5 million, and $1.0 million was charged to TNMP.

PNMR receives a tax deduction for certain stock option exercises during the period the options are exercised, generally for the excess of the price at which the options are sold over the exercise prices of the options, and a tax deduction for the value of restricted stock at the vesting date.

At December 31, 2014, PNMR had unrecognized compensation expense of $4.7 million related to restricted stock and performance-based shares and $1.8 million related to market-based shares, which are expected to be recognized over an average of 1.8 years.

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.

B- 81

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

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

	Year Ended December 31,
Restricted Shares and Performance-Based Shares	2014			2013			2012
Expected quarterly dividends per share	$	0.185		$	0.165		$	0.145
Risk-free interest rate	0.62		%	0.34		%	1.22		%
Market-Based Shares
Dividend yield	2.82		%	2.86		%	3.45		%
Expected volatility	25.11		%	25.11		%	43.98		%
Risk-free interest rate	0.64		%	0.36		%	1.04		%

The following table summarizes activity in restricted stock awards, including performance-based and market-based shares, and stock options:

	Restricted Stock				Stock Options
	Shares		Weighted-Average Grant Date Fair Value		Shares		Weighted Average Exercise Price
Outstanding at December 31, 2013	315,305		$	17.87	1,343,666		$	20.63
Granted	242,164		$	21.27	—		$	—
Exercised	(295,423	)	$	16.70	(345,426	)	$	20.04
Forfeited	(3,276	)	$	22.46	(17,151	)	$	26.43
Expired	—		—		(60,584	)	$	27.98
Outstanding at December 31, 2014	258,770		$	22.31	920,505		$	20.39

Included as restricted stock granted and exercised 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 2011 through 2013 performance period.

As of December 31, 2014, PNMR’s stock-based compensation program provides for performance and market targets through 2016. Excluded from the above table are 179,845 shares approved by the Board in February 2015 (based upon achieving market targets, weighted at 60%, at target levels and performance targets, weighted at 40%, at maximum levels for the 2012 through 2014 performance period), as well as maximums of 179,811 and 163,152 shares for the three-year performance periods ending in 2015 and 2016 that would be awarded if all performance and market criteria are achieved at maximum levels and all executives remain eligible.

In March 2012, the Company entered into a retention award agreement with its Chairman, President, and Chief Executive Officer under which she would receive 135,000 shares of PNMR’s common stock if PNMR meets specific market targets at the end of 2016 and she remains an employee of the Company. Under the agreement, she would receive 35,000 of the total shares if PNMR achieved specific market targets at the end of 2014. The specified market target was achieved at the end of 2014 and the Board approved her receiving the 35,000 shares in February 2015. 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 this retention award agreement.

Effective as of January 1, 2015, the Company entered into a retention award agreement with its Executive Vice President and Chief Financial Officer under which he would receive awards of restricted stock if PNMR meets specific performance targets at the end of 2016 and 2017 and he remains an employee of the Company. If PNMR achieves the specific performance target for

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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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

the period from January 1, 2015 through December 31, 2016, he would receive $100,000 of PNMR common stock based on the market value per share on the grant date in early 2017. Similarly, if PNMR achieves the specific performance target for the period from January 1, 2015 through December 31, 2017, he would receive $275,000 of PNMR common stock based on the market value per share on the grant date in early 2018. If the target for the first performance period is not met, but the target for the second performance period is met, he would receive both awards, less any amount received previously under the agreement. The retention award was made under the PEP and was approved by the Board on December 9, 2014. The above table does not include any restricted stock shares under this retention award agreement.

At December 31, 2014, the aggregate intrinsic value of stock options outstanding, all of which are exercisable, was $8.9 million with a weighted-average remaining contract life of 2.83 years. At December 31, 2014, the exercise price of 254,050 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:

	Year Ended December 31,
Restricted Stock	2014		2013		2012
Weighted-average grant date fair value	$	21.27	$	20.03	$	16.75
Total fair value of restricted shares that vested (in thousands)	$	4,933	$	4,395	$	5,099
Stock Options
Weighted-average grant date fair value of options granted	$	—	$	—	$	—
Total fair value of options that vested (in thousands)	$	—	$	625	$	1,054
Total intrinsic value of options exercised (in thousands)	$	2,473	$	2,721	$	6,356

(14) Construction Program and Jointly-Owned Electric Generating Plants

PNM is a participant in several jointly-owned power plant projects. The primary operating or participation agreements for the joint projects expire in July 2016 for Four Corners, July 2022 for SJGS, December 2046 for Luna, and November 2047 for PVNGS.

PNM’s expenditures for additions to utility plant were $316.8 million in 2014, including expenditures on jointly-owned projects. TNMP does not participate in the ownership or operation of any generating plants, but incurred expenditures for additions to utility plant of $127.2 million during 2014. On a consolidated basis, PNMR’s expenditures for additions to utility plant were $460.7 million in 2014.

Joint Projects

Under the agreements for the jointly-owned projects, PNM has an undivided interest in each asset and liability of the project and records its pro-rata share of each item in the corresponding asset and liability account on PNM’s Consolidated Balance Sheets. Likewise, PNM records its pro-rata share of each item of operating and maintenance expenses for its jointly-owned plants within the corresponding operating expense account in its Consolidated Statements of Earnings. PNM is responsible for financing its share of the capital and operating costs of the joint projects.

B- 83

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

At December 31, 2014, PNM’s interests and investments in jointly-owned generating facilities are:

Station (Fuel Type)	Plant in Service		Accumulated Depreciation			Construction Work in Progress			Composite Interest
	(In thousands)
SJGS (Coal)	$	1,009,378	$	(423,364	)	$	25,551		46.30	%
PVNGS (Nuclear) (1)	$	533,702	$	(152,273	)	$	42,334		10.20	%
Four Corners Units 4 and 5 (Coal)	$	162,111	$	(101,007	)	$	8,253		13.00	%
Luna (Gas)	$	66,169	$	(20,297	)	$	(136	)	33.33	%

⁽¹⁾  Includes interest in PVNGS Unit 3, interest in common facilities for all PVNGS units, and owned interests in PVNGS Units 1 and 2.

San Juan Generating Station

PNM operates and jointly owns SJGS. SJGS Units 1 and 2 are owned on a 50% shared basis with Tucson. SJGS Unit 3 is owned 50% by PNM, 41.8% by SCPPA, and 8.2% by Tri-State. SJGS Unit 4 is owned 38.457% by PNM, 28.8% by M-S-R Public Power Agency, 10.04% by the City of Anaheim, California, 8.475% by the City of Farmington, New Mexico, 7.2% by the County of Los Alamos, New Mexico, and 7.028% by UAMPS. See Note 16 for additional information about SJGS, including the potential restructuring of SJGS ownership.

Palo Verde Nuclear Generating Station

PNM is a participant in the three units of PVNGS, also known as the Arizona Nuclear Power Project, with APS (the operating agent), SRP, EPE, SCE, SCPPA, and The Department of Water and Power of the City of Los Angeles. PNM has a 10.2% undivided interest in PVNGS, with portions of its interests in Units 1 and 2 held under leases. See Note 7 for additional information concerning the PVNGS leases, including PNM’s notices that it will exercise its option to purchase the assets underlying certain of the leases at the expiration of the leases on January 15, 2016.

Operation of each of the three PVNGS units requires an operating license from the NRC. The NRC issued full power operating licenses for Unit 1 in June 1985, Unit 2 in April 1986, and Unit 3 in November 1987. The full power operating licenses were originally for a period of 40 years and authorize APS, as operating agent for PVNGS, to operate the three PVNGS units. On April 21, 2011, the NRC approved extensions in the operating licenses for the plants for 20 years through June 2045 for Unit 1, April 2046 for Unit 2, and November 2047 for Unit 3. In April 2010, APS entered into a Municipal Effluent Purchase and Sale Agreement that provides effluent water rights necessary for cooling purposes at PVNGS through 2050.

Four Corners Power Plant

PNM is a participant in two units of Four Corners with APS (the operating agent), EPE, SRP, and Tucson. PNM has a 13.0% undivided interest in Units 4 and 5 of Four Corners. The Four Corners plant site is leased from the Navajo Nation and is also subject to an easement from the federal government. APS, on behalf of the Four Corners participants, negotiated amendments to an existing facility lease with the Navajo Nation, which extends the Four Corners leasehold interest from 2016 to 2041. 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 addition, installation of SCR control technology at Four Corners requires a PSD permit, which APS received in December 2014.  PNM cannot predict whether the 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 PNM and the other Four Corners owners. See Note 16 for additional information about Four Corners.

Luna Energy Facility

Luna is a combined-cycle power plant near Deming, New Mexico. Luna is owned equally by PNM, Tucson, and Samchully Power & Utilities 1, LLC. The operation and maintenance of the facility has been contracted to North American Energy Services.

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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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

Construction Program

The Company anticipates making substantial capital expenditures for the construction and acquisition of utility plant and other property and equipment. An unaudited summary of the budgeted construction expenditures, including expenditures for jointly-owned projects, and nuclear fuel, is as follows:

	2015		2016		2017		2018		2019		Total
					(In millions)
PNM	$	423.9	$	402.3	$	334.8	$	180.6	$	260.3	$	1,601.9
TNMP	121.3		92.8		93.3		105.9		105.0		518.3
Corporate and Other	24.0		19.3		15.4		13.7		14.7		87.1
Total PNMR	$	569.2	$	514.4	$	443.5	$	300.2	$	380.0	$	2,207.3

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 $70.7 million related to environmental upgrades at SJGS to address regional haze and $268.4 million related to the identified sources of replacement capacity under the revised plan for compliance described in Note 16. The above 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, environmental upgrades at Four Corners estimated to be $80.0 million, the purchase of the leased portion of the EIP, and the purchase of the assets underlying three of the PVNGS Unit 2 leases at the expiration of those leases.

(15) Asset Retirement Obligations

AROs are recorded based on the determination of underlying assumptions, such as discount rates, estimates of the future costs for decommissioning, and the timing of the removal activities to be performed. Any changes in these assumptions underlying the required calculations may require revisions to the estimated AROs when identified. A reconciliation of the ARO liability is as follows:

	PNMR			PNM			TNMP
	(In thousands)
Liability at December 31, 2011	$	79,233		$	78,425		$	699
Liabilities incurred	—			—			—
Liabilities settled	(25		)	—			(25		)
Accretion expense	6,685			6,617			58
Liability at December 31, 2012	85,893			85,042			732
Liabilities incurred	—			—			—
Liabilities settled	(79		)	(67		)	(12		)
Accretion expense	7,245			7,174			62
Revisions to estimated cash flows(1)	3,076			3,076			—
Liability at December 31, 2013	96,135			95,225			782
Liabilities incurred	—			—			—
Liabilities settled	—			—			—
Accretion expense	7,984			7,906			66
Revisions to estimated cash flows	51			51			—
Liability at December 31, 2014	$	104,170		$	103,182		$	848

⁽¹⁾  Based on studies to estimate the amount and timing of future ARO expenditures. PNM has an ARO for PVNGS that includes the obligations for nuclear decommissioning of that facility. In 2013, a new decommissioning study for PVNGS

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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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

was implemented reflecting updated cash flow estimates, including the extended operating licenses. The new study resulted in an increase of $0.5 million to the ARO. In addition, a new decommissioning study for SJGS was implemented in 2013, resulting in a $2.5 million increase to the ARO.

(16) Commitments and Contingencies

Overview

There are various claims and lawsuits pending against the Company. The Company also is subject to federal, state, and local environmental laws and regulations and periodically participates in the investigation and remediation of various sites. In addition, the Company occasionally enters into financial commitments in connection with its business operations. Also, the Company is involved in various legal and regulatory (Note 17) proceedings in the normal course of its business. It is not possible at this time for the Company to determine fully the effect of all litigation and other legal and regulatory proceedings on its financial position, results of operations, or cash flows.

With respect to some of the items listed below, the Company has determined that a loss is not probable or that, to the extent probable, cannot be reasonably estimated. In some cases, the Company is not able to predict with any degree of certainty the range of possible loss that could be incurred. Nevertheless, the Company assesses legal and regulatory matters based on current information and makes judgments concerning their potential outcome, giving due consideration to the nature of the claim, the amount and nature of 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. Except as otherwise disclosed, the Company does not expect that any known lawsuits, environmental costs, and commitments will have a material effect on its financial condition, results of operations, or cash flows.

Commitments and Contingencies Related to the Environment

PVNGS Decommissioning Funding

PNM has a program for funding its share of decommissioning costs for PVNGS, including portions held under leases. The nuclear decommissioning funding program is invested in equities and fixed income instruments in qualified and non-qualified trusts. PNM funded $4.9 million, $4.9 million, and $2.6 million for the years ended December 31, 2014, 2013, and 2012 into the qualified and non-qualified trust funds. The estimated market value of the trusts at December 31, 2014 and 2013 was $244.6 million and $222.5 million.

Nuclear Spent Fuel and Waste Disposal

Nuclear power plant operators are required to enter into spent fuel disposal contracts with the DOE that require the DOE to accept and dispose of all spent nuclear fuel and other high-level radioactive wastes generated by domestic power reactors. Although the Nuclear Waste Policy Act required the DOE to develop a permanent repository for the storage and disposal of spent nuclear fuel by 1998, the DOE announced that it would not be able to open the repository by 1998 and sought to excuse its performance of these requirements. In November 1997, the 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 alleged 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. APS and DOE entered into a settlement agreement, and on October 7, 2014, APS received a settlement payment of $57.4 million for costs paid through June 30, 2011, for DOE’s failure to accept spent nuclear fuel generated at PVNGS. PNM’s share of the

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

settlement is $5.9 million, substantially all of which is credited back to PNM’s customers. The settlement agreement also establishes a process for the payment of subsequent claims through December 30, 2016. Under the settlement agreement, APS must submit claims annually for payment of allowable costs. On October 31, 2014, APS submitted a $42.5 million claim for costs paid between July 1, 2011, and June 30, 2014. PNM’s share of the settlement would amount to $4.3 million, will be recorded when a final determination of the claim is made, which is anticipated to be in March 2015, and would primarily be credited back to PNM’s customers. The settlement agreement terminates upon payment of costs paid through December 31, 2016, unless extended by mutual written agreement.

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 December 31, 2014 and 2013, PNM had a liability for interim storage costs of $12.3 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 and temporary storage rule (“Waste Confidence Decision”).

The D.C. Circuit found that the Waste Confidence Decision update constituted a major federal action, which, consistent with NEPA, requires either an environmental impact statement or a finding of no significant impact from the NRC’s actions.  The D.C. Circuit found that the NRC’s evaluation of the environmental risks from spent nuclear fuel was deficient, and therefore remanded the Waste Confidence Decision update for further action consistent with NEPA.

On September 6, 2012, the NRC commissioners issued a directive to the NRC staff to proceed with development of a generic EIS to support an updated Waste Confidence Decision.  The NRC commissioners also directed the staff to establish a schedule to publish a final rule and environmental impact study within 24 months of September 6, 2012. 

In September 2013, the NRC issued its draft generic EIS to support an updated Waste Confidence Decision. On August 26, 2014, the NRC approved a final rule on the environmental effects of continued storage of spent nuclear fuel. The continued storage rule adopted the findings of the generic EIS regarding the environmental impacts of storing spent fuel at any reactor site after the reactor’s licensed period of operations. As a result, those generic impacts do not need to be re-analyzed in the environmental reviews for individual licenses. Although PVNGS had not been involved in any licensing actions affected by the D.C. Circuit’s June 8, 2012, decision, the NRC lifted its suspension on final licensing actions on all nuclear power plant licenses and renewals that went into effect when the D.C. Circuit issued its June 2012 decision. The August 2014 final rule has been subject to continuing legal challenges before the NRC and the United States Court of Appeals.

PVNGS has sufficient capacity at its on-site ISFSI to store all of the nuclear fuel that will be irradiated during the initial operating license period, which ends in December 2027.  Additionally, PVNGS has sufficient capacity at its on-site ISFSI to store a portion of the fuel that will be irradiated during the period of extended operation, which ends in November 2047.  If uncertainties regarding the United States government’s obligation to accept and store spent fuel are not favorably resolved, APS will evaluate alternative storage solutions that may obviate the need to expand the ISFSI to accommodate all of the fuel that will be irradiated during the period of extended operation.

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. 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 DOE’s intention to suspend collecting annual fees for nuclear waste disposal from nuclear power plant operators. On January 3, 2014, the DOE notified Congress of its intention to suspend collection of the one-mill fee, subject to Congress’ disapproval. On May 16, 2014, the DOE adjusted the fee to zero. 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 fee applicable to PVNGS Units 1 and

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PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

2 is being recovered by PNM in its retail rates. PNM anticipates challenges to this action and is unable to predict its ultimate outcome.

The Clean Air Act

Regional Haze

In 1999, EPA developed a regional haze program and regional haze rules under the CAA. The rule directs each of the 50 states to address regional haze. Pursuant to the CAA, states have the primary role to regulate visibility requirements by promulgating SIPs. States are required to establish goals for improving visibility in national parks and wilderness areas (also known as Class I areas) and to develop long-term strategies for reducing emissions of air pollutants that cause visibility impairment in their own states and for preventing degradation in other states. States must establish a series of interim goals to ensure continued progress. The first planning period specifies setting reasonable progress goals for improving visibility in Class I areas by the year 2018. In July 2005, EPA promulgated its final regional haze rule guidelines for states to conduct BART determinations for certain covered facilities, including utility boilers, built between 1962 and 1977 that have the potential to emit more than 250 tons per year of visibility impairing pollution. If it is demonstrated that the emissions from these sources cause or contribute to visibility impairment in any Class I area, then BART must be installed by 2018.

SJGS

BART 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 required installation of selective catalytic reduction technology (“SCR”) on all four units by September 21, 2016. In November 2012, EPA approved all components of the SIP, except for the NOx BART determination for SJGS, which continued to be subject to the FIP.

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. These parties also formally asked EPA to stay the effective date of the rule. Several environmental groups intervened in support of EPA. The parties file periodic status reports with the Tenth Circuit, but proceedings are being held in abeyance as agreed to by the parties.

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 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.

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. NMED developed a RSIP and submitted it to the EIB for approval in May 2013. The EIB approved the RSIP in September 2013 and it was submitted to EPA for approval in October 2013. Final rules approving the RSIP and withdrawing the FIP were published in the Federal Register on October 9, 2014 and became effective on November 10, 2014.

Conversion of SJGS Units 1 and 4 to balanced draft technology (“BDT”) is included with the installation of SNCRs in the RSIP. The requirement to install BDT was made binding and enforceable in the NSR permit that accompanied the RSIP submitted to the EPA. EPA’s rule approving the RSIP specifically references the NSR permit by including a condition that requires “modification of the fan systems on Units 1 and 4 to achieve ‘balanced’ draft configuration ….”

Implementation Activities – Due to the compliance deadline set forth in the FIP, PNM took steps to commence installation of SCRs at SJGS. In October 2012, PNM entered into a contract with an engineering, procurement, and construction contractor to install SCRs on behalf of the SJGS owners. At the time PNM entered into the contract, PNM estimated the total cost to install SCRs on all four units of SJGS to be between approximately $824 million and $910 million. The costs for the project to install

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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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

SCRs would encompass installation of BDT equipment to comply with the NAAQS requirements described below. The construction contract was terminated in December 2014 following approval of the RSIP by EPA.

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 BDT 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 above estimates include gross receipts taxes, AFUDC, and other PNM costs. Based upon its current SJGS ownership interest, PNM’s share of the costs described above would be about 46.3%.

Following the February 2013 development of the alternative BART compliance plan, PNM began taking steps to prepare for the potential installation of SNCR and BDT equipment on Units 1 and 4 due to the long lead times on certain equipment purchases. In May 2013, PNM entered into an equipment and related services contract with a technology provider. In July 2014, PNM entered into a contract for management of the construction and in September 2014 entered into a construction and procurement contract.

NMPRC Filing –On December 20, 2013, PNM made a filing with the NMPRC requesting certain approvals necessary to effectuate the RSIP. In this filing, PNM requested:

• Permission to retire SJGS Units 2 and 3 at December 31, 2017 and to recover over 20 years their net book value at that date along with a regulated return on those costs

• A CCN to include PNM’s ownership of PVNGS Unit 3, amounting to 134 MW, as a resource to serve New Mexico retail customers at a proposed value of $2,500 per KW, effective January 1, 2018

• An order allowing cost recovery for PNM’s share of the installation of SNCR and BDT equipment to comply with NAAQS requirements on SJGS Units 1 and 4, not to exceed a total cost of $82 million

• 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 have been a reduction of 340 MW in PNM’s ownership of SJGS

The December 20, 2013 NMPRC filing identified 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. PNM received approval to construct the 40 MW of solar PV facilities in its 2015 Renewable Energy Plan. See Note 17. Specific approvals to acquire the gas facility and the treatment of associated costs will be made in future filings. PNM estimates the cost of these identified resources would be approximately $268.4 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 would 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 SNCR and BDT equipment.

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 RSIP. 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. In July 2014, PNM filed a notice with the NMPRC regarding the status of the negotiations among the SJGS participants, including that the SJGS participants reached non-binding agreements in principle on the ownership restructuring of SJGS and that PNM was proposing to acquire 132 MW of SJGS Unit 4 effective December 31, 2017, rather than exchanging 78 MW of capacity in SJGS Unit 3 for 78 MW in SJGS Unit 4 as contemplated in the December 20, 2013 NMPRC filing. Those agreements are memorialized in the resolution and term sheet described below.

On October 1, 2014, PNM, the staff of the NMPRC, the NMAG, New Mexico Independent Power Producers, Western Resource Advocates, and Renewable Energy Industries Association of New Mexico filed a stipulation with the NMPRC. NMIEC subsequently joined the agreement. New Mexico Independent Power Producers, Western Resource Advocates, and Renewable Energy Industries Association of New Mexico have since withdrawn support of the stipulation. Statements of opposition were filed by other intervenors.

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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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

Under the terms of the stipulation, PNM:

• Would be authorized to abandon SJGS Units 2 and 3 effective December 31, 2017

• Would be granted a CCN for an additional 132 MW of SJGS Unit 4 capacity as of January 1, 2018 with a rate base value of $26 million plus any reasonable and prudent investments made in Unit 4 prior to that date; PNM would reduce its carrying value of SJGS Unit 3 by this $26 million

• Would recover 50% of the estimated $231 million undepreciated value in SJGS Units 2 and 3 at December 31, 2017; recovery would be over a twenty year period and would include a return on the unrecovered amount at PNM’s WACC; at December 31, 2014, PNM’s net book value of its current ownership share of SJGS Units 2 and 3 was approximately $282 million

• Would be granted a CCN for 134 MW of PVNGS Unit 3 at a January 1, 2018 value of $221.1 million ($1,650 per KW); PNM’s ownership share of PVNGS would also be subject to a capacity factor performance threshold of 75% for a seven year period beginning January 1, 2018; subject to certain exceptions, if the capacity factor is not achieved in any year, PNM would refund the cost of replacement power through its FPPAC; at December 31, 2014, PNM’s net book value of PVNGS Unit 3 was approximately $144 million

• Would file for recovery of its reasonable and prudent costs of installation of the SNCR and BDT equipment requirements at SJGS Units 1 and 4 up to $90.6 million

• Would not be allowed to recover a total of approximately $20 million of increased operations and maintenance costs associated with the agreement reached with the remaining SJGS participants, additional fuel handling expenses, and certain other costs incurred in efforts to comply with the CAA

A public hearing in the NMPRC case was held in January 2015. In connection with the hearing, PNM filed testimony indicating that:

• PNM would not acquire the 65 MW of capacity in SJGS Unit 4 that was no longer anticipated to be acquired by the City of Farmington, as discussed under SJGS Ownership Restructuring Matters below

• PNM would not enter into a coal supply agreement for SJGS that extends beyond 2022 without NMPRC approval

• PNM would have an ownership restructuring agreement for SJGS in place by May 1, 2015

PNM expects a decision from the NMPRC in the second quarter of 2015. PNM is unable to predict if the NMPRC will approve the stipulation. If the stipulation is approved as filed, PNM anticipates it would incur a regulatory disallowance that would include the write-off of 50% of the undepreciated investment in SJGS Units 2 and 3, an offset to the regulatory disallowance to reflect including the investment in PVNGS Unit 3 in the ratemaking process at the stipulated value, and other impacts of the stipulation. Although PNM would record the regulatory disallowance upon approval by the NMPRC, the amount of the disallowance would be dependent on the provisions of the NMPRC’s final order, as well as PNM’s projections of the December 31, 2017 net book values of SJGS Units 2 and 3 and PVNGS Unit 3. The amount initially recorded would be subject to adjustment to reflect changes in the projected December 31, 2017 net book values of the plants. Based on the provisions of the stipulation as filed and PNM’s current projection of December 31, 2017 book values, PNM estimates the net pre-tax regulatory disallowance would be between $60 million and $70 million.

SJGS Ownership Restructuring Matters – 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 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.

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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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

The SJGS participants have engaged in mediated negotiations concerning the implementation of the RSIP to address BART at SJGS. These negotiations initially included potential shifts in ownership among participants and between Units 3 and 4 that could have resulted in PNM acquiring additional ownership in Unit 4 prior to the shutdown of SJGS Units 2 and 3. 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.

On June 26, 2014, a non-binding resolution (the “Resolution”) was unanimously approved by the SJGS Coordination Committee. The Resolution identifies the participants who would be exiting active participation in SJGS effective December 31, 2017, and participants, including PNM, who would retain an interest in the ongoing operation of one or more units of SJGS. The Resolution provides the essential terms of restructured ownership of SJGS between the exiting participants and the remaining participants and addresses other related matters. The Resolution includes provisions indicating that the exiting participants would remain obligated for their proportionate shares of environmental, mine reclamation, and certain other legacy liabilities that are attributable to activities that occurred prior to their exit, as well as outlining how their shares would be determined. Also, on June 26, 2014, a non-binding term sheet was approved by all of the remaining participants that provides the essential terms of restructured ownership of SJGS among the remaining participants. As part of the non-binding terms, PNM confirmed that it would acquire an additional 132 MW in SJGS Unit 4 effective December 31, 2017. There would be no initial cost for PNM to acquire the additional 132 MW although PNM’s share of capital improvements, including the costs of installing SNCR and BDT equipment, and operating expenses would increase to reflect the increased ownership. The acquisition of 132 MW of SJGS Unit 4 would result in PNM’s ownership share of SJGS Unit 4 being 64.5% and of SJGS Units 1 and 4 aggregating 58.7%. The Resolution and the non-binding term sheet recognize that prior to executing a binding restructuring agreement, the remaining participants will need to have greater certainty in regard to the economic cost and availability of fuel for SJGS for the period after December 31, 2017. As discussed under Coal Supply below, the remaining participants are in the process of negotiating agreements concerning future fuel supply for SJGS, the resolution of which is necessary for continued operation of SJGS after December 31, 2017. On September 2, 2014, the SJGS Coordination Committee adopted a non-binding supplement to the Resolution, which provides for allocation of future costs of decommissioning among current SJGS owners using a time-based sliding scale and outlines indemnification obligations.

In September 2014, the SJGS participants executed a binding Fuel and Capital Funding Agreement to implement certain provisions of the Resolution, including payment by the remaining participants of capital costs for the Unit 4 SNCR project starting July 1, 2014, and acquisition by PNM of the exiting participants’ coal inventory as of January 1, 2015. PNM filed the Fuel and Capital Funding Agreement with FERC on September 18, 2014, with a request for a retroactive effective date to July 1, 2014. FERC approved the request on November 13, 2014. The Fuel and Capital Funding Agreement provides that the SJGS participants will return to the prior arrangement if a binding restructuring agreement is not reached.

On January 7, 2015, the City of Farmington, New Mexico, which has an ownership interest in Unit 4, notified the other participants that it will not acquire additional MWs in Unit 4, leaving 65 MWs in that unit unsubscribed. As discussed under NMPRC Filing above, PNM has indicated that it will not acquire any of the unsubscribed MWs. However, a scenario is being evaluated in which PNMR Development would acquire the 65 MWs. The City of Farmington’s action was taken under the Fuel and Capital Funding Agreement and has the impact of negating certain provisions of that agreement, including the payment arrangement related to SNCRs and PNM’s acquisition of the exiting participants’ coal inventory described above, and reinstating the voting and capital improvement cost allocations under the current SJPPA. Accordingly, on February 3, 2015, PNM informed the participants in the Fuel and Capital Funding Agreement that the agreement would terminate by its terms no later than February 6, 2015. The City of Farmington and the other continuing participants in SJGS have indicated that they remain committed to on-going ownership in SJGS and mediated discussions regarding remaining issues have continued, including matters that were addressed in the Fuel and Capital Funding Agreement.

The participants continue to negotiate other definitive agreements that would formalize the matters contained in the Resolution, as amended. A number of regulatory approvals are required to implement the proposed ownership restructuring of SJGS. Any final binding agreements relating to the ownership restructuring are subject to the approval of each participant’s board or other decision-making body and are subject to required regulatory approvals. PNM is unable to predict the impact of the above developments on negotiations, whether definitive agreements will be reached among the owners, or whether required approvals will be obtained, but expects negotiations to proceed consistent with the time frames described in NMPRC Filing above.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

Other Developments and Current Status – The SJPPA requires PNM, as operating agent, to obtain approval of capital improvement project expenditures from participants who have an ownership interest in the relevant unit or property common to more than one unit. 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 described below, 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. In addition, other capital projects related to Unit 4 were not approved by the participants. PNM subsequently requested that the owners of Unit 4 approve the expenditure of costs critical to being able to comply with the time frame in the RSIP with respect to the Unit 4 project of $1.9 million on March 10, 2014, $6.4 million on June 27, 2014, and total project expenses of $76.6 million (including the two prior requests) on January 22, 2015. The Unit 4 owners did not approve these requests.

PNM, in its capacity as operating agent of SJGS, is authorized and obligated under the SJPPA 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. Therefore, on March 10, 2014 and July 14, 2014, PNM, as operating agent for SJGS, issued “Prudent Utility Practice” notices under the SJPPA indicating PNM was undertaking certain critical activities to keep the Unit 4 SNCR project on schedule.

As discussed above, EPA approved the RSIP and withdrew the FIP on October 9, 2014 and those approvals became effective on November 10, 2014. PNM believes significant progress is being made towards implementation of the RSIP. However, the final implementation of the RSIP is still dependent upon PNM obtaining NMPRC approval to retire San Juan Units 2 and 3. Obtaining NMPRC approval will likely require that final binding agreements be reached among the SJGS owners on a revised ownership structure to facilitate the retirement of these two units. In turn, reaching agreement on ownership restructuring, will likely require that agreement be reached regarding the supply of coal for SJGS for periods after December 31, 2017. PNM can provide no assurance that these requirements will be accomplished. If the RSIP requirements ultimately are not implemented due to adverse or alternative regulatory, legislative, legal, or restructuring developments or other factors, PNM would need to pursue other alternatives to address compliance with the CAA.PNM will seek recovery from its ratepayers for costs that may be incurred as a result of the CAA requirements. PNM is unable to predict the ultimate outcome of these matters.

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.

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 shut down by APS on December 30, 2013. For particulate matter emissions, EPA is requiring Units 4 and 5 to meet an emission limit of 0.015 lb/MMBTU and the plant to meet a 20% opacity limit, both of which are achievable through operation of the existing baghouses. Although unrelated to BART, the final BART rule also imposes a 20% opacity limitation on certain fugitive dust emissions from Four Corners’ coal and material handling operations.

SCE, a participant in Four Corners, indicated that certain California legislation may prohibit it from making emission control expenditures at Four Corners. APS and SCE entered into an asset purchase agreement, providing for the purchase by APS of SCE’s 48% interest in each of Units 4 and 5 of Four Corners. A principal condition to closing was the execution of a new coal supply contract for Four Corners on terms reasonably acceptable to APS. See Coal Supply below.

On December 30, 2013, APS announced the closing of its purchase of SCE’s 48% interest in each of Units 4 and 5 of Four Corners. Concurrently with the closing of the SCE transaction, the ownership of the coal supplier and operator of the mine that

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December 31, 2014, 2013 and 2012

serves Four Corners was transferred to a company formed by the Navajo Nation to own the mine and develop other energy projects. Also occurring concurrently, the Four Corners co-owners executed a long term agreement for the supply of coal to Four Corners from July 2016, when the current coal supply agreement expires, through 2031.

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.  On June 19, 2014, PNM submitted comments on the draft EIS as owner and operator of two electric transmission lines that are part of the connected action for the EIS.  A final EIS is expected to be issued in March 2015. In addition, installation of SCR control technology at Four Corners requires a PSD permit, which APS received in December 2014. PNM cannot predict whether the 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 $80.0 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. On July 23, 2014, the Tenth Circuit issued a unanimous decision affirming EPA’s action and denying WEG’s petition for review. On September 15, 2014, the Tenth Circuit issued its mandate marking an official end to the case.

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. On October 21, 2014, the Tenth Circuit denied the petitions for review and affirmed EPA’s actions. On December 15, 2014, the Tenth Circuit issued its mandate marking an official end to the case.

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. On May 13, 2014, EPA released the draft data requirements rule for the 1-hour SO₂ NAAQS, which directs state and tribal air agencies to characterize current air quality in areas with large SO₂ sources to identify maximum 1-hour SO₂ concentrations. The proposed rule also describes the process and timetable by which

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December 31, 2014, 2013 and 2012

air regulatory agencies would characterize air quality around large SO₂ sources through ambient monitoring or modeling. This characterization will result in these areas being designated as attainment, nonattainment, or unclassified for compliance with the 1-hour SO₂ NAAQS. 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 November 8, 2013, PNM received an amendment to its NSR air permit for SJGS, which would be required for the installation of either SCRs or SNCRs described above. The revised permit, requires the reduction of SO₂ emissions to 0.10 pound per MMBTU on SJGS Units 1 and 4 and continues to require the installation of BDT equipment modifications for the purpose of reducing fugitive emissions, including NOx, SO₂, and particulate matter. These reductions will help SJGS meet the NAAQS. It is anticipated that the equipment modifications 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. 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 60-70 parts per billion (“ppb”). On December 17, 2014, EPA published a proposed rule that would revise the NAAQS for ground level ozone. The rule would reduce the current primary 8-hour ozone NAAQS from 75 ppb to between 70 and 65 ppb. EPA is proposing a secondary standard to provide protection against cumulative exposures that can damage plants and trees. To achieve this level of protection, EPA is proposing to set an 8-hour secondary standard at a level within the range of 65 to 70 ppb. According to EPA, 2011-2013 ozone ambient air monitoring data indicates that Bernalillo, Dona Ana, Eddy, and San Juan counties in New Mexico exceed a 70 ppb ozone concentration. In addition, Lea, Luna Santa Fe, and Valencia counties exceed the 65 ppb ozone concentration. Counties that exceed the ozone NAAQS would be designated as nonattainment for ozone. 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 controls to meet a new ozone NAAQS. PNM cannot predict the outcome of this matter, the impact of other potential environmental mitigations, or if additional controls would be required at any of its affected facilities as a result of ozone non-attainment designation. EPA is under a court order to finalize the ozone standard by October 1, 2015.

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 2011, PNM entered into an agreement with NMED and the plaintiffs to resolve a dispute over the applicable NOx emission limits under the Consent Decree. Under the agreement, so long as the NOx emissions limits imposed under the EPA FIP and the New Mexico SIP meet a specified emissions limit, and PNM does not challenge these limits, the parties’ dispute is deemed settled.

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 sought 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. Under the stipulated order, PNM was required to repeat the mercury study required under the Consent Decree using sorbent traps instead of the continuous emissions 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 completed stack testing and submitted the study report to NMED and the plaintiffs in December 2014. Based on PNM’s cost/benefit analysis, PNM recommended that the carbon injection not be increased from its current level. NMED and the plaintiffs are evaluating the study and PNM’s recommendation. 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.

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

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 parties have recently agreed on terms of a settlement. The terms of the settlement do not have a material impact on PNM.  PNM recorded the impact of its share of the proposed settlement in 2014. A final consent decree has not yet been executed.

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 NEPA 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 a finding that the federal defendants violated NEPA by approving the mine plans, voiding, reversing, and remanding the various mining modification approvals, enjoining the federal defendants from re-issuing the mining plan approvals for the mines until compliance with NEPA has been demonstrated, 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. Legal briefing is complete and the matter is ready for a ruling from the court. If WEG ultimately obtains the relief it has requested, such a ruling could require significant expenditures to reconfigure operations at the San Juan mine, impact the production of coal, and impact the economic viability of the San Juan mine and SJGS. 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. In May 2005, APS and the Navajo Nation signed an agreement resolving the dispute regarding the Navajo Nation’s authority to adopt operating permit regulations under the Navajo Nation Air Pollution Prevention and Control Act. As a result of this agreement, APS sought, and the courts granted, dismissal of the pending litigation in the Navajo Nation Supreme Court and the Navajo Nation District Court, to the extent the claims relate to the CAA. The agreement does not address or resolve any dispute relating to other aspects of the Navajo Acts. PNM cannot currently predict the outcome of these matters or the range of their potential impacts.

Cooling Water Intake Structures

EPA issued its final cooling water intake structures rule on May 19, 2013, which establishes 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 final rule was published on August 15, 2014 and became effective October 14, 2014.

The final rule allows multiple compliance options and considerations for site specific conditions and the permit writer is granted a significant amount of discretion in determining permit requirements, schedules, and conditions. To minimize impingement mortality, the rule provides operators of facilities, such as SJGS and Four Corners, seven options for meeting “best technology available” standards for reducing impingement. To minimize entrainment mortality, the permitting authority must establish the “best technology available” for entrainment on a site-specific basis, taking into consideration an array of factors, including social costs and benefits. Affected sources must submit source water baseline characterization data to the permitting authority to assist in the determination. Compliance deadlines under the rule are tied to permit renewal and will be subject to a

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December 31, 2014, 2013 and 2012

schedule of compliance established by the permitting authority. The renewal date for the SJGS NPDES permit is March 31, 2016; however, additional time to submit the application may be allowed by the NPDES permit writer. APS is currently in discussions with EPA Region 9, the National Pollutant Discharge Elimination System permit writer for Four Corners, to determine the scope of the impingement and entrainment requirements, which will, in turn, determine APS’s costs to comply with the rule. APS has indicated that it does not expect such costs to be material. 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. 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 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 conducted similar site-wide sampling activities in April 2014 and obtained results similar to the 2013 data. As part of this effort, PNM also collected a sample of hydrocarbon product for “fingerprint” analysis from a monitoring well located on the northeastern corner of the property.  This analysis indicated that the hydrocarbon product was a mixture of newer and older fuels, and the location of the monitoring well suggests that the hydrocarbon product is likely from offsite sources. PNM does not believe the former generating station is the source of the increased levels of free-phase hydrocarbons, but no conclusive determinations have been made. It is possible that PNM’s prior activities to remediate hydrocarbon contamination, as conducted under an NMED-approved plan, may have resulted in increased nitrate levels.  Additional testing and analysis will need to be performed before conclusions can be reached regarding the cause of the increased nitrate levels or the method and cost of remediation.  PNM is unable to predict the outcome of these matters.

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

Coal Combustion Byproducts Waste Disposal

Regulation

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 included two options for waste designation of coal ash. One option was 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 was 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 is developing a proposed rule governing the placement of CCBs at coal mining and reclamation operations. 

On January 29, 2014, in a consolidated case in the D.C. Circuit involving several environmental groups, including Sierra Club, and industry group members, the court issued 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.

On December 19, 2014, EPA issued its coal ash rule, including a non-hazardous waste determination for coal ash. Coal ash will be regulated as a solid waste under Subtitle D of RCRA. The rule does not cover mine placement of coal ash and OSM is expected to publish a rule covering mine placement in 2015. It is expected that OSM will be influenced by EPA’s rule. Because the rule is promulgated under Subtitle D, it does not require regulated facilities to obtain permits, does not require the states to adopt and implement the new rules, and is not within EPA’s enforcement jurisdiction. Instead, the rule’s compliance mechanism is for a state or citizen group to bring a RCRA citizen suit in federal district court against any facility that is alleged to be in non- compliance with the new requirements.

PNM is reviewing the rule to fully understand its implications. The rule’s preamble indicates EPA is still evaluating whether to reverse its original regulatory determination and regulate coal ash under RCRA Subtitle C, which means it is possible at some point in the future for EPA to review the new CCR rules. PNM would seek recovery from its ratepayers of all costs that are ultimately incurred. PNM cannot predict the outcome of OSM’s proposed rulemaking regarding CCB regulation, including mine placement of CCBs, or whether OSM’s actions will have a material impact on PNM’s operations, financial position, or cash flows. 

Sierra Club Consent Decree

In April 2010, the Sierra Club filed suit against PNMR, PNM, SJCC, and BHP in the United States District Court for the District of New Mexico. In the complaint, as amended, Sierra Club alleged that activities at SJGS and SJCC’s San Juan mine were causing imminent and substantial harm to the environment, including ground and surface water in the region, and that placement of CCBs at the San Juan mine constituted “open dumping” in violation of RCRA.  The suit also included claims against SJCC and BHP under the Surface Mine Control and Reclamation Act. The complaint requested judgment for injunctive relief, payment of civil penalties, and an award of plaintiffs’ attorney’s fees and costs.

On March 28, 2012, the parties filed an executed consent decree with the court, which was approved by the court on April 12, 2012, settling the litigation. Under the terms of the consent decree, the SJGS owners and SJCC will construct and operate a slurry wall and recovery trench, fund other environmental projects, and pay Sierra Club’s attorneys’ and experts’ fees. The total estimated cost of the settlement is $10.2 million, of which about $4.5 million is PNM’s share. Substantially all of the income statement impact related to this settlement was recorded in 2011. The consent decree also includes a release of claims and a covenant not to sue by Sierra Club. PNM is complying with the requirements of the consent decree.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

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 must comply with the MATS rule by April 16, 2015, unless the facility has been granted a 1-year extension under CAA section 112(i)(3). PNM has not requested an extension and will begin complying with the MATS rule by the date specified in the 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 requested and received a 1-year extension until April 16, 2016 for Four Corners to comply with the MATS rule. However, 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 December 31, 2014 and 2013, prepayments for coal, which are included in other current assets, amounted to $37.3 million and $12.3 million. 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.

PNM and the other owners of SJGS are evaluating alternatives for the supply of coal after the expiration of the current coal sales agreement. As discussed under SJGS Ownership Restructuring Matters above, the Resolution and the non-binding term sheet approved by the SJGS Coordination Committee on June 26, 2014 recognize that prior to executing a binding restructuring agreement relating to the ownership of SJGS, the remaining participants will need to have greater certainty in regard to the cost and availability of fuel for SJGS for the period after December 31, 2017. The remaining participants are in the process of negotiating agreements concerning future fuel supply for SJGS. On October 1, 2014, the San Juan Fuels Committee approved a resolution authorizing an amendment to the coal sales agreement. The parties to the coal sales agreement and the amendment are SJCC, PNM, and Tucson. The amendment provided for the negotiation of a potential purchase transaction for the mine assets by one or more of the utilities, an affiliate, or another entity agreed to by the parties to be consummated on or before December 31, 2016. The amendment, which was effective as of October 2, 2014, also released the parties from the obligation to negotiate an extension of the coal sales agreement, but does not impact the utilities’ option to purchase the mining assets at the end of the current contract term if the purchase transaction is not completed. On February 12, 2015, the SJGS Coordination Committee approved a resolution authorizing the modification of the amendment to extend the date for negotiation of a transaction until May 1, 2015 and to allow for a direct sale of the SJCC mining operations by BHP to a third-party mining company. PNM anticipates that in connection with a consummated purchase transaction, the third-party mining company would enter into an agreement to supply coal to SJGS. The parties to the amendment also entered into an agreement in October 2014 providing the SJGS participants with access to data necessary to evaluate the mine assets and liabilities. This agreement has terminated and was not renewed in order to allow the parties to focus on the direct sales process. Currently, PNM cannot predict the outcome of these negotiations or if a transaction will be consummated.

APS purchased 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, beginning in July 2016 and expiring in 2031, was entered into with that entity. The BHP subsidiary is to be retained as the mine manager and operator until December 2016. Coal costs are anticipated to increase approximately 30% at the inception of the new contract. The contract provides for pricing adjustments over its term based on economic indices. PNM anticipates that its share of the increased costs will be recovered through its FPPAC.

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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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

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 current 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 2014 estimates, remaining payments for mine reclamation, in future dollars, are estimated to be $57.3 million for the surface mines at both SJGS and Four Corners and $93.3 million for the underground mine at SJGS as of December 31, 2014. At December 31, 2014 and 2013, liabilities, in current dollars, of $25.7 million and $23.8 million for surface mine reclamation and $8.6 million and $7.8 million for underground mine reclamation were recorded in other deferred credits. On June 1, 2012, the SJGS owners entered into a trust funds agreement to provide funding to compensate SJCC for post-term reclamation obligations under the coal sales agreement. The trust funds agreement requires each owner to enter into an individual trust agreement with a financial institution as trustee, create an irrevocable trust, and periodically deposit funding into the trust for the owner’s share of the mine reclamation obligation. Deposits, which are based on funding curves, must be made on an annual basis. PNM funded $1.0 million in 2014, $0.3 million in 2013, and $3.5 million in 2012. Future funding requirements are currently expected to approximate $0.6 million annually.

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 (Note 4) 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, which was performed in 2013, 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. The reclamation amounts discussed above reflect PNM’s estimates of its share of the revised costs. How costs would be divided among the owners of SJGS has not been finalized. Regulatory determinations made by the NMPRC may also affect the impact on PNM. 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 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. Coal inventories have been restored to pre-incident levels and SJCC provided notice to PNM on September 23, 2014 that the mine has been restored to normal 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 $18.7 million. PNM has credited its FPPAC balancing account for the insurance proceeds allocable to PNM’s New Mexico jurisdictional customers. See Note 17.

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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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

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 were submitted to a panel for binding arbitration. The issues were: 1) whether the SJGS participants owed SJCC unbilled mining costs of $5.2 million or whether SJCC owed 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 were not billable under the mining contract.  PNM’s share of amounts subject to the arbitration was approximately 46.3%. A hearing before the arbitration panel on the remaining issues was held in May 2014. The arbitration panel found in favor of SJCC on both issues. Of PNM’s share of the costs, approximately 33% of the first issue was passed through PNM’s FPPAC and the rest impacted earnings in 2014. The amounts related to the second issue were recorded when billed in prior periods and had no impact in 2014.

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 9.4%, 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. 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 cannot predict the timing or outcome of this litigation. However, PNM does not expect the outcome to have a material impact on its financial position, results of operations, or cash flows.

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 a maximum annual payment limitation of $5.7 million.

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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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

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 premium assessments of $4.8 million for each retrospective premium 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.

Natural Gas Supply

PNM procures gas supplies for its power plants from third-party sources and contracts with third party transportation providers.

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, Rio Bravo, 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 has entered its appearance in the appellate case. No hearing dates or deadlines have been set at this 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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

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. The court denied the utilities’ motion for judgment. The court further granted the County’s motion to dismiss the state law claims. The utilities filed an amended complaint reflecting the two federal claims remaining before the federal court. The utilities also filed a complaint in Bernalillo County, New Mexico District Court reflecting the state law counts dismissed by the federal court. In subsequent briefing in federal court, the County filed a motion for judgment of one of the utilities’ claims, which was granted by the court, leaving a claim regarding telecommunications service as the remaining federal claim. This matter is ongoing in state court. The utilities and Bernalillo County reached a standstill agreement whereby the County would not take any enforcement action against the utilities pursuant to the ordinance during the pendency of the litigation, but not including any period for appeal of a judgment, or upon 30 days written notice by either the County or the utilities of their intention to terminate the agreement.  If the challenges to the ordinance are 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

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TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

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, 43 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. Subsequent to the dismissal, PNM received a letter from counsel on behalf of what appears to be a subset of the 43 landowner allottees involved in the appeal, notifying PNM that the specified allottees were revoking their consents for renewal of right of way on six specific allotments.  On January 22, 2015, PNM received a letter from the BIA Regional Director identifying ten allotments with rights-of-way renewals that were previously contested.  The letter indicated that the renewals were not processed because the necessary consent was not met.  It is the BIA Regional Director’s position that PNM must re-obtain consent from these landowners.  PNM is in the process of investigating the validity of this notice of revocation and its potential impact in light of the BIA’s position and the recent dismissal with prejudice of the appeal, and is therefore unable at this time to predict the likely outcome of this matter.

(17) Regulatory and Rate Matters

The Company is involved in various regulatory matters, some of which contain contingencies that are subject to the same uncertainties as those described in Note 16.

PNM

2014 Electric Rate Case

On December 11, 2014, PNM filed an application for revision of electric retail rates based upon a calendar year 2016 future year test period. The application proposes a revenue increase of $107.4 million, effective January 1, 2016. PNM’s proposed ROE is 10.5%. The requested base rate increase, combined with other rate changes, represent an average bill increase of 7.69%. PNM requested this increase to account for infrastructure investments made since the last rate case and investments needed in the next two years to provide reliable service to PNM’s retail customers, as well as to reflect the declining sales growth in PNM’s service territory. The primary driver of PNM’s identified revenue deficiency, accounting for approximately 92% of the rate increase, is related to infrastructure investments and the recovery of those investment dollars, including depreciation. PNM’s success with energy efficiency programs is a contributing factor to the decline in PNM’s energy sales since the last rate case and accounts for the balance of the rate increase after accounting for offsetting cost reductions. PNM is proposing several changes to rate design to establish fair and equitable pricing across rate classes and to better align cost recovery with cost causation. Specific rate design proposals include increased customer and demand charges, a revenue decoupling pilot program applicable to residential and small power customers, an access charge to customers installing photovoltaic systems after December 31, 2015, a re-allocation of revenue among PNM’s customer classes, a new economic development rate, and continuation of PNM’s renewable energy rider. A public hearing on the rate case is expected to begin in July 2015 and an order from the NMPRC is expected in the fourth quarter of 2015.

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.

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PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

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. Currently, the RCT is set at 3% of customers’ annual electric charges.

PNM’s renewable energy procurement plan for 2012 requested a variance from the RPS due to RCT limitations. The plan was diversity-compliant based on the reduced RPS, except for non-wind/non-solar resources, which were not available. In December 2011, the NMPRC approved PNM’s 2012 plan, but ordered PNM to spend an additional $0.9 million on renewable procurements in 2012. The NMPRC also required PNM to file its 2013 renewable energy procurement plan by April 30, 2012. The 2013 plan proposed procurements for 2013 and 2014 of 20 MW of PNM-owned solar PV facilities, at an estimated cost of $45.5 million, wind and solar REC purchases in 2013, and a PPA for the output of the Lightning Dock Geothermal facility. The plan also included an additional procurement of 2 MW of PNM-owned solar PV facilities at an estimated cost of $4.5 million to supply the energy sold under PNM’s voluntary renewable energy tariff. The plan enabled PNM to comply with the statutory RPS in 2013, but required a variance from the NMPRC’s diversity requirements in 2013 while the proposed geothermal facilities were being constructed. The NMPRC approved the plan in December 2012, but reduced the additional solar PV procurement from 2 MW to 1.5 MW. In 2013, PNM made renewable procurements consistent with the 2013 plan approved by the NMPRC. Construction of the solar PV facilities was completed in 2013 at a cost of $48.9 million. The geothermal 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 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 generator 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 filed its 2015 renewable energy procurement plan on June 2, 2014. The plan meets RPS and diversity requirements within the RCT in 2015 and 2016. PNM’s proposed new procurements included the construction by December 31, 2015 of 40 MW of PNM-owned solar PV facilities at a cost of $79.3 million. The proposed 40 MW solar facilities are identified as being a cost-effective resource in PNM’s application to retire SJGS Units 2 and 3 (Note 16). On September 25, 2014, a stipulated settlement was filed by PNM, staff of the NMPRC, the NMAG, NMIEC, Coalition for Clean Affordable Energy, and Western Resource Advocates. The stipulation proposed approval of PNM’s procurement proposals; however, the costs for the 40 MW of solar would be included in base rates to be set in PNM’s next general rate case rather than through PNM’s renewable energy rider. Under the agreement, PNM would be required to make additional renewable energy procurements in the event that the prior year’s actual renewable energy procurements did not meet the RPS for that year based on actual retail sales and the actual RCT. The parties also agreed to have additional discussions to attempt to reach agreement on RPS and large customer adjustment calculations to be used in future PNM renewable procurement plans. A public hearing on the stipulation was held on October 27, 2014. On November 26, 2014, the NMPRC issued an order approving the stipulation with a modification that revised the not-to-exceed price from $4.25 per MWh to $3.00 per MWh for any additional necessary procurements to meet the RPS requirement in 2013 or 2014. In December 2014, PNM procured an additional 44,000 MWh of renewable resources to meet the 2013 RPS requirement at an average cost of $1.75 per MWh.

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. Preliminary calculations indicate PNM’s jurisdictional equity return did not exceed 10.5% in 2014.

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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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

PNM recorded revenues from the rider of $34.3 million, $23.7 million, and $6.4 million in 2014, 2013, and 2012. In PNM’s 2015 renewable energy procurement plan case, the NMPRC approved a rate, which is designed to collect $44.7 million in 2015.

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.

On October 6, 2014, PNM filed an energy efficiency program application for programs proposed to be offered beginning in June 2015. The filing included proposed program costs of $25.8 million plus a proposed profit incentive. The proposed energy efficiency budget and plan are consistent with the 2013 amendments to the Efficient Use of Energy Act. PNM and the NMPRC staff filed a stipulation on January 30, 2015. If approved, the stipulation would establish program budgets and incentive amounts, assuming a threshold level of energy savings are achieved, for 2015 and 2016. Two parties filed statements in opposition to the stipulation. A public hearing on the stipulation was held in February 2015.

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.

In June 2011, the NMPRC approved PNM-specific incentives for savings. PNM collected approximately $1.3 million, on an annual basis, in incentive revenues through November 2013 consistent with this order. On March 27, 2013, PNM filed its reconciliation for actual energy efficiency program costs, associated incentives, and actual collections for calendar year 2012. The reconciliation filing showed a net over-recovery of $0.2 million, composed of an over-recovery of $1.0 million of program costs and an under-recovery of incentives of $0.8 million. PNM subsequently revised the estimated incentive under-recovery to $0.5 million. PNM and the NMPRC staff filed a motion seeking to substitute the new reconciliation filing with a proposed effective date of May 28, 2013. On April 24, 2013, the NMPRC issued an order granting the motion. PNM implemented the new rate on May 28, 2013. In PNM’s 2014 energy efficiency program application, PNM proposed an energy efficiency incentive of $2.1 million. PNM’s proposed incentive was based upon a shared benefits methodology and is similar in amount to previous PNM incentives authorized by the NMPRC. Under the terms of the January 30, 2015 stipulation discussed above, the incentive amount would be $1.7 million in 2015 and $1.8 million in 2016 assuming threshold level of savings are achieved. A public hearing was held in February 2015. The NMPRC has not yet acted upon PNM’s application.

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.

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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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

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 utility’s WACC times its approved annual program costs. The NMPRC received comments and a public hearing was held on November 20, 2013. The NMPRC issued an order on October 8, 2014, adopting the proposed rule.

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. 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 mine fire incident discussed in Note 16, resolves the ratemaking treatment for coal pre-treatment at SJGS until the next rate case, required PNM to write-off $10.5 million of the under-collected balance in its FPPAC balancing account, and required 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.

The NMPRC approval of the amended stipulation in PNM’s 2010 Electric Rate Case limited the amount that could be recovered on an annual basis for fuel costs during certain years. Costs in excess of the limits were deferred, without carrying costs, for recovery in future periods. The fuel cost caps were $38.8 million for the FPPAC year beginning July 1, 2012 and $36.2 million for the FPPAC year beginning July 1, 2013. The fuel cost caps ended on June 30, 2014. The resulting under-recovery as of April 30, 2014 was $63.5 million. Consistent with the order approved in PNM’s FPPAC Continuation Application, PNM is recovering this under-collection, net of the write-off agreed to in the settlement, over an 18 month period beginning July 1, 2014.

Integrated Resource Plan

NMPRC rules require that investor owned utilities file an IRP every three years. The IRP is required to cover a 20-year planning period and contain an action plan covering the first four years of that period. PNM filed its 2014 IRP on July 1, 2014. The four-year action plan was consistent with the replacement resources identified in PNM’s application to retire SJGS Units 2 and 3. PNM indicated that it planned to meet its anticipated long-term load growth with a combination of additional renewable energy resources, energy efficiency, and natural gas-fired facilities. Consistent with statute and NMPRC rule, PNM incorporated a public advisory process into the development of its 2014 IRP. On July 31, 2014, several parties requested the NMPRC not to accept the 2014 IRP as compliant with NMPRC rule because to do so could affect the pending proceeding on PNM’s application to abandon SJGS Units 2 and 3 and for CCNs for certain replacement resources (Note 16) and because they assert that the IRP does not conform to the NMPRC’s IRP rule. Certain parties also ask that further proceedings on the IRP be held in abeyance until the conclusion of the pending abandonment/CCN proceeding. The NMPRC issued an order in August 2014 that dockets a case to determine whether the IRP complies with applicable NMPRC rules. The order also holds the case in abeyance pending the issuance of final, non-appealable orders in PNM’s 2015 renewable energy procurement plan case and its application to retire SJGS Units 2 and 3.

San Juan Generating Station Units 2 and 3 Retirement

On December 20, 2013, PNM filed an application at the NMPRC to retire SJGS Units 2 and 3 on December 31, 2017. On October 1, 2014, PNM and certain parties to the case filed a stipulation with the NMPRC proposing a settlement of this case. Other parties are opposing the stipulated agreement. Additional information concerning the NMPRC filing, including a summary of the terms of the stipulation is set forth in Note 16. A public hearing in the NMPRC case was held in January 2015. 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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

Four Corners Right of First Refusal

On February 17, 2015, PNM received notice from EPE that EPE has entered into an agreement to sell its 7% interest in Four Corners to APS, thereby triggering PNM’s ability to exercise its right of first refusal (“ROFR”) to acquire a portion of EPE’s interest in Four Corners. PNM intends to inform the NMPRC about receipt of the notice and advise the NMPRC that PNM does not intend to exercise its rights under the ROFR. If not exercised, the ROFR will expire 120 days from the date of the notice.

Transmission Rate Case

In October 2010, PNM filed a notice with FERC to increase its wholesale electric transmission revenues by $11.1 million annually, based on a return on equity of 12.25%. The filing also sought to revise certain Open Access Transmission Tariff provisions and bi-lateral contractual terms.  In December 2010, FERC issued an order accepting PNM’s filing and suspending the proposed tariff revisions for five months. The proposed rates were implemented on June 1, 2011, subject to refund. The rate increase applied to all of PNM’s wholesale electric transmission service customers, which include other utilities, electric cooperatives, and entities that use PNM’s transmission system to transmit power at the wholesale level.  The rate increase did not impact PNM’s retail customers. On January 2, 2013, FERC approved an unopposed settlement agreement, which increases transmission service revenues by $2.9 million annually. In addition, the parties agreed that if PNM files for a formula based rate change within one year from FERC’s approval of the settlement agreement, no party will oppose the general principle of a formula rate, although the parties may still object to particular aspects of the formula. PNM refunded amounts collected in excess of the settled rates in January 2013, concluding this matter.

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. The 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. The proposed $3.2 million rate increase would be in addition to the $2.9 million rate increase approved by the FERC on January 2, 2013.

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 apply to all of PNM’s wholesale electric transmission service 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 then current rates. PNM filed the updated rate request with FERC on May 30, 2014, at which time the new rates became effective, subject to refund. The parties have engaged in settlement negotiations and PNM anticipates that a settlement will be filed with FERC in the near future. There is no required time frame for FERC to act upon a settlement. PNM is unable to predict the outcome of this proceeding.

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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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

Firm-Requirements Wholesale Customers

Navopache Electric Cooperative, Inc. Rate Case

In September 2011, PNM filed an unexecuted amended sales agreement between PNM and NEC with FERC. The agreement proposed a cost of service based rate for the electric service and ancillary services PNM provides to NEC, which would result in an annual increase of $8.7 million or a 39.8% increase over existing rates. PNM also requested a FPPAC and full recovery of certain third-party transmission charges PNM incurs to serve NEC. NEC filed a protest to PNM’s filing with FERC. In November 2011, FERC issued an order accepting the filing, suspending the effective date to be effective April 14, 2012, subject to refund, and set the proceeding for settlement. The parties finalized a settlement agreement and PNM filed for the necessary FERC approval on December 6, 2012. The settlement agreement provided for an annual increase of $5.3 million and an extension of the contract for 10 years through December 31, 2035. On April 5, 2013, FERC approved the settlement agreement. PNM has refunded the amounts collected in excess of the settled rates concluding this matter.

City of Gallup, New Mexico Contract

PNM provided 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.

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 ended on June 29, 2014.  PNM’s revenues for power sold under the Gallup contract were $6.1 million in the six months ended June 30, 2014 and totaled $11.7 million during 2013.  PNM’s 2014 Electric Rate Case discussed above reflects a reallocation of costs among regulatory jurisdictions reflecting the termination of the contract to serve Gallup.

TNMP

Advanced Meter System Deployment

In July 2011, the PUCT approved a settlement and authorized an AMS deployment plan that permits TNMP to collect $113.4 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 requested comments and held a public meeting on 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 were 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 sought recovery of $0.2 million through proposed initial fees ranging from $142.84 to $247.48 and an additional $0.5 million in annual ongoing expenses via a proposed monthly charge of $38.99. On June 20, 2014, the PUCT approved a settlement among the parties permitting TNMP to recover $0.2 million in costs through initial fees ranging from $63.97 to $168.61 and ongoing annual expenses of $0.5 million collected through a $36.78 monthly fee. The settlement presumes up to 1,081 consumers will elect the non-standard meter service, but preserves TNMP’s rights to adjust the fees if the number of anticipated consumers differs from that estimate. TNMP notified all appropriate customers that they could elect non-standard

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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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

metering. As of February 20, 2015, 89 customers have made the election. TNMP does not expect the implementation of non-standard metering service to have a material impact on its financial position, results of operations, or cash flows.

Remand of ERCOT Transmission Rates for 1999 and 2000

Following various appeals, the ERCOT transmission rates approved for the fourth quarter of 1999 and 2000 were remanded back to the PUCT. In October 2011, TNMP joined in a non-unanimous settlement relating to resettlement of the fourth quarter of 1999. In January 2012, the PUCT approved the non-unanimous settlement awarding TNMP $1.6 million. In June 2012, TNMP filed its transmission cost recovery factor filing (“TCRF”) seeking $3.2 million in additional transmission costs. The PUCT staff requested a hearing asserting the settlement proceeds from the 1999 remand settlement must be credited against the costs TNMP requested in its TCRF. After further discussion, PUCT staff agreed that no credit was required since TNMP had not recovered those costs in 1999. The PUCT staff agreed to interim rate relief permitting TNMP to add $1.6 million in uncontested costs to its existing TCRF. TNMP implemented the interim rates on September 1, 2012. On November 19, 2012, the PUCT ordered that the $1.6 million in interim rates were final and authorized TNMP to institute a surcharge in March 2013 to collect the additional $1.6 million in initially disputed costs plus interest.

Energy Efficiency

TNMP recovers the costs of its energy efficiency programs through an energy efficiency cost recovery factor, which includes projected program costs, under or over collected costs from prior years, rate case expenses, and performance bonuses (if the programs exceed expectations). In September 2011, the PUCT approved a settlement that allows TNMP to collect the estimated 2012 energy efficiency program costs of $3.4 million and a $0.3 million bonus for 2010. TNMP’s new rates were effective January 1, 2012. 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, including a performance bonus for 2012 of $0.7 million, beginning March 1, 2014. On May 30, 2014, TNMP filed its 2015 energy efficiency cost recovery factor application with the PUCT requesting recovery of $5.7 million to be collected beginning March 1, 2015. The request included an incentive bonus of $1.5 million for having achieved demand savings for the 2013 program year that exceeded the goal. On August 6, 2014, the parties filed a stipulation resolving TNMP’s application. The PUCT approved the settlement on September 11, 2014 permitting TNMP to collect $5.7 million beginning March 1, 2015. TNMP recorded the $1.5 million incentive bonus for 2013 upon approval by 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. The following sets forth TNMP’s most recent interim transmission cost rate increases:

Effective Date	Approved Increase in Rate Base		Annual Increase in Revenue
	(in millions)
September 27, 2012	$	26.4	$	2.5
March 20, 2013	21.9		2.9
September 17, 2013	18.1		2.8
March 13, 2014	18.2		2.9
September 8, 2014	25.2		4.2

In January 2015, TNMP filed an application to further update its transmission rates to reflect an increase in total rate base of $27.1 million, which would increase revenues by $4.4 million annually. The application is pending before the PUCT.

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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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

Periodic Distribution Rate Adjustment

In September 2011, the PUCT approved a new rule permitting interim rate adjustments to reflect changes in investments in distribution assets. The rule permits distribution utilities to file for a periodic rate adjustment between April 1 and April 8 of each year as long as the electric utility is not earning more than its authorized rate of return using weather-normalized data.

Consolidated Tax Savings Adjustment

On June 14, 2013, the Governor of Texas signed into law a bill eliminating the consolidated tax savings adjustment (“CTSA”) from electric utility ratemaking in Texas. Previously, the CTSA required electric utilities to artificially reduce their respective tax expenses due to the losses incurred by their affiliates. The bill became effective on September 1, 2013.

(18) 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. These services are billed at cost on a monthly basis to the business units.

PNMR files a consolidated federal income tax return with its affiliated companies. A tax allocation agreement exists between PNMR and each of its affiliated companies. These agreements provide that the subsidiary company will compute its taxable income on a stand-alone basis. If the result is a net tax liability, such amount shall be paid to PNMR. If there are net operating losses and/or tax credits, the subsidiary shall receive payment for the tax savings from PNMR to the extent that PNMR is able to utilize those benefits.

See Note 6 for information on intercompany borrowing arrangements. The table below summarizes the nature and amount of related party transactions of PNMR, PNM and TNMP:    

	Year Ended December 31,
	2014		2013		2012
			(In thousands)
Services billings:
PNMR to PNM	$	86,871	$	92,597	$	99,986
PNMR to TNMP	28,349		28,937		29,110
PNM to TNMP	524		562		595
TNMP to PNMR	31		7		15
Income tax sharing payments:
PNMR to TNMP	—		—		1,951
PNMR to PNM	—		77,433		63,114
TNMP to PNMR	—		3,643		—
Interest payments:
PNM to PNMR	65		4		1
TNMP to PNMR	309		481		137

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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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

(19) Accumulated Other Comprehensive Income (Loss)

AOCI reports a measure for accumulated changes in equity that result from transactions and other economic events other than transactions with shareholders. Information regarding AOCI is as follows:

	Accumulated Other Comprehensive Income (Loss)
	Unrealized Gain on Available-for-Sale Securities			Pension Liability Adjustment			Fair Value Adjustment for Cash Flow Hedges			Total
				(In thousands)
PNMR
Balance at December 31, 2011	$	15,634		$	(82,432	)	$	(58	)	$	(66,856	)
Amounts reclassified from AOCI (pre-tax)	(37,269		)	4,611			182			(32,476		)
Income tax impact of amounts reclassified	14,755			(1,825		)	(65		)	12,865
Other OCI changes (pre-tax)	38,548			(30,084		)	(428		)	8,036
Income tax impact of other OCI changes	(15,262		)	11,910			153			(3,199		)
Net change after income taxes	772			(15,388		)	(158		)	(14,774		)
Balance at December 31, 2012	16,406			(97,820		)	(216		)	(81,630		)
Amounts reclassified from AOCI (pre-tax)	(11,956		)	6,364			207			(5,385		)
Income tax impact of amounts reclassified	4,734			(2,524		)	(73		)	2,137
Other OCI changes (pre-tax)	27,419			17,136			(279		)	44,276
Income tax impact of other OCI changes	(10,855		)	(6,781		)	98			(17,538		)
Net change after income taxes	9,342			14,195			(47		)	23,490
Balance at December 31, 2013	25,748			(83,625		)	(263		)	(58,140		)
Amounts reclassified from AOCI (pre-tax)	(13,862		)	5,152			558			(8,152		)
Income tax impact of amounts reclassified	5,461			(2,032		)	(195		)	3,234
Other OCI changes (pre-tax)	17,473			(15,282		)	(153		)	2,038
Income tax impact of other OCI changes	(6,812		)	6,024			53			(735		)
Net change after income taxes	2,260			(6,138		)	263			(3,615		)
Balance at December 31, 2014	$	28,008		$	(89,763	)	$	—		$	(61,755	)

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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 CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

	Accumulated Other Comprehensive Income (Loss)
	Unrealized Gain on Available-for-Sale Securities			Pension Liability Adjustment			Fair Value Adjustment for Cash Flow Hedges		Total
				(In thousands)
PNM
Balance at December 31, 2011	$	15,634		$	(82,432	)	$	—	$	(66,798	)
Amounts reclassified from AOCI (pre-tax)	(37,269		)	4,611			—		(32,658		)
Income tax impact of amounts reclassified	14,755			(1,825		)	—		12,930
Other OCI changes (pre-tax)	38,548			(30,084		)	—		8,464
Income tax impact of other OCI changes	(15,262		)	11,910			—		(3,352		)
Net change after income taxes	772			(15,388		)	—		(14,616		)
Balance at December 31, 2012	16,406			(97,820		)	—		(81,414		)
Amounts reclassified from AOCI (pre-tax)	(11,956		)	6,364			—		(5,592		)
Income tax impact of amounts reclassified	4,734			(2,524		)	—		2,210
Other OCI changes (pre-tax)	27,419			17,136			—		44,555
Income tax impact of other OCI changes	(10,855		)	(6,781		)	—		(17,636		)
Net change after income taxes	9,342			14,195			—		23,537
Balance at December 31, 2013	25,748			(83,625		)	—		(57,877		)
Amounts reclassified from AOCI (pre-tax)	(13,862		)	5,152			—		(8,710		)
Income tax impact of amounts reclassified	5,461			(2,032		)	—		3,429
Other OCI changes (pre-tax)	17,473			(15,282		)	—		2,191
Income tax impact of other OCI changes	(6,812		)	6,024			—		(788		)
Net change after income taxes	2,260			(6,138		)	—		(3,878		)
Balance at December 31, 2014	$	28,008		$	(89,763	)	$	—	$	(61,755	)

B- 112

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

	Accumulated Other Comprehensive Income (Loss)
	Unrealized Gain on Available-for-Sale Securities		Pension Liability Adjustment		Fair Value Adjustment for Cash Flow Hedges			Total
			(In thousands)
TNMP
Balance at December 31, 2011	$	—	$	—	$	(58	)	$	(58	)
Amounts reclassified from AOCI (pre-tax)	—		—		182			182
Income tax impact of amounts reclassified	—		—		(65		)	(65		)
Other OCI changes (pre-tax)	—		—		(428		)	(428		)
Income tax impact of other OCI changes	—		—		153			153
Net change after income taxes	—		—		(158		)	(158		)
Balance at December 31, 2012	—		—		(216		)	(216		)
Amounts reclassified from AOCI (pre-tax)	—		—		207			207
Income tax impact of amounts reclassified	—		—		(73		)	(73		)
Other OCI changes (pre-tax)	—		—		(279		)	(279		)
Income tax impact of other OCI changes	—		—		98			98
Net change after income taxes	—		—		(47		)	(47		)
Balance at December 31, 2013	—		—		(263		)	(263		)
Amounts reclassified from AOCI (pre-tax)	—		—		558			558
Income tax impact of amounts reclassified	—		—		(195		)	(195		)
Other OCI changes (pre-tax)	—		—		(153		)	(153		)
Income tax impact of other OCI changes	—		—		53			53
Net change after income taxes	—		—		263			263
Balance at December 31, 2014	$	—	$	—	$	—		$	—

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 Consolidated Statements of Earnings. Pre-tax amounts reclassified from AOCI related to Pension Liability Adjustment are reclassified to Operating Expenses – Administrative and general in the Consolidated Statements of Earnings. For the years ended December 31, 2014 and 2013, approximately 24.4% and 18.7% of the amount reclassified were capitalized into construction work in process and approximately 2.0% and 3.0% were capitalized into other accounts. Pre-tax amounts reclassified from AOCI related to Fair Value Adjustment for Cash Flow Hedges are reclassified to Interest Charges in the Consolidated Statements of Earnings. An insignificant amount is then capitalized as AFUDC. The income tax impacts of all amounts reclassified from AOCI are included in Income Taxes in the Consolidated Statements of Earnings.

(20) Goodwill; Impairments

The excess purchase price over the fair value of the assets acquired and the liabilities assumed by PNMR for its 2005 acquisition of TNP was recorded as goodwill and was pushed down to the businesses acquired. In 2007, the TNMP assets that were included in its New Mexico operations, including goodwill, were transferred to PNM.

GAAP requires the Company to evaluate its goodwill for impairment annually at the reporting unit level or more frequently if circumstances indicate that the goodwill may be impaired. The Company evaluates goodwill impairment as of April 1st of each year. PNMR’s reporting units that have goodwill are PNM and TNMP. Application of the impairment test requires judgment, including the identification of reporting units, assignment of assets and liabilities to reporting units, and determination of the fair value of each reporting unit.

GAAP provides that in certain circumstances an entity may perform a qualitative analysis to conclude that the goodwill of a reporting unit is not impaired. Under a qualitative assessment an entity considers macroeconomic conditions, industry and market considerations, cost factors, overall financial performance, other relevant entity-specific events affecting a reporting unit,

B- 113

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

as well as whether a sustained decrease (both absolute and relative to its peers) in share price had occurred. An entity considers the extent to which each of the adverse events and circumstances identified could affect the comparison of a reporting unit’s fair value with its carrying amount. An entity places more weight on the events and circumstances that most affect a reporting unit’s fair value or the carrying amount of its net assets. An entity also considers positive and mitigating events and circumstances that may affect its determination of whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount. An entity evaluates, on the basis of the weight of evidence, the significance of all identified events and circumstances in determining whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount. If, after assessing the totality of events or circumstances, an entity determines that it is not more likely than not that the fair value of a reporting unit is less than its carrying amount, a quantitative analysis is not required.

In other circumstances, an entity may perform a quantitative analysis to reach the conclusion regarding impairment with respect to a reporting unit. The first step of the quantitative impairment test requires an entity to compare the fair value of the reporting unit with its carrying value, including goodwill. If as a result of this analysis, the entity concludes there is an indication of impairment in a reporting unit having goodwill, the entity is required to perform the second step of the impairment analysis, determining the amount of goodwill impairment to be recorded. The amount is calculated by comparing the implied fair value of the goodwill to its carrying amount. This exercise requires the entity to allocate the fair value determined in step one to the individual assets and liabilities of the reporting unit. Any remaining fair value would be the implied fair value of goodwill on the testing date. To the extent the recorded amount of goodwill of a reporting unit exceeds the implied fair value determined in step two, an impairment loss would be reflected in results of operations.

An entity may choose to perform a quantitative analysis without performing a qualitative analysis and may perform a qualitative analysis for certain reporting units, but a quantitative analysis for others. Prior to 2013, the Company performed qualitative analyses for all reporting units having goodwill. For the annual evaluations performed as of April 1, 2014 and 2013, PNMR utilized a qualitative analysis for the TNMP reporting unit and a quantitative analysis for the PNM reporting unit.

For the PNM reporting unit, a discounted cash flow methodology was primarily used in the quantitative analysis to estimate the fair value of the reporting unit. This analysis requires significant judgments, including estimation of future cash flows, which is dependent on internal forecasts, estimation of long-term growth rates for the business, and determination of appropriate weighted average cost of capital for each reporting unit. Changes in these estimates and assumptions could materially affect the determination of fair value and the conclusion of impairment.

The April 1, 2014 and 2013 quantitative evaluations indicated the fair value of the PNM reporting unit, which has goodwill of $51.6 million, exceeded its carrying value by approximately 30% and 27%. An increase of 0.5% in the expected return on equity capital utilized in discounting the forecasted cash flows, would have reduced the excess of PNM’s fair value over carrying value to approximately 23% and 20% at April 1, 2014 and 2013. The 2014 and 2013 qualitative analysis for the TNMP reporting unit, which has goodwill of $226.7 million, included the consideration of various reporting unit specific factors as well as industry and macroeconomic factors to determine whether these factors were reasonably likely to have a material impact on the fair value of the reporting unit. Factors considered included the results of the April 1, 2012 quantitative analysis, which indicated that fair value exceeded carrying value of the reporting unit by approximately 26%, current and long-term forecasted financial results, regulatory environment, credit rating, interest rate environment, absolute and relative price of PNMR’s common stock, and operating strategy. TNMP believes it is operating within a generally favorable regulatory environment, its historical and forecasted financial results are positive, and its credit is perceived positively. Based on the analysis of the relevant factors, PNMR concluded that it is more likely than not that the fair value of the TNMP reporting unit exceeds its carrying value. The annual evaluations performed as of April 1, 2014 and 2013 did not indicate impairments of the goodwill of any of PNMR’s reporting units. Since the April 1, 2014 annual evaluation, there have been no indications that the fair values of the reporting units with recorded goodwill have decreased below the carrying values.

Prior annual evaluations have not indicated impairments of any of PNMR’s reporting units, except in 2008. During 2008, the market capitalization of PNMR’s common stock was significantly below book value. In addition, First Choice, a PNMR reporting unit that was sold in 2011, was significantly impacted by depressed economic conditions and changes in the market in which it operated. As a result, goodwill impairments of $51.1 million for PNM, $34.5 million for TNMP, and an aggregate of $174.4 million for PNMR were recorded in 2008. Since 2008, the price of PNMR’s common stock has increased, improving the relationship between PNMR’s market capitalization and book value. In addition, improved regulatory treatment has been experienced by PNM in New Mexico and by TNMP in Texas. These factors resulted in more predictable earnings and increased fair values of the reporting units. Since 2008, the annual evaluations have not indicated that the fair values of the reporting units with recorded goodwill have decreased below their carrying values.

B- 114

PNM RESOURCES, INC. AND SUBSIDIARIES

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2014, 2013 and 2012

(21) Quarterly Operating Results (Unaudited)

Unaudited operating results by quarters for 2014 and 2013 are presented below. In the opinion of management of the Company, all adjustments (consisting of normal recurring accruals) necessary for a fair statement of the results of operations for such periods have been included.

	Quarter Ended
	March 31		June 30		September 30		December 31
	(In thousands, except per share amounts)
PNMR
2014
Operating revenues	$	328,897	$	346,160	$	413,951	$	346,845
Operating income	48,753		71,296		116,799		62,849
Net earnings	16,131		33,181		59,486		22,111
Net earnings attributable to PNMR	12,468		29,141		55,653		18,992
Net Earnings Attributable to PNMR per Common Share:
Basic	0.16		0.37		0.70		0.24
Diluted	0.16		0.36		0.69		0.24
2013
Operating revenues	$	317,665	$	347,599	$	399,730	$	322,929
Operating income	50,704		77,867		117,739		40,532
Net earnings	13,962		31,383		58,814		11,397
Net earnings attributable to PNMR	10,626		27,678		54,555		7,648
Net Earnings Attributable to PNMR per Common Share:
Basic	0.13		0.35		0.68		0.10
Diluted	0.13		0.34		0.68		0.10
PNM
2014
Operating revenues	$	262,736	$	275,704	$	334,993	$	274,481
Operating income	31,304		49,806		90,615		40,988
Net earnings	11,205		24,254		49,052		16,942
Net earnings attributable to PNM	7,674		20,346		45,351		13,955
2013
Operating revenues	$	257,894	$	279,690	$	326,026	$	252,702
Operating income	37,239		58,302		95,217		18,427
Net earnings	14,773		29,697		51,950		6,256
Net earnings attributable to PNM	11,569		26,124		47,823		2,639
TNMP
2014
Operating revenues	$	66,161	$	70,456	$	78,958	$	72,364
Operating income	17,262		21,265		25,873		21,188
Net earnings	6,803		9,534		12,355		9,115
2013
Operating revenues	$	59,771	$	67,909	$	73,704	$	70,227
Operating income	13,054		19,667		22,254		17,210
Net earnings	3,726		8,339		10,106		6,919

B- 115

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

The Board of Directors and Stockholders

PNM Resources, Inc:

We have reported separately herein on the consolidated balance sheets of PNM Resources, Inc and subsidiaries (the Company) as of December 31, 2014 and 2013, and the related consolidated statements of earnings, consolidated statements of comprehensive income, consolidated statements of changes in equity, and consolidated statements of cash flows for each of the years in the two-year period ended December 31, 2014. In connection with our audits of the aforementioned consolidated financial statements, we also audited the related financial statement schedules as listed within Item 15. These financial statement schedules are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statement schedules based on our audits.

In our opinion, such financial statement schedules, when considered in relation to the basic consolidated financial statements taken as a whole, present fairly, in all material respects, the information set forth therein.

/s/ KPMG LLP

Albuquerque, New Mexico

February 27, 2015

B- 116

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

The Board of Directors and Stockholders

Public Service Company of New Mexico:

We have reported separately herein on the consolidated balance sheets of Public Service Company of New Mexico and subsidiaries (the Company) as of December 31, 2014 and 2013, and the related consolidated statements of earnings, consolidated statements of comprehensive income, consolidated statements of changes in equity, and consolidated statements of cash flows for each of the years in the two-year period ended December 31, 2014. In connection with our audits of the aforementioned consolidated financial statements, we also audited the related financial statement schedule as listed within Item 15. The financial statement schedule is the responsibility of the Company’s management. Our responsibility is to express an opinion on the financial statement schedule based on our audits.

In our opinion, such financial statement schedule, when considered in relation to the basic consolidated financial statements taken as a whole, presents fairly, in all material respects, the information set forth therein.

/s/ KPMG LLP

Albuquerque, New Mexico

February 27, 2015

B- 117

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

The Board of Directors and Stockholder

Texas-New Mexico Power Company:

We have audited and reported separately herein on the consolidated balance sheets of Texas-New Mexico Power Company and subsidiaries (the Company) as of December 31, 2014 and 2013, and the related consolidated statements of earnings, consolidated statements of comprehensive income, consolidated statements of changes in equity, and consolidated statements of cash flows for each of the years in the two-year period ended December 31, 2014. In connection with our audits of the aforementioned consolidated financial statements, we also audited the related financial statement schedule as listed within Item 15. The financial statement schedule is the responsibility of the Company’s management. Our responsibility is to express an opinion on the financial statement schedule based on our audits.

In our opinion, such financial statement schedule, when considered in relation to the basic consolidated financial statements taken as a whole, presents fairly, in all material respects, the information set forth therein.

/s/ KPMG LLP

Albuquerque, New Mexico

February 27, 2015

B- 118

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Stockholders of

PNM Resources, Inc.

Albuquerque, New Mexico

We have audited the consolidated financial statements of PNM Resources, Inc. and subsidiaries (the "Company") for the year ended December 31, 2012, and have issued our report thereon dated March 1, 2013; such consolidated financial statements and report are included elsewhere in this Form 10-K. Our audit also included the consolidated financial statement schedules for the year ended December 31, 2012 of the Company listed in Item 15. These consolidated financial statement schedules are the responsibility of the Company's management. Our responsibility is to express an opinion based on our audit. In our opinion, such consolidated financial statement schedules, when considered in relation to the basic consolidated financial statements taken as a whole, present fairly, in all material respects, the information set forth herein.

/s/ DELOITTE & TOUCHE LLP

Phoenix, Arizona

March 1, 2013

B- 119

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Stockholders of

Public Service Company of New Mexico

Albuquerque, New Mexico

and

Texas-New Mexico Power Company

Lewisville, Texas

We have audited the consolidated financial statements of Public Service Company of New Mexico and subsidiaries and Texas-New Mexico Power Company and subsidiaries (the "Companies") for the year ended December 31, 2012, and have issued our reports thereon dated March 1, 2013; such consolidated financial statements and reports are included elsewhere in this Form 10-K. Our audits also included the consolidated financial statement schedules for the year ended December 31, 2012 of the Companies listed in Item 15 . These consolidated financial statement schedules are the responsibility of the Companies’ management. Our responsibility is to express an opinion based on our audits. In our opinion, such consolidated financial statement schedules, when considered in relation to the basic consolidated financial statements taken as a whole, present fairly, in all material respects, the information set forth herein.

/s/ DELOITTE & TOUCHE LLP

Phoenix, Arizona

March 1, 2013

B- 120

SCHEDULE I

PNM RESOURCES, INC.

CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY

STATEMENTS OF EARNINGS

	Year ended December 31,
	2014			2013			2012
	(In thousands)
Operating Revenues	$	—		$	—		$	—
Operating Expenses	650			941			3,287
Operating income (loss)	(650		)	(941		)	(3,287		)
Other Income and Deductions:
Equity in earnings of subsidiaries	124,543			116,634			117,900
Other income	622			769			670
Other deductions	(13,650		)	(22,825		)	(20,904		)
Net other income (deductions)	111,515			94,578			97,666
Earnings Before Income Taxes	110,865			93,637			94,379
Income Tax Expense (Benefit)	(5,389		)	(6,870		)	(11,168		)
Net Earnings	$	116,254		$	100,507		$	105,547

B- 121

SCHEDULE I

PNM RESOURCES, INC.

CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY

STATEMENTS OF CASH FLOWS

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Cash Flows From Operating Activities:
Net earnings	$	116,254		$	100,507		$	105,547
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	680			4,192			5,000
Deferred income tax expense	(69,442		)	(51,820		)	(46,632		)
Equity in (earnings) of subsidiaries	(124,543		)	(116,634		)	(117,900		)
Loss on reacquired debt	—			3,253			—
Stock based compensation expense	5,931			5,320			3,585
Changes in certain assets and liabilities:
Other current assets	22,955			28,460			(43,638		)
Other assets	51,644			46,558			34,096
Accounts payable	(88		)	620			8
Accrued interest and taxes	(7,683		)	(9,266		)	(28,855		)
Other current liabilities	(1,668		)	(146		)	3,876
Other liabilities	28,704			(27,756		)	(29,601		)
Net cash flows from operating activities	22,744			(16,712		)	(114,514		)
Cash Flows From Investing Activities:
Utility plant additions	(474		)	(960		)	(7,524		)
Investments in subsidiaries	—			(13,800		)	—
Cash dividends from subsidiaries	46,599			158,772			61,406
Net cash flows from investing activities	46,125			144,012			53,882
Cash Flows From Financing Activities:
Short-term borrowings (repayments), net	600			(37,600		)	120,900
Repayment of long-term debt	—			(29,468		)	(2,387		)
Proceeds from stock option exercise	6,999			4,618			11,684
Purchases to satisfy awards of common stock	(17,319		)	(13,807		)	(25,168		)
Dividends paid	(58,940		)	(50,980		)	(44,609		)
Other, net	81			—			—
Net cash flows from financing activities	(68,579		)	(127,237		)	60,420
Change in Cash and Cash Equivalents	290			63			(212		)
Cash and Cash Equivalents at Beginning of Period	92			29			241
Cash and Cash Equivalents at End of Period	$	382		$	92		$	29
Supplemental Cash Flow Disclosures:
Interest paid	$	12,152		$	14,510		$	15,007
Income taxes paid (refunded), net	$	(2,014	)	$	22,378		$	1,501

B- 122

SCHEDULE I

PNM RESOURCES, INC.

CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY

BALANCE SHEETS

	December 31,
	2014			2013
	(In thousands)
Assets
Cash and cash equivalents	$	382		$	92
Intercompany receivables	107,619			136,387
Income taxes receivable	29			14,989
Other, net	8,115			8,544
Total current assets	116,145			160,012
Property, plant and equipment, net of accumulated depreciation of $10,251 and $9,167	27,076			26,601
Investment in subsidiaries	1,757,650			1,683,321
Other long-term assets	70,939			53,892
Total long-term assets	1,855,665			1,763,814
	$	1,971,810		$	1,923,826
Liabilities and Stockholders’ Equity
Short-term debt	$	100,600		$	100,000
Short-term debt-affiliate	8,819			8,819
Current maturities of long-term debt	118,766			—
Accrued interest and taxes	2,816			2,797
Other current liabilities	16,320			16,876
Total current liabilities	247,321			128,492
Long-term debt	—			118,766
Other long-term liabilities	2,943			2,999
Total liabilities	250,264			250,257
Common stock (no par value; 120,000,000 shares authorized; issued and outstanding 79,653,624 shares)	1,173,845			1,178,369
Accumulated other comprehensive income (loss), net of tax	(61,755		)	(58,140		)
Retained earnings	609,456			553,340
Total common stockholders’ equity	1,721,546			1,673,569
	$	1,971,810		$	1,923,826

See Notes 6, 7, 14, and 16 for information regarding commitments, contingencies, and maturities of long-term debt.

B- 123

SCHEDULE II

PNM RESOURCES, INC. AND SUBSIDIARIES

VALUATION AND QUALIFYING ACCOUNTS

			Additions				Deductions
Description	Balance at beginning of year		Charged to costs and expenses		Charged to other accounts		Write-offs and other		Balance at end of year
			(In thousands)
Allowance for doubtful accounts, year ended December 31:
2012	$	1,778	$	3,367	$	—	$	3,394	$	1,751
2013	$	1,751	$	2,849	$	—	$	3,177	$	1,423
2014	$	1,423	$	3,267	$	—	$	3,224	$	1,466

B- 124

SCHEDULE II

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARY

A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC.

VALUATION AND QUALIFYING ACCOUNTS

			Additions				Deductions
Description	Balance at beginning of year		Charged to costs and expenses		Charged to other accounts		Write-offs		Balance at end of year
			(In thousands)
Allowance for doubtful accounts, year ended December 31:
2012	$	1,778	$	3,384	$	—	$	3,411	$	1,751
2013	$	1,751	$	2,864	$	—	$	3,192	$	1,423
2014	$	1,423	$	3,275	$	—	$	3,232	$	1,466

B- 125

SCHEDULE II

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC.

VALUATION AND QUALIFYING ACCOUNTS

			Additions					Deductions
Description	Balance at beginning of year		Charged to costs and expenses			Charged to other accounts		Write-offs			Balance at end of year
			(In thousands)
Allowance for doubtful accounts, year ended December 31:
2012	$	—	$	(17	)	$	—	$	(17	)	$	—
2013	$	—	$	(15	)	$	—	$	(15	)	$	—
2014	$	—	$	(8	)	$	—	$	(8	)	$	—

B- 126

ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE

None.

ITEM 9A. CONTROLS AND PROCEDURES

PNMR

(a) Evaluation of disclosure controls and procedures.

As of the end of the period covered by this annual report, PNMR conducted an evaluation under the supervision and with the participation of its management, including the Chief Executive Officer and the 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 concluded that the disclosure controls and procedures are effective.

(b) Management’s report on internal control over financial reporting.

“Management’s Annual Report on Internal Control Over Financial Reporting” appears on page B-2. This report is incorporated by reference herein. PNMR’s internal control over financial reporting as of December 31, 2014 has been audited by KPMG LLP, as an independent registered public accounting firm, as stated in their report which is included herein.

(c) Changes in internal controls.

There have been no changes in PNMR’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 December 31, 2014 that have materially affected, or are reasonably likely to materially affect, PNMR’s internal control over financial reporting.

PNM

(a) Evaluation of disclosure controls and procedures.

As of the end of the period covered by this annual report, PNM conducted an evaluation under the supervision and with the participation of its management, including the Chief Executive Officer and the 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 concluded that the disclosure controls and procedures are effective.

(b) Management’s report on internal control over financial reporting.

“Management’s Annual Report on Internal Control Over Financial Reporting” appears on page B-3. This report is incorporated by reference herein.

(c) Changes in internal controls.

There have been no changes in PNM’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 December 31, 2014 that have materially affected, or are reasonably likely to materially affect, PNM’s internal control over financial reporting.

TNMP

(a) Evaluation of disclosure controls and procedures.

As of the end of the period covered by this annual report, TNMP conducted an evaluation under the supervision and with the participation of its management, including the Chief Executive Officer and the 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 concluded that the disclosure controls and procedures are effective.

C- 1

(b) Management’s report on internal control over financial reporting.

“Management’s Annual Report on Internal Control Over Financial Reporting” appears on page B-4. This report is incorporated by reference herein.

(c) Changes in internal controls.

There have been no changes in 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 December 31, 2014 that have materially affected, or are reasonably likely to materially affect, TNMP’s internal control over financial reporting.

ITEM 9B. OTHER INFORMATION

On February 26, 2015, the Board approved an amendment to PNMR’s bylaws effective February 26, 2015. The amendment revised one of the qualifications for director candidates set forth in Article II, Section 9(f) of PNMR’s bylaws by deleting the requirement that candidates have an equity ownership interest in PNMR before commencing service on the Board. The bylaws retain the requirement that each director have an equity ownership in PNMR consistent with the approved director stock ownership guidelines. Disclosure of PNMR’s bylaw amendment is being made under this Item 9B of Form 10-K in lieu of Item 5.03(a) of Form 8-K.

PART III

ITEM 10. DIRECTORS, EXECUTIVE OFFICERS, AND CORPORATE GOVERNANCE

Reference is hereby made to “Proposal 1: Elect Nine Directors” in PNMR’s Proxy Statement relating to the annual meeting of stockholders to be held on May 12, 2015 (the “2015 Proxy Statement”), to PART I, SUPPLEMENTAL ITEM – “EXECUTIVE OFFICERS OF THE COMPANY” in this Form 10-K, “Section 16(a) Beneficial Ownership Reporting Compliance”, “Code of Ethics,” and “Board Committees and Their Functions” – “Audit and Ethics Committee” in the 2015 Proxy Statement. The Company intends to satisfy the disclosure requirements of Form 8-K relating to amendments to the Company’s code of ethics applicable to its senior executive and financial officers by posting such information on its Internet website. Information about the Company’s website is included under Part I, Item 1 – “Websites.”

PNMR’s common stock is listed on the New York Stock Exchange. As a result, PNMR’s Chief Executive Officer is required to make an annual certification to the New York Stock Exchange stating that she was not aware of any violations by PNMR of the New York Stock Exchange corporate governance listing standards. PNMR’s Chief Executive Officer made the most recent certification to the New York Stock Exchange on June 3, 2014.

ITEM 11. EXECUTIVE COMPENSATION

Reference is hereby made to “Executive Compensation”, and all subheadings thereunder from “Compensation Discussion and Analysis” to “Change in Control, Termination, Retirement, or Impaction”, “Director Compensation,” and “Board Committees and Their Functions – Compensation and Human Resources Committee – Interlocks and Insider Participation” in the 2015 Proxy Statement.

ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS

Reference is hereby made to “Ownership of Our Common Stock – Five Percent Shareholders” and “ – Executive Officers and Directors” and “Equity Compensation Plan Information” in the 2015 Proxy Statement.

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS AND DIRECTOR INDEPENDENCE

Reference is hereby made to “Information About Our Corporate Governance – Related Person Transaction Policy” and “ – Director Independence” in the 2015 Proxy Statement.

ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES

Reference is hereby made to “Audit and Ethics Committee Report” and “Independent Auditor Fees” in the 2015 Proxy Statement. Independent auditor fees for PNM and TNMP are reported in the 2015 Proxy Statement for PNMR. All such fees are fees of PNMR. PNMR charges a management fee to PNM and TNMP that includes an allocation of independent auditor fees.

C- 2

PART IV

ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES

(a) - 1.	See Index to Financial Statements under Part II, Item 8.
(a) - 2.	Financial Statement Schedules for the years 2014, 2013, and 2012 are omitted for the reason that they are not required or the information is otherwise supplied under Part II, Item 8.
(a) - 3-A.	Exhibits Filed:
Exhibit No		Description
3.4	PNMR	Bylaws of PNM Resources, Inc. with all amendments through February 26, 2015
10.1.1**	PNMR	2015 Director Compensation Summary
10.1.2**	PNMR	PNM Resources, Inc. Executive Savings Plan II, amended and restated effective as of January 1, 2015, executed as of December 29, 2014
10.2**	PNM	Employee Retention Agreement executed December 9, 2014 between PNM Resources, Inc. and Charles N. Eldred
10.3	PNM	Extension of LOI Deadline Under Amendment No. Six to Underground Coal Sales Agreement among SJCC, PNM and Tucson dated February 20, 2015
10.4.1**	PNMR	Acknowledgment Form for officer performance share awards granted under the Second Amended and Restated Omnibus Performance Equity Plan dated May 19, 2009, as amended
10.4.2**	PNMR	Acknowledgment Form for officer restricted stock rights awards granted under the PNM Resources, Inc. 2014 Performance Equity Plan dated May 15, 2014
10.4.3**	PNMR	Acknowledgment Form for director restricted stock rights awards granted under the PNM Resources, Inc. 2014 Performance Equity Plan dated May 15, 2014
10.4.4**	PNMR	Employee Retention Agreement executed December 9, 2014 between PNMR Services Company and Thomas G. Sategna
12.1	PNMR	Ratio of Earnings to Fixed Charges
12.2	PNM	Ratio of Earnings to Fixed Charges
12.3	TNMP	Ratio of Earnings to Fixed Charges
21	PNMR	Certain subsidiaries of PNM Resources, Inc.
23.1	PNMR	Consent of KPMG LLP for PNM Resources, Inc.
23.2	PNM	Consent of KPMG LLP for Public Service Company of New Mexico
23.3	PNMR	Consent of Deloitte & Touche LLP for PNM Resources, Inc.
23.4	PNM	Consent of Deloitte & Touche LLP for Public Service Company of New Mexico
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 Financial 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

D- 1

101.INS	PNMR	XBRL Instance Document
101.SCH	PNMR	XBRL Taxonomy Extension Schema Document
101.CAL	PNMR	XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF	PNMR	XBRL Taxonomy Extension Definition Linkbase Document
101.LAB	PNMR	XBRL Taxonomy Extension Label Linkbase Document
101.PRE	PNMR	XBRL Taxonomy Extension Presentation Linkbase Document

(a) -3- B. Exhibits Incorporated By Reference:

The documents listed below are being filed (as shown above) or have been previously filed on behalf of PNM Resources, PNM or TNMP and are incorporated by reference to the filings set forth below pursuant to Exchange Act Rule 12b-32 and Regulation S-K section 10, paragraph (d).

Exhibit No.	Description of Exhibit	Filed as Exhibit:	Registrant(s) File No:
Articles of Incorporation and By-laws
3.1	Articles of Incorporation of PNM Resources, as amended to date (Certificate of Amendment dated October 27, 2008 and Restated Articles of Incorporation dated August 3, 2006)	3.1 to the Company’s Current Report on Form 8-K filed November 21, 2008	1-32462 PNMR
3.2	Restated Articles of Incorporation of PNM, as amended through May 31, 2002	3.1.1 to the Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2002	1-6986 PNM
3.3	Articles of Incorporation of TNMP, as amended through July 7, 2005	3.1.2 to the Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2005	2-97230 TNMP
3.4	Bylaws of PNM Resources, Inc. with all amendments to and including February 26, 2015	3.4 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2014	1-32462 PNMR
3.5	Bylaws of PNM with all amendments to and including May 31, 2002	3.1.2 to the Company’s Report on Form 10-Q for the fiscal quarter ended June 30, 2002	1-6986 PNM
3.6	Bylaws of TNMP with all amendments to and including June 18, 2013	3.6 to TNMP’s Current Report on Form 8-K filed June 20, 2013	2-97230 TNMP
Indentures‡
PNMR
4.1	Indenture, dated as of March 15, 2005, between PNMR and JPMorgan Chase Bank, N.A., as Trustee	10.2 to PNMR’s Current Report on Form 8-K filed March 31, 2005	1-32462 PNMR
4.2	Supplemental Indenture No. 1, dated as of March 30, 2005, between the Company and JPMorgan Chase Bank, N.A. as Trustee, with Form of Senior Note included as Exhibit A thereto	10.3 to PNMR’s Current Report on Form 8-K filed March 31, 2005	333-32170 PNMR
4.3	Supplemental Indenture No. 2, dated as of May 16, 2008 between PNMR and The Bank of New York Trust Company, N.A. (successor to JPMorgan Chase Bank, N.A.), as trustee	4.3 to PNMR’s Current Report on Form 8-K filed May 21, 2008	1-32462 PNMR
4.4	Agreement of Resignation, Appointment and Acceptance, effective as of June 1, 2011, among PNMR, The Bank of New York Mellon Trust Company, N.A. and Union Bank, N.A. (for March 15, 2005 PNMR Indenture)	4.1 to the Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2011	1-32462 PNMR

D- 2

PNM
4.5	Indenture (for Senior Notes), dated as of March 11, 1998, between PNM and The Chase Manhattan Bank, as Trustee	4.4 to PNM’s Quarterly Report on Form 10-Q for the quarter ended March 31, 1998	1-6986 PNM
4.6	First Supplemental Indenture, dated as of March 11, 1998, supplemental to Indenture, dated as of March 11, 1998, Between PNM and The Chase Manhattan Bank, as Trustee	4.5 to PNM’s Quarterly Report on Form 10-Q for the quarter ended March 31, 1998	1-6986 PNM
4.7	Second Supplemental Indenture, dated as of March 11, 1998, supplemental to Indenture, dated as of March 11, 1998, Between PNM and The Chase Manhattan Bank, as Trustee	4.6 to PNM’s Quarterly Report on Form 10-Q for the quarter ended March 31, 1998	1-6986 PNM
4.8	Third Supplemental Indenture, dated as of October 1, 1999 to Indenture dated as of March 11, 1998, between PNM and The Chase Manhattan Bank, as Trustee	4.6.1 to PNM’s Annual Report on Form 10-K for the fiscal year ended December 31, 1999	1-6986 PNM
4.9	Fourth Supplemental Indenture, dated as of May 1, 2003 to Indenture dated as of March 11, 1998, between PNM and JPMorgan Chase Bank (formerly The Chase Manhattan Bank), as Trustee	4.6.2 to PNM’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2003	1-6986 PNM
4.10	Fifth Supplemental Indenture, dated as of May 1, 2003 to Indenture dated as of March 11, 1998, between PNM and JPMorgan Chase Bank, as Trustee	4.6.3 to PNM’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2003	1-6986 PNM
4.11	Sixth Supplemental Indenture, dated as of May 1, 2003 to Indenture dated as of March 11, 1998, between PNM and JPMorgan Chase Bank, as Trustee	4.6.4 to PNM’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2003	1-6986 PNM
4.12	Seventh Supplemental Indenture, dated as of June 1, 2007 to Indenture dated as of March 11, 1998, between PNM and The Bank of New York Trust Company, N.A. (successor to JPMorgan Chase Bank), as Trustee	4.23 to PNM’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2007	1-6986 PNM
4.13	Eighth Supplemental Indenture, dated as of June 1, 2010 to Indenture dated as of March 11, 1988, between PNM and The Bank of New York Mellon Trust Company (successor to JPMorgan Chase Bank), as Trustee	10.1 to PNM’s Current Report on Form 8-K/A filed July 29, 2010	1-6986 PNM
4.14	Ninth Supplemental Indenture, dated as of June 1, 2010 to Indenture dated as of March 11, 1988, between PNM and The Bank of New York Mellon Trust Company (successor to JPMorgan Chase Bank), as Trustee	10.2 to PNM’s Current Report on Form 8-K/A filed July 29, 2010	1-6986 PNM
4.15	Agreement of Resignation, Appointment and Acceptance effective as of May 1, 2011, among PNM, The Bank of New York Mellon Trust Company, N.A. and Union Bank, N.A. (for March 11, 1998 PNM Indenture)	4.2 to PNM’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2011	1-6986 PNM
4.16	Tenth Supplemental Indenture, dated as of September 1, 2012, between PNM and Union Bank, N.A.(ultimate successor as trustee to The Chase Manhattan Bank), as Trustee	4.1 to PNM’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2012	1-6986 PNM
4.17	Indenture (for Senior Notes), dated as of August 1, 1998, between PNM and The Chase Manhattan Bank, as Trustee	4.1 to PNM’s Registration Statement No. 333-53367	333-53367 PNM
4.18	First Supplemental Indenture, dated August 1, 1998, supplemental to Indenture, dated as of August 1, 1998, between PNM and The Chase Manhattan Bank, as Trustee	4.3 to PNM’s Current Report on Form 8-K Dated August 7, 1998	1-6986 PNM
4.19	Second Supplemental Indenture, dated September 1, 2003, supplemental to Indenture, dated as of August 1, 1998, between PNM and JPMorgan Chase Bank (formerly, The Chase Manhattan Bank), as Trustee	4.7.1 to PNM’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2003	1-6986 PNM

D- 3

4.20	Third Supplemental Indenture, dated as of May 13, 2008 between PNM and The Bank of New York Trust Company, N.A. as trustee	4.1 to PNM’s Current Report on Form 8-K filed May 15, 2008	1-6986 PNM
4.21	Agreement of Resignation, Appointment and Acceptance, effective as of June 1, 2011, among PNM, The Bank of New York Mellon Trust Company and Union Bank, N.A. (for August 1, 1998 PNM Indenture)	4.3 to the Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2011	1-6986 PNM
4.22	Fourth Supplemental Indenture, dated as of October 12, 2011, to the Indenture, dated as of August 1, 1998, between PNM and Union Bank, N.A. (ultimate successor as trustee to The Chase Manhattan Bank), as trustee	4.1 to PNM’s Current Report on Form 8-K filed October 12, 2011	1-6986 PNM
TNMP
4.23	The First Mortgage Indenture dated as of March 23, 2009, between TNMP and The Bank of New York Mellon Trust Company, N.A., as Trustee	4.1 to TNMP’s Current Report on Form 8-K filed March 27, 2009	2-97230 TNMP
4.24	The First Supplemental Indenture dated as of March 23, 2009, between TNMP and The Bank of New York Mellon Trust Company, N.A., as Trustee	4.2 to TNMP’s Current Report on Form 8-K filed March 27, 2009	2-97230 TNMP
4.25	The Second Supplemental Indenture dated as of March 25, 2009, between TNMP and The Bank of New York Mellon Trust Company, N.A., as Trustee	4.3 to TNMP’s Current Report on Form 8-K filed March 27, 2009	2-97230 TNMP
4.26	The Third Supplemental Indenture dated as of April 30, 2009 between TNMP and The Bank of New York Mellon Trust Company, N.A., as Trustee	4.1 to TNMP’s Current Report on Form 8-K filed May 6, 2009	2-97230 TNMP
4.27	First Amendment dated as of December 16, 2010 between TNMP and The Bank of New York Mellon Trust Company, N.A., as Trustee to The Third Supplemental Indenture dated as of April 30, 2009	4.1 to TNMP’s Current Report on Form 8-K filed December 17, 2010	2-97230 TNMP
4.28	Agreement of Resignation, Appointment and Acceptance, effective as of June 1, 2011, among TNMP, The Bank of New York Mellon Trust Company, N.A. and Union Bank, N.A. (for March 23, 2009 TNMP Indenture)	4.4 to TNMP’s Quarterly Report Form 10-Q for the quarter ended June 30, 2011	2-97230 TNMP
4.29	Fourth Supplemental Indenture dated as of September 30, 2011 between TNMP and Union Bank, N.A., as Trustee	4.1 to TNMP’s Current Report on Form 8-K filed October 6, 2011	2-97230 TNMP
4.30	Fifth Supplemental Indenture dated as of April 3, 2013 between TNMP and Union Bank, N.A., as Trustee	4.1 to TNMP’s Current Report on Form 8-K filed April 3, 2013	2-97230 TNMP
4.31	Sixth Supplemental Indenture dated as of June 27, 2014 between TNMP and Union Bank, N.A., as Trustee	4.1 to TNMP’s Current Report on Form 8-K filed June 27, 2014	2-97230 TNMP
Material Contracts
10.5	Credit Agreement, dated as of October 31, 2011, among PNM Resources, Inc., the lenders party thereto, Wells Fargo Bank, National Association, as Administrative Agent and Union Bank, N.A., as Syndication Agent	10.1 to the Company’s Current Report on Form 8-K filed October 31, 2011	1-32462 PNMR
10.6	First Amendment to Credit Agreement dated January 18, 2012 among PNMR, the lenders party thereto and Wells Fargo Bank, National Association, as Administrative Agent	10.1 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2011	1-32462 PNMR
10.7	Second Amendment to Credit Agreement dated October 31, 2013 among PNMR, the lenders party thereto and Wells Fargo Bank, National Association, as Administrative Agent	10.2 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2013	1-32462 PNMR
10.8	Third Amendment to Credit Agreement dated December 17, 2014 among PNMR, the lenders party thereto and Wells Fargo Bank, National Association, as Administrative Agent	10.1 to the Company’s Current Report on Form 8-K filed December 17, 2014	1-32462 PNMR

D- 4

10.9	Second Amended and Restated Term Loan Agreement dated as of December 22, 2014 among PNMR, the lender parties (JPMorgan Chase Bank, N.A. and Union Bank, N.A.) and JPMorgan Chase Bank, N.A., as administrative agent	10.1 to PNMR’s to the Company’s Current Report on Form 10-K December 22, 2014	1-32462 PNMR
10.10	Credit Agreement, dated as of October 31, 2011, among PNM, the lenders party thereto, Wells Fargo Bank, National Association, as Administrative Agent and Union Bank, N.A., as Syndication Agent	10.2 to PNM’s Current Report on Form 8-K filed October 31, 2011	1-6986 PNM
10.11	First Amendment to Credit Agreement dated January 18, 2012 among PNM, the lenders party thereto, and Wells Fargo Bank, National Association, as Administrative Agent	10.2 to PNM’s Annual Report on Form 10-K for the year ended December 31, 2011	1-6986 PNM
10.12	Second Amendment to Credit Agreement executed December 17, 2014 and fully effective as of January 22, 2015	10.2 to the Company’s Current Report on Form 8-K filed December 17, 2014	1-6986 PNM
10.13	Credit Agreement, dated as of January 8, 2014, among PNM, the lenders identified therein, and U.S. Bank National Association, as Administrative Agent and BOKF, N.A. d/b/a Bank of Albuquerque, as Syndication Agent	10.1 to PNM’s Current Report on Form 8-K filed January 8, 2014	1-6986 PNM

10.14	Term Loan Agreement dated as of April 22, 2013, among PNM, the lenders identified therein and Union Bank, N.A. as administrative agent		10.1 to PNM’s Current Report on Form 8-K filed April 23, 2013			1-6986 PNM
10.15		Term Loan Agreement dated as of December 22, 2014 between PNM and JPMorgan Chase Bank, as lender and administrative agent		10.2 to PNM’s Current Report on Form 8-K filed December 22, 2014		1-6987 PNM
10.16		Second Amended and Restated Credit Agreement, dated as of September 18, 2013, among TNMP, the lenders identified therein and Key Bank National Association, as administrative agent		10.1 to TNMP’s Current Report on Form 8-K filed September 18, 2013		2-97230 TNMP
10.17		Term Loan Credit Agreement dated as of September 30, 2011, among TNMP, as borrower, the lenders identified therein, and JPMorgan Chase Bank, N.A., as administrative agent		10.1 to TNMP’s Current Report on Form 8-K filed October 6, 2011		2-97230 TNMP
10.18		Bond Purchase Agreement dated December 9, 2013 between TNMP and the purchasers named therein (for $80,000,000 4.03% First Mortgage Bonds, due 2024, Series 2014A)		10.1 to TNMP’s Current Report on Form 8-K filed December 10, 2013		2-97230 TNMP
10.19**		PNM Resources, Inc. 2014 Performance Equity Plan dated May 15, 2014		4.3 to PNMR’s Form S-8 Registration Statement filed May 15, 2014	333-195974 PNMR
10.20**		PNM Resources, Inc. Second Amended and Restated Omnibus Performance Equity Plan dated May 19, 2009		4.1 to PNM Resources’ Form S-8 Registration Statement filed May 20, 2009		333-159361 PNMR
10.21**		Amendment dated May 17, 2011 to PNMR’s Second Amended and Restated Omnibus Performance Equity Plan		10.1 to PNMR’s Current Report Form 8-K filed May 20, 2011		1-32462 PNMR
10.22**		Second Amendment executed March 28, 2012 to the PNMR Second Amended and Restated Omnibus Performance Equity Plan		10.6 to PNMR’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2012		1-32462 PNMR
10.23**		Third Amendment (approved by PNMR shareholders on May 15, 2012) to the PNMR Second Amended and Restated Omnibus Performance Equity Plan		10.1 to PNMR’s Current Report on Form 8-K filed May 17, 2012		1-32462 PNMR
10.24**		PNM Resources, Inc. 2014 Officer Annual Incentive Plan dated March 20, 2014		10.1 to PNMR’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2014		1-32462 PNMR

D- 5

10.25**	PNM Resources, Inc. 2013 Officer Annual Incentive Plan dated March 29, 2013	10.1 to PNMR’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2013	1-32462 PNMR
10.26**	PNM Resources, Inc. 2014 Long-Term Incentive Plan dated March 20, 2014	10.2 to PNMR’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2014	1-32464 PNMR
10.27**	PNM Resources, Inc. 2013 Long-Term Incentive Plan dated March 29, 2013	10.2 to PNMR’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2013	1-32462 PNMR
10.28**	PNM Resources, Inc. 2012 Long-Term Incentive Plan dated March 28, 2012	10.2 to the Company Quarterly Report on Form 10-Q for the quarter ended March 31, 2012	1-32462 PNMR
10.29**	Acknowledgment Form for officer performance share awards granted under Second Amended Restated Omnibus Performance Equity Plan dated May 19, 2009, as amended	10.4.1 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2014	1-32462 PNMR
10.30**	Form of Stock Option Award Agreement for non-qualified stock options granted under performance equity plan in 2010	10.3 to PNMR’s Current Report on Form 8-K filed May 26, 2009	1-32462 PNMR
10.31**	Form of the award agreement for non- qualified stock options granted under performance equity plan in 2007-2009	10.2 to the Company’s Current Report on Form 8-K filed February 16, 2007	1-32462 PNMR
10.32**	Acknowledgement Forms for restricted stock rights awards granted under the Second Amended and Restated Omnibus Performance Equity Plan dated May 19, 2009, as amended	10.6 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2013	1-32462 PNMR
10.33**	Special Performance-Based Retention Award Agreement between PNMR and Patricia K. Collawn dated March 29, 2012	10.3 to the Company’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2012	1-32462 PNMR
10.34*	Employee Retention Agreement executed December 9, 2014 between PNMR and Charles N. Eldred	10.2 to PNMR’s Annual Report on For 10-K for the year ended December 31, 2014	1-32462 PNMR
10.35**	Acknowledgement Form for officer restricted stock rights awards granted under the PNM Resources, Inc. 2014 Performance Equity Plan dated May 15, 2014	10.4.2 to PNMR’s Annual Report on For 10-K for the year ended December 31, 2014	1-32462 PNMR
10.36**	2013 Director Compensation Summary (2014 annual retainer is the same as the 2013 annual retainer)	10.1 to PNMR’s Annual Report on Form 10-K for the year ended December 31, 2012	1-32462 PNMR
10.37**	2015 Director Compensation Summary	10.1.1 to PNMR’s Annual Report on Form 10-K for the year ended December 31, 2014	1-32462 PNMR
10.38**	Acknowledgement Forms for restricted stock rights and stock option awards granted to directors under the Second Amended and Restated Omnibus Performance Equity Plan dated May 19, 2009, as amended	10.3 to the Company’s Current Report on Form 8-K filed March 1, 2011	1-32462 PNMR
10.39**	Acknowledgment Form with attached Terms and Conditions for restricted stock rights awards granted to directors under the PNM Resources, Inc. 2014 Performance Equity Plan dated May 15, 2014	10.4.3 to PNMR’s Annual Report on Form 10-K for the year ended December 31, 2014	1-32462 PNMR
10.40**	PNM Resources, Inc. Executive Spending Account Plan (amended and restated effective January 1, 2011)	10.4 to the Company’s Current Report on Form 8-K filed March 1, 2011	1-32462 PNMR
10.41**	PNM Resources, Inc. Executive Savings Plan II (amended and restated effective January 1, 2015)	10.1.2 to PNMR’s Annual Report on Form 10-K for the year ended December 31, 2014	1-32462 PNMR

D- 6

10.42**	PNM Resources, Inc. After-Tax Retirement Plan effective January 1, 2009	10.5 to PNMR’s Annual Report on Form 10-K for the fiscal year ended December 31, 2008	1-32462 PNMR
10.43**	First Amendment executed March 28, 2012 to the PNMR After-Tax Retirement Plan	10.5 to PNMR’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2012	1-32462 PNMR
10.44**	Second, Third and Fourth Amendments, each effective January 1, 2014, to the PNM Resources, Inc. After-Tax Retirement Plan	10.5 to PNMR’s Annual Report on Form 10-K for the year ended December 31, 2013	1-32462 PNMR
10.45**	Summary of Executive Time Off Policy Effective January 1, 2006	10.31 to the Company’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2005	1-32462 PNMR
10.46**	Amendment to Corporate Policy Absence from Work Policy 125 executed December 16, 2011	10.6 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2011	1-32462 PNMR
10.47**	PNM Resources, Inc. Annual Executive Physical Exam Program Wraparound Plan Document effective as of January 1, 2014	10.7 to PNMR’s Annual Report on Form 10-K for the fiscal year ended December 31, 2013	1-32462 PNMR
10.48**	PNM Resources, Inc. Non-Union Severance Pay Plan effective August 1, 2007 (amended and restated)	10.3 to the Company’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007	1-32462 PNMR
10.49**	First Amendment to the PNM Resources Non-Union Severance Pay Plan executed November 20, 2008	10.3 to PNMR’s Annual Report on Form 10-K for the fiscal year ended December 31, 2008	1-32462 PNMR
10.50**	Second Amendment (executed March 27, 2012) to PNMR Non-Union Severance Pay Plan	10.8 to PNMR’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2012	1-32462 PNMR
10.51**	PNM Resources, Inc. Officer Retention Plan executed March 28, 2012 as amended and restated effective as of January 1, 2012	10.7 to the Company’s Quarterly Report in Form 10-Q for the quarter ended March 31, 2012	1-32462 PNMR
10.52**	PNM Resources, Inc. Director Retainer Plan, dated December 31, 2001	4.3 to PNM Resources, Inc. Post-Effective Amendment No. 1 to Form S-8 Registration Statement filed December 31, 2001	333-03289 PNMR
10.53**	First Amendment dated February 17, 2003 to PNM Resources, Inc. Director Retainer Plan	10.40.1 to the Company’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2003	333-32170 PNMR
10.54**	PNM Resources Officer Life Insurance Plan dated April 28, 2004	10.24.1 to the Company’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2004	333-32170 PNMR
10.55**	First Amendment to PNM Resources Officer Life Insurance Plan dated December 16, 2004	10.27 to the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2004.	333-32170 PNMR
10.56**	Second Amendment to PNM Resources Officer Life Insurance Plan executed April 15, 2007	10.5 to the Company’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007	1-32462 PNMR
10.57**	Third Amendment to the PNMR Officer Life Insurance Plan effective January 1, 2009	10.10 to PNMR’s Annual Report on Form 10-K for the fiscal year ended December 31, 2008	1-32462 PNMR

D- 7

10.58**	Fourth Amendment to the PNMR Officer Life Insurance Plan effective January 1, 2009	10.15 to PNMR’s Annual Report on Form 10-K for the fiscal year ended December 31, 2008	1-32462 PNMR
10.59**	Fifth Amendment to the PNM Resources, Inc. Officer Life Insurance Plan executed December 16, 2011	10.5 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2011	1-32462 PNMR
10.60**	Executive Long Term Disability Plan effective January 1, 2003	10.88 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2002	333-32170 PNMR
10.61	Supplemental Indenture of Lease dated as of July 19, 1966 between PNM and other participants in the Four Corners Project and the Navajo Indian Tribal Council	4-D to PNM’s Registration Statement No. 2-26116	2-26116 PNM
10.62	Amendment and Supplement No. 1 to Supplemental and Additional Indenture of Lease dated April 25, 1985 between the Navajo Tribe of Indians and Arizona Public Service Company, El Paso Electric Company, Public Service Company of New Mexico, Salt River Project Agricultural Improvement and Power District, Southern California Edison Company, and Tucson Electric Power Company (refiled)	10.1.1 to PNM’s Annual Report on Form 10-K for fiscal year ended December 31, 1995	1-6986 PNM
10.63	Amendment and Supplement No. 2 to Supplemental and Additional Indenture of Lease with the Navajo Nation dated March 7, 2011	10.1 to PNM’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2011	1-6986 PNM
10.64	Amendment and Supplement No. 3 to Supplemental and Additional Indenture of Lease with the Navajo Nation dated March 7, 2011	10.2 to PNM’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2011	1-6986 PNM
10.65	Water Supply Agreement between the Jicarilla Apache Tribe and Public Service Company of New Mexico, dated July 20, 2000	10.5 to PNM’s Quarterly Report of Form 10-Q for the quarter ended September 30, 2001	1-6986 PNM
10.66	Arizona Nuclear Power Project Participation Agreement among PNM and Arizona Public Service Company, Salt River Project Agricultural Improvement and Power District, Tucson Gas & Electric Company and El Paso Electric Company, dated August 23, 1973	5-T to PNM’s Registration Statement No. 2-50338	2-50338 PNM
10.67	Amendments No. 1 through No. 6 to Arizona Nuclear Power Project Participation Agreement	10.8.1 to PNM’s Annual Report on Form 10-K for fiscal year ended December 31, 1991	1-6986 PNM
10.68	Amendment No. 7 effective April 1, 1982, to the Arizona Nuclear Power Project Participation Agreement (refiled)	10.8.2 to PNM’s Annual Report on Form 10-K for fiscal year ended December 31, 1991	1-6986 PNM
10.69	Amendment No. 8 effective September 12, 1983, to the Arizona Nuclear Power Project Participation Agreement (refiled)	10.58 to PNM’s Annual Report on Form 10-K for fiscal year ended December 31, 1993	1-6986 PNM
10.70	Amendment No. 9 to Arizona Nuclear Power Project Participation Agreement dated as of June 12, 1984 (refiled)	10.8.4 to PNM’s Annual Report of the Registrant on Form 10-K for fiscal year ended December 31, 1994	1-6986 PNM
10.71	Amendment No. 10 dated as of November 21, 1985 and Amendment No. 11 dated as of June 13, 1986 and effective January 10, 1987 to Arizona Nuclear Power Project Participation Agreement (refiled)	10.8.5 to PNM’s Annual Report of the Registrant on Form 10-K for fiscal year ended December 31, 1995	1-6986 PNM
10.72	Amendment No. 12 to Arizona Nuclear Power Project Participation Agreement dated June 14, 1988, and effective August 5, 1988	19.1 to PNM’s Quarterly Report on Form 10-Q for the quarter ended September 30, 1990	1-6986 PNM
10.73	Amendment No. 13 to the Arizona Nuclear Power Project Participation Agreement dated April 4, 1990, and effective June 15, 1991	10.8.10 to PNM’s Annual Report on Form 10-K for the fiscal year ended December 31, 1990	1-6986 PNM

D- 8

10.74	Amendment No. 14 to the Arizona Nuclear Power Project Participation Agreement effective June 20, 2000	10.8.9 to PNM’s Annual Report on Form 10-K for the fiscal year ended December 31, 2000	1-6986 PNM
10.75	Amendment No. 15 to the Arizona Nuclear Power Project Participation Agreement dated November 29, 2010 and effective January 13, 2011	10.1 to PNM’s Current Report on Form 8-K filed March 1, 2011	1-6986 PNM
1076	Amendment No. 16, effective as of April 28, 2014, to the Arizona Nuclear Power Project Participation Agreement	10.3 to PNM’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2014	1-6986 PNM
10.77	Underground Coal Sales Agreement, dated August 31, 2001 among San Juan Coal Company, PNM and Tucson Electric Power Company	10.85 to PNM’s Quarterly Report on Form 10-Q for the quarter ending September 30, 2001 (Confidential treatment was requested for portions of this exhibit, and such portions were omitted from this exhibit filed and were filed separately with the Securities and Exchange Commission)	1-6986 PNM
10.78	Amendment One to Underground Coal Sales Agreement dated December 15, 2003 among San Juan Coal Company, PNM and Tucson Electric Coal Company	10.9.1 to PNM’s Amended Report on Form 10-K for fiscal year ended December 31, 2003 (Confidential treatment was requested for portions of this exhibit, and such portions were omitted from this exhibit filed and were filed separately with the Securities and Exchange Commission)	1-6986 PNM
10.79	Amendment Two to Underground Coal Sales Agreement effective September 15, 2004 among San Juan Coal Company, PNM and Tucson Electric Coal Company	10.9.2 to PNM’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2004	1-6986 PNM
10.80	Amendment Three to Underground Coal Sales Agreement executed April 29, 2005 among San Juan Coal Company, PNM and Tucson Electric Coal Company (Confidential treatment was requested for portions of this exhibit, and such portions were omitted from this exhibit filed and were filed separately with the Securities and Exchange Commission)	10.86.1 to the Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2005	1-6986 PNM
10.81	Amendment Four to Underground Coal Sales Agreement effective March 7, 2007 among San Juan Coal Company, PNM and Tucson Electric Coal Company	10.89 to PNM’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2007	1-6986 PNM
10.82	Amendment Five to Underground Coal Sales Agreement executed December 21, 2007 among San Juan Coal Company, PNM and Tucson Electric Power Company (Confidential treatment was requested for portions of this exhibit, and such portions were omitted from this exhibit filed and were filed separately with the Securities and Exchange Commission)	10.95 to PNM’s Annual Report on Form 10-K for the year ended December 31, 2007	1-6986 PNM
10.83	Amendment No. Six to Underground Coal Sales Agreement executed October 2, 2014 among San Juan Coal Company, PNM and Tucson Electric Power Company and acknowledged by San Juan Transportation Company	10.1 to PNM’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2014	1-6986 PNM
10.83.1	Extension of LOI Deadline Under Amendment No. Six to Underground Coal Sales Agreement among SJCC, PNM and Tucson dated February 20, 2015	10.3 to the Company’s Annual Report on Form 10-K for the year ended December, 31 2014	1-6986 PNM

D- 9

10.84	San Juan Generation Station Fuel and Capital Funding Agreement dated September 12, 2014 among PNM, Tucson Electric Power Company, The City of Farmington, New Mexico, M-S-R Public Power Agency, The Incorporated County of Los Alamos, New Mexico, Southern California Public Power Authority, City of Anaheim, Utah Associated Municipal Power Systems, and Tri-State Generation and Transmission Association, Inc.	10.2 to PNM’s Quarter Report on Form 10-Q for the quarter ended September 30, 2014	1-6986 PNM
10.85	Participation Agreement among PNM, Tucson Electric Power Company and certain financial institutions relating to the San Juan Coal Trust dated as of December 31, 1981 (refiled)	10.14 to PNM’s Annual Report on Form 10-K for fiscal year ended December 31, 1992	1-6986 PNM
10.86	Participation Agreement dated as of June 30, 1983 among Security Trust Company, as Trustee, PNM, Tucson Electric Power Company and certain financial institutions relating to the San Juan Coal Trust (refiled)	10.61 to PNM’s Annual Report on Form 10-K for fiscal year ended December 31, 1993	1-6986 PNM
10.87	Amended and Restated San Juan Project Participation Agreement dated as of March 23, 2006, among Public Service Company of New Mexico, Tucson Electric Power Company, The City of Farmington, New Mexico, M-S-R Public Power Agency, The Incorporated County of Los Alamos, New Mexico, Southern California Public Power Authority, City of Anaheim, Utah Associated Municipal Power System and Tri-State Generation and Transmission Association, Inc.	10.119 to PNM’s Quarterly Report on Form 10-Q for the quarter ended March 30, 2006	1-6986 PNM
10.88*	Facility Lease dated as of December 16, 1985 between The First National Bank of Boston, as Owner Trustee, and PNM (Unit 1 transaction) together with Amendments No. 1, 2 and 3 thereto (refiled)	10.18 to PNM’s Annual Report on Form 10-K for fiscal year ended December 31, 1995	1-6986 PNM
10.89*	Amendment No. 4 dated as of December 11, 2013 to Facility Lease dated as of December 16, 1985 as heretofore amended, between U.S. Bank National Association (ultimate successor to The First National Bank of Boston), as Owner Trustee, and PNM (Unit 1 transaction)	10.3 to PNM’s Annual Report on Form 10-K for fiscal year ended December 31, 2013	1-6986 PNM
10.90	Facility Lease dated as of July 31, 1986, between the First National Bank of Boston, as Owner Trustee, and PNM (Unit 1 transaction) together with Amendments No. 1, 2 and 3 thereto (refiled)	10.19 to PNM’s Annual Report on Form 10-K for fiscal year ended December 31, 1996	1-6986 PNM
10.91*	Facility Lease dated as of August 12, 1986, between The First National Bank of Boston, as Owner Trustee, and PNM (Unit 2 transaction) together with Amendments No. 1 and 2 thereto (refiled)	10.20 to PNM’s Annual Report on Form 10-K for fiscal year ended December 31, 1996	1-6986 PNM
10.92	Amendment No. 2 dated as of April 10, 1987 to Facility Lease dated as of August 12, 1986 (Unit 2 transaction), as amended, between The First National Bank of Boston, not in its individual capacity, but solely as Owner Trustee under a Trust Agreement, dated as of August 12, 1986, with MFS Leasing Corp., Lessor and Public Service Company of New Mexico, Lessee (refiled)	10.20.2 to PNM’s Annual Report on Form 10-K for fiscal year ended December 31, 1998	1-6986 PNM
10.93	Facility Lease dated as of December 15, 1986, between The First National Bank of Boston, as Owner Trustee, and PNM (Unit 1 Transaction) together with Amendment No. 1 thereto (refiled)	10.21 to PNM’s Annual Report on Form 10-K for fiscal year ended December 31, 1996	1-6986 PNM

D- 10

10.94	Amendment No. 2 dated as of March 18, 2014, to the Facility Lease dated December 15, 1986, as heretofore amended, between U.S. Bank National Association, not in its individual capacity, but solely as Owner Trustee under a Trust Agreement ,dated as of December 15, 1986, with PV2-PNM December 35 Corporation, Lessor, and PNM, Lessee	10.1 to PNM’s Current Report on Form 8-K filed March 18, 2014	1-6986 PNM
10.95	Letter Agreement dated February 25, 2014, between Public Service Company of New Mexico and CGI Capital, Inc.	10.1 to PNM’s Current Report on Form 8-K filed February 28, 2014	1-6986 PNM
10.96	Letter Agreement dated May 1, 2014, among PNM, PNMR Development and Management Corporation, Cypress Verde LLC, and Cypress Second PV Partnership	10.4 to PNM’s Quarter Repot on Form 10-Q for the quarter ended March 31, 2014	1-6986 PNM
10.97	Facility Lease dated as of December 15, 1986, between The First National Bank of Boston, as Owner Trustee, and PNM (Unit 2 Transaction) together with Amendment No. 1 thereto (refiled)	10.22 to PNM’s Annual Report on Form 10-K for fiscal year ended December 31, 1996	1-6986 PNM
10.98	Master Decommissioning Trust Agreement for Palo Verde Nuclear Generating Station dated March 15, 1996, between Public Service Company of New Mexico and Mellon Bank, N.A.	10.68 to PNM’s Quarterly Report on Form 10-Q for the quarter ended March 31, 1996	1-6986 PNM
10.99	Amendment Number One to the Master Decommissioning Trust Agreement for Palo Verde Nuclear Generating Station dated January 27, 1997, between Public Service Company of New Mexico and Mellon Bank, N.A.	10.68.1 to PNM’s Annual Report on Form 10-K for fiscal year ended December 31, 1997	1-6986 PNM
10.100	Amendment Number Two to the Master Decommissioning Trust Agreement for Palo Verde Nuclear Generating Station between Public Service Company of New Mexico and Mellon Bank, N.A.	10.68.2 to PNM’s Annual Report on Form 10-K for fiscal year ended December 31, 2003	1-6986 PNM
10.101	PVNGS Capital Trust-Variable Rate Trust Notes-PVNGS Note Agreement dated as of July 31, 1998	10.76 to PNM’s Quarterly Report on Form 10-Q for the quarter ended September 30, 1998	1-6986 PNM
10.102	Stipulation in the matter of PNM’s transition plan Utility Case No. 3137, dated October 10, 2002 as amended by Amendment to Stipulated Agreement dated October 18, 2002	10.86 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2002	1-6986 PNM
10.103	Stipulation dated February 28, 2005 in NMPRC Case No. 04-00315-UT regarding the application of PNM Resources and TNMP for approval of the TNP acquisition	10.134 to the Company’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2005	1-32462 PNMR/ TNMP
10.104	Consent Decree entered into by PNM on March 9, 2005 relating to the citizen suit under the Clean Air Act and the excess emissions report matter for SJGS	10.135 to the Company’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2005	1-6986 PNM
Subsidiaries
21	Certain subsidiaries of PNM Resources	21 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2014	1-32462 PNMR

D- 11

Additional Exhibits
99.1*	Participation Agreement dated as of December 16, 1985, among the Owner Participant named therein, First PV Funding Corporation, The First National Bank of Boston, in its individual capacity and as Owner Trustee (under a Trust Agreement dated as of December 16, 1985 with the Owner Participant), Chemical Bank, in its individual capacity and as Indenture Trustee (under a Trust Indenture, Mortgage, Security Agreement and Assignment of Rents dated as of December 16, 1985 with the Owner Trustee), and PNM (Unit 1 transaction), including Appendix A definitions, together with Amendment No. 1 dated July 15, 1986 and Amendment No. 2 dated November 18, 1986 (refiled)	99.2 to PNM’s Annual Report on Form 10-K for fiscal year ended December 31, 1995	1-6986 PNM
99.2*	Trust Indenture, Mortgage, Security Agreement and Assignment of Rents dated as of December 16, 1985, between the First National Bank of Boston, as Owner Trustee, and Chemical Bank, as Indenture Trustee together with Supplemental Indentures Nos. 1 and 2 (Unit 1 transaction) (refiled)	99.3 to PNM’s Quarterly Report on Form 10-Q for the quarter ended March 31, 1996	1-6986 PNM
99.3*	1996 Supplemental Indenture dated as of September 27, 1996 to Trust Indenture, Mortgage, Security Agreement and Assignment of Rents dated as of December 16, 1985 between State Street Bank and Trust Company, as Owner Trustee, and The Chase Manhattan Bank, as Indenture Trustee (Unit 1 transaction)	99.21 to PNM’s Quarterly Report on Form 10-Q for the quarter ended September 30, 1996	1-6986 PNM
99.4*	Assignment, Assumption and Further Agreement dated as of December 16, 1985, between Public Service Company of New Mexico and The First National Bank of Boston, as Owner Trustee (Unit 1 transaction)	28(c) to PNM’s Current Report on Form 8-K dated December 31, 1985	1-6986 PNM
99.5	Participation Agreement dated as of July 31, 1986, among the Owner Participant named herein, First PV Funding Corporation, The First National Bank of Boston, in its individual capacity and as Owner Trustee (under a Trust Agreement dated as of July 31, 1986, with the Owner Participant), Chemical Bank, in its individual capacity and as Indenture Trustee (under a Trust Indenture, Mortgage, Security Agreement and Assignment of Rents dated as of July 31, 1986, with the Owner Trustee), and Public Service Company of New Mexico, including Appendix A definitions together with Amendment No. 1 thereto (refiled)	99.5 to PNM’s Annual Report on Form 10-K for fiscal year ended December 31, 1996	1-6986 PNM
99.6	Trust Indenture, Mortgage, Security Agreement and Assignment of Rents dated as of July 31, 1986, between The First National Bank of Boston, as Owner Trustee, and Chemical Bank, as Indenture Trustee together with Supplemental Indenture No. 1 thereto (refiled)	99.6 to PNM’s Annual Report on Form 10-K for fiscal year ended December 31, 1996	1-6986 PNM
99.7	Assignment, Assumption, and Further Agreement dated as of July 31, 1986, between Public Service Company of New Mexico and The First National Bank of Boston, as Owner Trustee (refiled)	99.7 to PNM’s Annual Report on Form 10-K for fiscal year ended December 31, 1996	1-6986 PNM
99.8*	Participation Agreement dated as of August 12, 1986, among the Owner Participant named therein, First PV Funding Corporation, The First National Bank of Boston, in its individual capacity and as Owner Trustee (under a Trust Agreement dated as of August 12, 1986, with the Owner Participant), Chemical Bank, in its individual capacity and as Indenture Trustee (under a Trust Indenture, Mortgage, Security Agreement and Assignment of Rents dated as of August 12, 1986, with the Owner Trustee), and PNM, including Appendix A definitions (Unit 2 transaction) (refiled)	99.8 to PNM’s Quarterly Report on Form 10-Q for the quarter ended March 31, 1997	1-6986 PNM

D- 12

99.9*	Amendment No. 1 dated as of November 18, 1986, to Participation Agreement dated as of August 12, 1986 (Unit 2 transaction) (refiled)	99.8.1 to PNM’s Quarterly Report on Form 10-Q for the quarter ended March 31, 1997	1-6986 PNM
99.10*	Trust Indenture, Mortgage, Security Agreement and Assignment of Rents dated as of August 12, 1986, between the First National Bank of Boston, as Owner Trustee, and Chemical Bank, as Indenture Trustee together with Supplemental Indenture No. 1 thereto (refiled) (Unit 2 transaction)	99.9 to PNM’s Annual Report of the Registrant on Form 10-K for fiscal year ended December 31, 1996	1-6986 PNM
99.11	1997 Supplemental Indenture, dated as of December 23, 1997, to Trust Indenture, Mortgage, Security Agreement and Assignment of Rents, dated as of August 12, 1986, between State Street Bank and Trust, as Owner Trustee, and The Chase Manhattan Bank, as Indenture Trustee	99.22 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2006	1-6986 PNM
99.12*	Assignment, Assumption, and Further Agreement dated as of August 12, 1986, between Public Service Company of New Mexico and The First National Bank of Boston, as Owner Trustee (Unit 2 transaction) (refiled)	99.10 to PNM’s Quarterly Report on Form 10-Q for the quarter ended March 31, 1997	1-6986 PNM
99.13	Participation Agreement dated as of December 15, 1986, among the Owner Participant named therein, First PV Funding Corporation, The First National Bank of Boston, in its individual capacity and as Owner Trustee (under a Trust Agreement dated as of December 15, 1986, with the Owner Participant), Chemical Bank, in its individual capacity and as Indenture Trustee (under a Trust Indenture, Mortgage, Security Agreement and Assignment of Rents dated as of December 15, 1986, with the Owner Trustee), and Public Service Company of New Mexico, including Appendix A definitions (Unit 1 Transaction) (refiled)	99.11 to PNM’s Quarterly Report on Form 10-Q for the quarter ended March 31, 1997	1-6986 PNM
99.14	Trust Indenture, Mortgage, Security Agreement and Assignment of Rents dated as of December 15, 1986, between The First National Bank of Boston, as Owner Trustee, and Chemical Bank, as Indenture Trustee (Unit 1 Transaction) (refiled)	99.12 to PNM’s Quarterly Report on Form 10-Q for the quarter ended March 31, 1997	1-6986 PNM
99.15	Assignment, Assumption and Further Agreement dated as of December 15, 1986, between Public Service Company of New Mexico and The First National Bank of Boston, as Owner Trustee (Unit 1 Transaction) (refiled)	99.13 to PNM’s Quarterly Report on Form 10-Q for the quarter ended March 31, 1997	1-6986 PNM
99.16	Participation Agreement dated as of December 15, 1986, among the Owner Participant named therein, First PV Funding Corporation, The First National Bank of Boston, in its individual capacity and as Owner Trustee (under a Trust Agreement dated as of December 15, 1986, with the Owner Participant), Chemical Bank, in its individual capacity and as Indenture Trustee (under a Trust Indenture, Mortgage, Security Agreement and Assignment of Rents dated as of December 15, 1986, with the Owner Trustee), and Public Service Company of New Mexico, including Appendix A definitions (Unit 2 Transaction) (refiled)	99.14 to PNM’s Quarterly Report on Form 10-Q for the quarter ended March 31, 1997	1-6986 PNM
99.17	Trust Indenture, Mortgage, Security Agreement and Assignment of Rents dated as of December 31, 1986, between the First National Bank of Boston, as Owner Trustee, and Chemical Bank, as Indenture Trustee (Unit 2 Transaction) (refiled)	99.15 to PNM’s Annual Report on Form 10-K for fiscal year ended December 31, 1996	1-6986 PNM

D- 13

99.18	Assignment, Assumption, and Further Agreement dated as of December 15, 1986, between Public Service Company of New Mexico and The First National Bank of Boston, as Owner Trustee (Unit 2 Transaction) (refiled)	99.16 to PNM’s Quarterly Report on Form 10-Q for the quarter ended March 31, 1997	1-6986 PNM
99.19	Agreement for the Sale and Purchase of Wastewater Effluent, dated November 13, 2000, among the City of Tolleson, Arizona Public Service Company and Salt River Project Agricultural Improvement and Power District	99.19 to PNM’s Annual Report on Form 10-K for fiscal year ended December 31, 2013	1-6986 PNM
99.20	Municipal Effluent Purchase and Sale Agreement dated April 23, 2010 between Cities of Phoenix, Mesa, Tempe, Scottsdale and Glendale, Arizona municipal corporations; and APS, SRP, acting on behalf of themselves and EPE, SCE, PNM, SCPPA, and Los Angeles Department of Water and Power	10.6 to the Company’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2010	1-6986 PNM

* One or more additional documents, substantially identical in all material respects to this exhibit, have been entered into, relating to one or more additional sale and leaseback transactions. Although such additional documents may differ in other respects (such as dollar amounts and percentages), there are no material details in which such additional documents differ from this exhibit.

** Designates each management contract or compensatory plan or arrangement required to be identified pursuant to paragraph 3 of Item 15(a) of Form 10-K.

‡     Certain instruments defining the rights of holders of long-term debt of the registrants included in the financial statements of registrants filed herewith have been omitted because the total amount of securities authorized thereunder does not exceed 10% of the total assets of registrants. The registrants hereby agree to furnish a copy of any such omitted instrument to the SEC upon request.

D- 14

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

			PNM RESOURCES, INC.
			(Registrant)
Date:	February 27, 2015	By	/s/ P. K. Collawn
			P. K. Collawn
			Chairman, President, and Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the Registrant and in the capacities and on the dates indicated.

Signature	Capacity	Date
/s/ P. K. Collawn	Principal Executive Officer and Director	February 27, 2015
P. K. Collawn
Chairman, President, and
Chief Executive Officer
/s/ C. N. Eldred	Principal Financial Officer	February 27, 2015
C. N. Eldred
Executive Vice President and
Chief Financial Officer
/s/ T. G. Sategna	Principal Accounting Officer	February 27, 2015
T. G. Sategna
Vice President and
Corporate Controller
/s/ A. E. Archuleta	Director	February 27, 2015
A. E. Archuleta
/s/ E. R. Conley	Director	February 27, 2015
E. R. Conley
/s/ A. J. Fohrer	Director	February 27, 2015
A. J. Fohrer
/s/ M. T. Mullarkey	Director	February 27, 2015
M. T. Mullarkey
/s/ R. R. Nordhaus	Director	February 27, 2015
R. R. Nordhaus
/s/ D. K. Schwanz	Director	February 27, 2015
D. K. Schwanz
/s/ B. W. Wilkinson	Director	February 27, 2015
B. W. Wilkinson
/s/ J. B. Woodard	Director	February 27, 2015
J. B. Woodard

E-1

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

			PUBLIC SERVICE COMPANY OF NEW MEXICO
			(Registrant)
Date:	February 27, 2015	By	/s/ P. K. Collawn
			P. K. Collawn
			President and Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the Registrant and in the capacities and on the dates indicated.

Signature	Capacity	Date
/s/ P. K. Collawn	Principal Executive Officer and Chairman of the Board	February 27, 2015
P. K. Collawn
President and
Chief Executive Officer
/s/ C. N. Eldred	Principal Financial Officer and Director	February 27, 2015
C. N. Eldred
Executive Vice President and
Chief Financial Officer
/s/ T. G. Sategna	Principal Accounting Officer	February 27, 2015
T. G. Sategna
Vice President and
Corporate Controller
	Director
R. N. Darnell
/s/ R. E. Talbot	Director	February 27, 2015
R. E. Talbot

E-2

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

			TEXAS-NEW MEXICO POWER COMPANY
			(Registrant)
Date:	February 27, 2015	By	/s/ P. K. Collawn
			P. K. Collawn
			Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the Registrant and in the capacities and on the dates indicated.

Signature	Capacity	Date
/s/ P. K. Collawn	Principal Executive Officer and Chairman of the Board	February 27, 2015
P. K. Collawn
Chief Executive Officer
/s/ T. G. Sategna	Principal Financial Officer and Principal Accounting Officer	February 27, 2015
T. G. Sategna
Vice President and
Controller
	Director
R. N. Darnell
/s/ C. N. Eldred	Director	February 27, 2015
C. N. Eldred
/s/ R. E. Talbot	Director	February 27, 2015
R. E. Talbot
/s/ J. N. Walker	Director	February 27, 2015
J. N. Walker

E-3

EX-3.4

Exhibit 3.4

BYLAWS

OF

PNM RESOURCES, INC.

With all Amendments to and Including February 26, 2015

BYLAWS

OF

PNM RESOURCES, INC.

ARTICLE I

MEETINGS OF SHAREHOLDERS

Section 1. Meetings

The annual meeting of shareholders shall be held at the time and place set by resolution of the Board of Directors for the election of directors and the transaction of such other business as may properly come before the meeting.

Special meetings may be called by a majority of the Board of Directors, the Chairman of the Board, the Chief Executive Officer or by holders of not less than one-tenth of all the shares entitled to vote at the meeting.

Section 2. Notice

Written notice of any meeting stating the time and place, and if a special meeting, the purpose, of the meeting shall be mailed to each shareholder of record entitled to vote at the meeting at the address of the shareholder as it appears on the stock transfer books of the Corporation, except as otherwise provided by law. Notices of special meetings called by a majority of the Board of Directors, the Chairman of the Board or the Chief Executive Officer, and of annual meetings shall be mailed not less than ten (10) days nor more than fifty (50) days before the meeting. Notices of other special shareholder meetings shall be mailed not less than forty (40) days nor more than fifty (50) days before the date of the meeting.

1

Section 3. Adjournment

Whenever a quorum is not present at any meeting of the shareholders, or whenever it may be deemed desirable, a majority in interest of the shareholders present in person or by proxy may adjourn the meeting from time to time to any future date, without notice other than by announcement at the meeting. At any continuation of the adjourned meeting at which a quorum is present, any business may be transacted which might have been transacted at the meeting originally scheduled.

Section 4. Order of Business

(a) The Chairman of the Board, or in the absence of the Chairman, the Chief Executive Officer, or in their absence, a director designated by the Board of Directors, shall call meetings of the shareholders to order and shall act as Chairman of the meeting. The shareholders may appoint any shareholder or the proxy of any shareholder to act as Chairman of any meeting of the shareholders in the absence of the Chairman of the Board, Chief Executive Officer and a director designated by the Board to serve as Chairman of the meeting. The Secretary, or in the absence of the Secretary, an Assistant Secretary, shall act as Secretary at all meetings of the shareholders, but in the absence of the Secretary and Assistant Secretary at any meetings of the shareholders, the Chairman of the meeting may appoint any person to act as Secretary of the meeting.

(b) The Chairman of the meeting shall have the right to determine the order of business at the meeting, to prescribe the rules and procedures for the conduct of the meeting, and to do all things necessary or desirable for the proper conduct of the meeting, including maintenance of order and safety and limitations on the time allotted to questions or comments on the affairs of the Corporation.

2

(c) The only business that may be conducted at an annual meeting of shareholders is that business which has been brought before the meeting: (i) by or at the direction of the Chairman of the meeting; (ii) pursuant to the notice of the meeting; or (iii) by any shareholder who is a holder of record at the time of the giving of the notice of the meeting who is entitled to vote at the meeting and who complies with the procedures set forth in Section 4 (d) and any applicable rules of the Securities and Exchange Commission (“SEC”).

(d)For business, including nomination of director candidates or other proposals pursuant to rules promulgated by the SEC, to be properly brought before an annual meeting by a shareholder, the shareholder must have given timely notice of the proposal in proper written form to the Secretary of the Corporation. If a nomination of director candidates or other proposal is brought pursuant to SEC rules, a shareholder must comply with the rule’s requirements, as well as the requirements set forth in this Section 4(d). To be timely under this Section 4(d), a shareholder’s notice must be delivered to or mailed and received at the Secretary’s office at least one hundred twenty (120) days before: (a) the date on which the Notice of Internet Availability of Proxy Materials (“Eproxy Notice”) for the prior year’s annual meeting of shareholders was first mailed, or (b) if no such Eproxy Notice was mailed, the date on which the proxy materials for the prior year’s annual meeting of shareholders were first mailed. To be in proper written form, a shareholder’s notice to the Secretary shall set forth in writing as to each matter the shareholder proposes to bring before the annual meeting:

(i) in the case of nomination of a director candidate, a description of the proposed candidate’s qualifications for the position, a brief summary of no more than five hundred (500) words providing reasons why the candidate is being

3

nominated, and the information required by subparts (iii), (iv), (v) and (vi) of this Section 4(d);

(ii) in the case of business other than the nomination of a director candidate, a brief description of the business desired to be brought before the annual meeting, the reasons for conducting the business at the annual meeting and the information required by subparts (iii), (iv), (v) and (vi) of this Section 4(d);

(iii) the name and address of the shareholder proposing the business and all persons or entities acting in concert with the shareholder;

(iv) the class and number of shares of the Corporation which are beneficially owned by the shareholder and all persons or entities acting in concert with the shareholder;

(v) the holding of any economic interest in the Corporation through derivative positions, including, swaps, options, and forwards, by the shareholder and all persons or entities acting in concert with the shareholder; and

(vi) any material interest of the shareholder in the proposed business.

The notice requirements set forth in this Section 4(d) shall not be waived nor shall they be deemed to have been satisfied by virtue of the fact that the Corporation has initiated its own process for electing directors at the annual meeting or for considering other business properly before the annual meeting.

Section 5. Inspectors

At each meeting of the shareholders at which a vote by ballot is taken, the polls shall be opened and closed, the proxies and ballots shall be collected, and the validity of proxies and the acceptance or rejection of votes shall be decided by two inspectors. No person who is a

4

candidate for the office of director shall act as inspector of any election for directors. The inspectors shall be appointed by the Board of Directors before the meeting or, if no appointment has been made, then by the Chairman of the meeting. If for any reason any of the inspectors previously appointed fails to attend or refuses or is unable to serve, those inspectors not serving shall be replaced by inspectors appointed by the Chairman of the meeting.

Section 6. Voting

At meetings of shareholders, every shareholder having voting rights as provided for in the Articles of Incorporation shall be entitled to one (1) vote for each share of stock outstanding in the name of the shareholder on the books of the Corporation on the date on which shareholders entitled to vote are determined or as otherwise provided for in the Articles of Incorporation. Each shareholder may be represented and vote by a proxy or proxies appointed by an instrument in writing or other manner authorized by the Board of Directors to the extent permitted by law. If the instrument designates two (2) or more persons to act as proxies, a majority of the proxies present at the meeting may exercise all of the powers conferred by the instrument unless the instrument provides otherwise. No proxy shall be voted at any meeting or continuation of an adjourned meeting other than that for which the proxy is given.

In all elections for directors, voting shall be by written ballot, or by electronic, telephonic or other process as the Board of Directors may authorize, to the extent permitted by law.

The Board of Directors may fix a date in advance not exceeding fifty (50) days before the date of any meeting of shareholders as a record date for the determination of shareholders entitled to notice of and to vote at the meeting. Only shareholders of record on the date so fixed shall be entitled to notice of and to vote at the meeting.

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ARTICLE II

DIRECTORS

Section 1. Number, Election and Terms

The business and property of the Corporation shall be managed under the direction of the Board of Directors. The Board of Directors shall, by resolution, fix the number of directors which shall be no less than five (5) and no more than twelve (12) in number who shall be elected annually.

Section 2. Compensation

Directors shall receive compensation for their services as directors as may be fixed by resolution of the Board of Directors, including reimbursement for expenses for Board related services.

Section 3. Meetings

The meetings of the Board of Directors shall be held at the times and places designated by the Board of Directors. The annual meeting of the Board of Directors for the election of officers and such other business as may properly come before the meeting shall be held immediately following the annual meeting of shareholders. Special meetings of the Board of Directors shall be held whenever called at the direction of the Chairman of the Board, the Chief Executive Officer, or any two (2) directors if there are less than nine (9) directors on the Board, or any three (3) directors if there are nine (9) or more directors on the Board.

Section 4. Notice

No notice shall be required of any annual or regular meeting of the Board of Directors unless the place has been changed from that last designated by the Board of Directors. Notice of any annual or regular meeting, when required, or of any special meeting, of the Board of

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Directors shall be given to each director in writing or by telephone at least twenty-four (24) hours before the time fixed for the meeting. Notice may be waived by any director. Unless otherwise indicated in the notice, any and all business may be transacted at a special meeting. At any meeting at which every director is present, even without notice, any business may be transacted.

Section 5. Adjournments

Any annual, regular or special meeting of the Board of Directors may be adjourned from time to time by the members present whether or not a quorum is present, and no notice shall be required of any continuation of an adjourned meeting beyond the announcement at the adjourned meeting.

Section 6. Indemnification

Each person serving as a director or an officer of the Corporation, or, at the request of the Corporation, as a director or an officer of any other company in which the Corporation has a financial interest and regardless of whether or not the person is then in office, and the heirs, executors, administrators and personal representatives of the person, shall be indemnified by the Corporation to the full extent of the authority of the Corporation to so indemnify as authorized by New Mexico law.

Section 7. Committees

The Board of Directors may designate from among its members one (1) or more committees, to exercise the power and authority and perform the functions that the Board may determine, except as may be limited by law.

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Section 8. General Board Attributes

Recognizing that the contribution of the Board will depend not only on the character and capabilities of the directors taken individually but also on their collective strengths, the Board shall be composed of:

a. directors chosen with a view toward bringing to the Board a variety of experience and background relevant to the Company's business;

b. directors who will form a balanced core of business executives with varied expertise including having accounting or related financial management expertise;

c. directors who have substantial experience outside the business community ‑‑ in the public, academic or scientific communities, for example;

d. directors who are financially literate and who satisfy the definition of audit committee financial expert promulgated by the New York Stock Exchange;

(e) directors who will represent the balanced, best interests of the shareholders as a whole rather than special interest groups or constituencies; and

(f) a majority of directors who are independent according to criteria established by the New York Stock Exchange.

Section 9. Director Qualifications

In addition to conformance to the general board attributes described above, candidates for election as directors should possess the following qualifications:

(a) each director should be an individual of the highest character and integrity and have an inquiring mind, vision and the ability to work well with others and exercise good judgment;

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(b) each director should be free of any conflict of interest which would violate any applicable law or regulation or interfere with the proper performance of the responsibilities of a director;

(c) each director should possess substantial and significant experience which would be of particular importance to the Company in the performance of the duties of a director;

(d) each director should have sufficient time available to devote to the affairs of the Company in order to carry out the responsibilities of a director;

(e) each director should have the capacity and desire to represent the balanced, best interests of the shareholders as a whole and not primarily a special interest group or constituency; and

(f) each director should have an equity ownership interest in the Company consistent with the approved director stock ownership guidelines.

ARTICLE III

CONTRACTS AND NEGOTIABLE INSTRUMENTS

Section 1. Authority to Sign Contracts

Unless the Board of Directors shall otherwise specifically direct, all contracts, instruments, documents or agreements of the Corporation shall be executed in the name of the Corporation by the Chief Executive Officer, or any officer, or any other employee, if approved by the Chief Executive Officer by either administrative policy letter or other specific written designation. It shall not be necessary that the corporate seal be affixed to any contract.

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Section 2. Authority to Sign Negotiable Instruments

Except as otherwise authorized by the Board of Directors, all checks, drafts, bills of exchange, promissory notes, electronic funds transfer documents, and other negotiable instruments shall be signed by the Chairman of the Board, Chief Executive Officer, Secretary, Treasurer or other officer. Facsimile signatures shall be sufficient to meet the requirements of this section.

Section 3. Approval by Shareholders

The Board of Directors in its discretion may submit any contract, or act, for approval or ratification at any annual meeting of the shareholders, or at any special meeting of the shareholders called for the purpose of considering the act or contract. Except as provided for in the Articles of Incorporation, any contract or act that shall be approved or ratified by the vote of the holders of a majorityof the capital stock of the Corporation which is represented in person or by proxy at the meeting shall be valid and binding upon the Corporation.

ARTICLE IV

OFFICERS

Section 1. Number, Election and Term

The Corporation shall have such officers, with titles and duties as shall be stated in resolutions adopted by the Board of Directors, as the Board in its discretion deems necessary or appropriate to conduct the business activities of the Corporation. The officers shall be elected annually by the Board of Directors at the annual meeting and who shall hold office until the next annual meeting or until a successor is elected and qualifies. The Board of Directors shall designate from among the officers a Chief Executive Officer, a Chief Financial Officer, a Chief Accounting Officer or Controller, a Treasurer and a Secretary who shall have the duty to record

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the proceedings of the meetings of the Board of Directors. The Board of Directors may elect one person to serve as both Chairman of the Board and Chief Executive Officer. The Board of Directors may from time to time appoint such additional officers as the interest of the Corporation may require and fix their terms and duties of office. A vacancy occurring in any office may be filled by the Board of Directors. All officers shall hold office at the discretion of the Board of Directors and shall be subject to removal at any time by the affirmative vote of a majority of the whole Board of Directors. Election of any person as an officer of the Corporation shall not of itself create contract rights. The Chairman of the Board shall have the authority to designate officers subject to election by the Board of Directors at its next meeting following the Chairman’s designation.

Section 2. Chairman of the Board of Directors

The Chairman of the Board shall be elected annually by the Board of Directors at the annual meeting and shall hold that office until a successor is elected and qualifies. In the event of the incapacity of the Chairman of the Board, the Board of Directors shall, by a majority vote of the Board of Directors, designate an Acting Chairman who shall, during the incapacity of the Chairman of the Board, assume and perform all functions and duties which the Chairman of the Board is authorized or required by law to do. The Chairman of the Board shall have the power to call special meetings of the shareholders and of the directors for any purpose. The Chairman of the Board shall preside at all meetings of the shareholders and of the Board of Directors unless the Chairman of the Board is absent or incapacitated. The Chairman of the Board, subject to the authority of the Board of Directors, shall generally do and perform all acts incident to the office of the Chairman of the Board and which are authorized or required by law.

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Section 3. Chief Executive Officer

The Chief Executive Officer shall provide active management over all operations of the Corporation subject to control of the Board of Directors. The Chief Executive Officer shall have the power to appoint and discharge, subject to the general approval or review by the Board of Directors, employees and agents of the Corporation and to fix their compensation, to make and sign contracts and agreements in the name of and on behalf of the Corporation and direct the general management and control of the business and affairs of the Corporation. The Chief Executive Officer may delegate authority to officers of the Corporation as the Chief Executive Officer may determine. The Chief Executive Officer shall have the power to segregate the operations of the Corporation into areas of responsibility. The Chief Executive Officer shall see that the books, reports, statements and certificates required by law are properly kept, made, and filed, and shall generally do and perform all acts which are authorized or required by law. The Chief Executive Officer shall designate an officer who shall, during the absence or incapacity of the Chief Executive Officer, assume and perform all functions and duties which the Chief Executive Officer might lawfully do if present in person and not under any incapacity.

Section 4. Other Officers

Each officer shall be responsible for the areas and activities assigned by the Chief Executive Officer, shall be subject to the authority of the Chief Executive Officer and shall assist in the general control and management of the business and affairs of the Corporation.

Section 5. Secretary

The Secretary shall keep a record in the proper books provided for that purpose of meetings and proceedings of shareholders, the Board of Directors and Committees of the Board of Directors, and shall record all votes of the directors and shareholders in a book to be kept for

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that purpose. The Secretary shall notify the directors and shareholders of meetings as required by law or by the Bylaws of the Corporation and shall perform other duties as may be required by law or the Bylaws of the Corporation, or which may be assigned from time to time by the Board of Directors, Chairman of the Board or Chief Executive Officer. The Secretary is authorized to appoint one or more assistants from time to time as the Secretary deems advisable, the assistant or assistants to serve at the pleasure of the Secretary, andto perform the duties that are delegated by the Secretary. An assistant shall not be an officer of the Corporation.

Section 6. Treasurer

The Treasurer shall have the custody of all the funds and securities of the Corporation, and shall have the power on behalf of the Corporation to sign checks, notes, drafts and other evidences of indebtedness, to borrow money for the current needs of the business of the Corporation and to make short‑term investments of surplus funds of the Corporation. The Treasurer shall render to the Board of Directors, the Chairman of the Board or the Chief Executive Officer, whenever requested, an account of all transactions performed as Treasurer and of the financial condition of the Corporation. The Treasurer shall perform other duties as may be assigned by the Board of Directors, the Chairman of the Board or the Chief Executive Officer. The Treasurer is authorized to appoint one or more assistants from time to time as the Treasurer deems advisable, the assistant or assistants to serve at the pleasure of the Treasurer, and to perform the duties that are delegated by the Treasurer. An assistant shall not be an officer of the Corporation.

Section 7. Controller

The Controller shall be the chief accounting officer of the Corporation and have full responsibility and control of the accounting practices of the Corporation. The Controller shall,

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subject to the approval of the Board of Directors, the Chairman of the Board or the Chief Executive Officer, establish accounting policies. The Controller shall standardize and coordinate accounting practices, supervise all accounting records and the presentation of all financial statements and tax returns. The Controller shall have other powers and duties as, from time to time, may be conferred by the Board of Directors, the Chairman of the Board or the Chief Executive Officer. The Controller is authorized to appoint one or more assistants from time to time as the Controller deems advisable, the assistant or assistants to serve at the pleasure of the Controller, and to perform the duties that are delegated by the Controller. An assistant shall not be an officer of the Corporation.

Section 8. Form of Appointment

In making any appointments of assistants, the Secretary, Treasurer and Controller shall use the following form:

I, ________________ (Name), the duly elected _______________ (Title) of PNM Resources, Inc. do hereby appoint

(Name) to serve as Assistant (Title) for the period of (Date) to (Date), unless this appointment is terminated earlier in writing, to assume or perform all functions and duties which I might require and, in my absence or incapacity, which I might lawfully do if present and not under any incapacity.

Any appointments of assistants by the Secretary, Treasurer or Controller and any terminations of appointments shall be maintained in the records of the Secretary’s office.

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ARTICLE V

CAPITAL STOCK

Section 1. Certificates of Stock

The name of the person owning shares of the capital stock of the Corporation, together with the number of shares and the date of issue, shall be entered on the Corporation’s books. All certificates surrendered to the Corporation shall be canceled, and no new certificates shall be issued until a certificate or certificates aggregating the same number of shares of the same class have been surrendered or canceled. The Board of Directors may make proper provision, from time to time, for the issuance of new certificates in place of lost, destroyed or stolencertificates.

Section 2. Transfer Agents and Registrars

The Corporation shall, if and whenever the Board of Directors determines, maintain one or more transfer offices or agencies, each in charge of a transfer agent designated by the Board of Directors, where the shares of the capital stock of the Corporation will be directly transferable, and also one or more registry offices, each in charge of a registrar designated by the Board of Directors, where shares of stock will be registered, and no certificates for shares of the capital stock of the Corporation, in respect of which one or more transfer agents and registrars shall have been designated, shall be valid unless countersigned by one of such transfer agents and registered by one of such registrars. The Board of Directors may also make additional rules and regulations as it may deem expedient concerning the issue, transfer and registration of certificates for shares of the capital stock of the Corporation.

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Section 3. Shares Held for Account

The Board of Directors may adopt by resolution a procedure whereby a shareholder of the Corporation may certify in writing to the Corporation that all or a portion of the shares registered in the name of the shareholder are held for the account of a specified person or persons as provided for by New Mexico law.

Section 4. Transfer of Shares

Transfers of shares shall be made only upon the books of the Corporation by the holderor by the holder’s attorney in fact upon surrender of certificates for a like number of shares.

Section 5. Lost, Destroyed or Stolen Certificates

A new certificate of stock may be issued in the place of any certificate previously issued by the Corporation, or any predecessor of the Corporation, alleged to have been lost, destroyed or stolen. The Board of Directors may, in its discretion, require the owner of the lost, destroyed or stolen certificate to give to the Corporation satisfactory evidence that the certificate was lost, destroyed or stolen. The Board of Directors may also require a bond sufficient to indemnify it and its transfer agent, against any claim that may be made on account of the alleged loss of the certificate or the issuance of any new certificate.

Section 6. Fixing of Record Dates

For the purpose of determining shareholders entitled to notice of any meeting of shareholders, or entitled to receive payment of any dividend, or in order to make a determination of shareholders for any other proper purpose, the Board of Directors may, by resolution, provide that the stock transfer books be closed for a stated period not to exceed fifty (50) days. If the stock transfer books are closed for the purpose of determining shareholders entitled to notice of a

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meeting of shareholders, the books shall be closed for at least ten (10) days immediately prior to the meeting.

In lieu of closing the stock transfer books, the Board of Directors may, by resolution, fix in advance a date as the record date for any determination of shareholders, the date to be not more than fifty (50)days and, in case of a meeting of shareholders, not less than ten (10)days prior to the date on which the action requiring the determination of shareholders is to be taken.

Section 7. Uncertificated Shares

The Corporation and each transfer agent designated by the Board of Directors are authorized to issue, register and transfer shares of capital stock of the Corporation (including fractional shares) in uncertificated book-entry form, provided that, within a reasonable time after the issuance or transfer of uncertificated shares, the corporation shall send, or cause the transfer agent to send, to the registered owner thereof a written notice containing the information required by applicable law.

ARTICLE VI

MISCELLANEOUS PROVISIONS

Section 1. Books

The books of the Corporation, except as otherwise provided by law, may be kept outside of the State of New Mexico, at such place or places as may be designated by the Board of Directors. The Board of Directors shall determine whether and to what extent, and at what time and places, and under what conditions and regulations, the accounts and the books of the Corporation, or any of them, shall be open to the inspection of shareholders; and no shareholder shall have any right to inspect any book or account or document of the Corporation except as conferred by the statutes of New Mexico, or authorized by the Board of Directors.

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Section 2. Corporate Seal

The common corporate seal is, and until otherwise ordered by the Board of Directors shall be, an impression circular in form upon paper or wax bearing the words “PNM Resources, Inc.Incorporated 2000.” The seal shall be in the charge of the Secretary. If and when directed by the Board of Directors, a duplicate of the seal may be kept and used by the Treasurer or by an Assistant Secretary or Assistant Treasurer.

Section 3. Fiscal Year

The fiscal year of the Corporation shall be as determined by the Board of Directors.

Section 4. Principal Office

The principal office shall be established and maintained at a place designated by the Board of Directors.

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EX-10.1.1

Exhibit 10.1.1

2015 Director Compensation Summary

Non-employee directors of PNM Resources, Inc. (the “Company”) receive their annual retainer in the form of cash and stock-based compensation as determined by the Company's Board of Directors (the “Board”). At the December 2014 Board meeting, the Board approved making the following changes to director compensation for 2015: increasing the annual cash retainer from $52,500 to $60,000, increasing the Finance Committee and Nominating and Governance Committee chair fees from $5,000 to $7,500, and increasing the market value of the annual award of restricted stock rights from $65,000 to $75,000. Thus, the 2015 annual retainer for non-employee directors is as follows:

Annual Retainer:	An annual cash retainer of $60,000 paid in quarterly installments and restricted stock rights* with a grant date market value of $75,000
Annual Presiding Lead Director Fee:	$20,000 paid in quarterly installments
Annual Committee Chair Fee:	$ 7,500 paid in quarterly installments (in addition to meeting attendance fees), except that the annual chair fee for the Audit and Ethics Committee and Compensation and Human Resources Committee is $10,000
Committee Meeting Attendance Fees:	$ 1,500 per Board Committee meeting

Directors are also reimbursed for any Board-related expenses, such as travel expenses incurred to attend Board and Board committee meetings and director educational programs. Further, directors are indemnified by the Company to the fullest extent permitted by law pursuant to the Company's bylaws and indemnification agreements between the Company and each director.

* The amount of the annual award of restricted stock rights is determined by dividing $75,000 by the closing price of the Company's stock on the New York Stock Exchange on the day of the grant. Restricted stock rights granted under the Company's Performance Equity Plan each vest in three equal annual installments beginning on the first anniversary of the grant date, subject to vesting acceleration upon retirement from the board. These awards are typically made at the annual meeting of directors, unless the meeting occurs during a black-out period for trading in the Company's securities as specified in the Company's Insider Trading Policy. As set forth under the Company's Equity Compensation Awards Policy, under those circumstances, the Board will either (a) schedule a special meeting after the expiration of the black-out period, (b) make awards pursuant to a unanimous written consent executed after the expiration of the black-out period, or (c) pre-approve the equity awards with an effective date after the expiration of the black-out period. The date of the awards is the date on which the Board approves the awards, unless (i) the approval date is a non-trading day, in which case the date is the immediately preceding trading date or (ii) in the case of pre-approval during a black-out period, in which case the grant date is the first trading date after the expiration of the black-out period.

EX-10.1.2

062014

Exhibit 10.1.2

PNM RESOURCES, INC.
EXECUTIVE SAVINGS PLAN II

062014

PNM RESOURCES, INC.
EXECUTIVE SAVINGS PLAN II

PREAMBLE

Effective as of December 15, 2004, PNM Resources, Inc. (the “Company”) established the PNM Resources, Inc. Executive Savings Plan II (the “Plan”). The purpose of the Plan is to permit certain key employees of the Company and its Affiliates who participate in the PNM Resources, Inc. Retirement Savings Plan (the “RSP”) to defer compensation and receive credits under this Plan without reference to the limitations on contributions in the RSP or those imposed by the Internal Revenue Code of 1986, as amended (the “Code”). The Plan was previously amended and restated effective January 1, 2009 to satisfy the requirements of Section 409A of the Code. The 2009 restated Plan was amended on two previous occasions.

Except as noted below, this amended and restated Plan document is effective as of January 1, 2015 (the “Effective Date”).

ARTICLE IDEFINITIONS

1.1General. When a word or phrase appears in this Plan with the initial letter capitalized, and the word or phrase does not begin a sentence, the word or phrase shall generally be a term defined in this Article I. The following words and phrases used in the Plan with the initial letter capitalized shall have the meanings set forth in this Article I, unless a clearly different meaning is required by the context in which the word or phrase is used or the word or phrase is defined for a limited purpose elsewhere in this Plan document:

(a)“Account” means the Discretionary Credit Account, Matching Credit Account, Standard Credit Account, Supplemental Credit Account, Supplemental Deferral Account or other account into which contributions are contributed by the Company on behalf of the Participant pursuant to this Plan.

(b)“Adopting Affiliate” means any Affiliate of the Company that has been authorized by the Board of Directors to adopt the Plan and which has adopted the Plan in accordance with Section 2.5 (Adoption by Affiliates). All Affiliates that adopted the Plan prior to this amendment and restatement shall continue as Adopting Affiliates.

(c)“Affiliate” means (1) a corporation which is a member of the same controlled group of corporations (within the meaning of Section 414(b) of the Code) as is the Company, and (2) any other trade or business (whether or not incorporated) controlling, controlled by, or under common control with the Company (within the meaning of Section 414(c) of the Code).

(d)“After-Tax Retirement Plan” means the PNM Resources, Inc. After-Tax Retirement Plan, as it may be amended from time to time. The After-Tax Retirement Plan will terminate on June 30, 2015.

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(e)“Benefits Department” means the organizational unit of PNMR Services Company with responsibility for administering benefit programs sponsored by PNM Resources and its Affiliates.

(f)“Benefits Governance Committee” means the Benefits Governance Committee or its successor appointed by the Company.

(g)“Board”or “Board of Directors” means the Board of Directors of the Company, or any authorized committee of the Board.

(h)“Change in Control” shall have the meaning ascribed to that term in the Retention Plan in which the Participant participates (i.e., the Officer Retention Plan or the Employee Retention Plan).

(i)“Code” means the Internal Revenue Code of 1986, as amended from time to time, and any regulations promulgated thereunder.

(j)“Company” means PNM Resources, Inc., and, to the extent provided in Section 10.6 (Successors) below, any successor corporation or other entity resulting from a merger or consolidation into or with the Company or a transfer or sale of substantially all of the assets of the Company.

(k)“Company Stock” means common stock, no par value, issued by the Company.

(l)“Company Stock Fund” means the hypothetical Investment Fund described in Section 5.3 (Special Company Stock Fund Provisions).

(m)“Compensation” for purposes of determining the Matching and Standard Credits, means the Participant’s base salary and other elements of compensation that are considered under the RSP (as it may be amended from time to time) for purposes of calculating the Participant’s RSP Employer and Matching Contributions, respectively. For purposes of determining the amount of a Participant’s permissible Supplemental Deferrals, “Compensation” means the Participant’s base salary and other elements of compensation that are considered under the RSP (as it may be amended from time to time) for purposes of calculating the Participant’s RSP Before Tax Contributions. For purposes of determining Compensation under this Plan, the limitations imposed by Section 401(a)(17) of the Code shall not apply.

(n)“Compensation and Human Resources Committee” means the Compensation and Human Resources Committee of the Board or its successor.

(o)“Corporate Investment Committee” means the Corporate Investment Committee or its successor appointed by the Company.

(p)“Disability” or “Disabled” means that a Participant is, by reason of any medically determinable physical or mental impairment that can be expected to result in death or can be expected to last for a continuous period of not less than 12 months, receiving income replacement benefits for a period of not less than 3 months under the Company’s long term

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disability plan. Any determination of Disability pursuant to the Plan is not an admission by the Company or the Adopting Affiliate that employs the Participant that a Participant is disabled under federal or state law.

(q)“Discretionary Credit Account” means the account maintained under the Plan to record the amounts credited to a Participant in accordance with Section 3.5 (Discretionary Credits).

(r)“Discretionary Credits” means the Discretionary Credits allocated to a Participant’s Discretionary Credit Account in accordance with Section 3.5 (Discretionary Credits).

(s)“Distribution Election Form” means the election form by which a Participant elects the manner in which his Accounts shall be distributed pursuant to Section 6.2 (Form of Distribution).

(t)“Effective Date” means January 1, 2015.

(u)“Eligible Officer” means a Participant who (1) occupies the position of Senior Vice President or higher of the Company, (2) has completed at least three Months of Service, and (3) has been selected by the Plan Administrator with the advance consent of the Compensation and Human Resources Committee to receive a Supplemental Credit.

(v)“Employee Retention Plan” means the PNM Resources, Inc. Employee Retention Plan, as it may be amended or replaced from time to time.

(w)“ERISA” means the Employee Retirement Income Security Act of 1974, as amended from time to time, and any regulations promulgated thereunder.

(x)“ESP I” means the PNM Resources, Inc. Executive Savings Plan.

(y)“Investment Fund” means the hypothetical investment fund or funds established by the Plan Administrator pursuant to Article V (Adjustment of Accounts).

(z)“Matching Credit Account” means the account maintained under the Plan to record the amounts credited to a Participant in accordance with Section 3.3(a) (Matching and Standard Credits – Matching Credit).

(aa)“Matching Credits” means the Matching Credits allocated to a Participant’s Matching Credit Account in accordance with Section 3.3(a) (Matching and Standard Credits – Matching Credit).

(bb)“Month of Service” means a calendar month during which a Participant performs services for the Company or an Adopting Affiliate on one or more days. If the Participant’s employment with the Company or an Adopting Affiliate includes a break in employment, then only the Months of Service in the last period of employment will be considered Months of Service.

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(cc)“Normal Retirement Date” means the date on which a Participant attains the age of 62 years.

(dd)“Officer Retention Plan” means the PNM Resources, Inc. Officer Retention Plan, as it may be amended or replaced from time to time.

(ee)“Participant” means an employee of the Company or any Adopting Affiliate who has been designated or selected for participation in the Plan pursuant to Section 2.2 (Selection of Participants) and who has not received all amounts to which he is entitled pursuant to the Plan. The Plan document occasionally distinguishes between Participants and “Active Participants.” When this distinction is made, the term “Active Participant” refers to a Participant who is currently employed by the Company or an Adopting Affiliate.

(ff)“Plan” means the PNM Resources, Inc. Executive Savings Plan II, as set forth herein.

(gg)“Plan Administrator” means the Company. Any action to be taken by the Plan Administrator may be taken by the Company’s senior human resources officer. In addition, the Company’s senior human resources officer may delegate such authority to the Benefits Department.

(hh)“Plan Year” means the calendar year.

(ii)“Recordkeeper” means the entity selected by the Company to keep Plan records and to adjust Accounts pursuant to Section 5.1 (Adjustment of Accounts) of the Plan.

(jj)“RSP” means the PNM Resources, Inc. Retirement Savings Plan, as it may be amended from time to time.

(kk)“RSP Before Tax Contribution” means “Before Tax Contributions,” as such term is defined in the RSP.

(ll)“RSP Employer Contribution” means “Discretionary Contributions,” as such term is defined in the RSP.

(mm)“RSP Matching Contribution” means “Matching Contributions,” as such term is defined in the RSP.

(nn)“Separation from Service” means either (1) the termination of a Participant’s employment with the Company and all Affiliates due to death, retirement or other reasons, or (2) a permanent reduction in the level of bona fide services the Participant provides to the Company and all Affiliates to an amount that is 20% or less of the average level of bona fide services the Participant provided to the Company and all Affiliates in the immediately preceding 36 months, with the level of bona fide service calculated in accordance with Treas. Reg. § 1.409A‑1(h)(1)(ii).

A Participant’s employment relationship is treated as continuing while the Participant is on military leave, sick leave, or other bona fide leave of absence (if the period of

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such leave does not exceed six months, or if longer, so long as the Participant’s right to reemployment with the Company or an Affiliate is provided either by statute or contract). If the Participant’s period of leave exceeds six months and the Participant’s right to reemployment is not provided either by statute or by contract, the employment relationship is deemed to terminate on the first day immediately following the expiration of such six-month period. Whether a termination of employment has occurred will be determined based on all of the facts and circumstances and in accordance with regulations issued by the United States Treasury Department pursuant to Section 409A of the Code.

(oo)“Specified Employee” means certain officers and highly compensated employees of the Company as defined in Treas. Reg. § 1.409A-1(i). The identification date for determining whether any employee is a Specified Employee during any Plan Year shall be the September 1 preceding the commencement of such Plan Year.

(pp)“Standard Credit Account” means the account maintained under the Plan to record the amounts credited to a Participant in accordance with Section 3.3(b) (Matching and Standard Credits – Standard Credit).

(qq)“Standard Credits” means the Standard Credits allocated to a Participant’s Standard Credit Account in accordance with Section 3.3(b) (Matching and Standard Credits – Standard Credit).

(rr)“Supplemental Credit Account” means the account maintained under the Plan to record the amounts credited to an Eligible Officer in accordance with Section 3.4 (Supplemental Credits).

(ss)“Supplemental Credits” means the Supplemental Credits allocated to an Eligible Officer’s Supplemental Credit Account in accordance with Section 3.4 (Supplemental Credits).

(tt)“Supplemental Deferral Account” means the account maintained under the Plan to record amounts deferred under Section 3.2 (Supplemental Deferrals) of the Plan.

(uu)“Supplemental Deferral Agreement” means the written deferral agreement described in Section 3.1 (Supplemental Deferral Agreement) that is entered into by a Participant pursuant to this Plan.

(vv)“Supplemental Deferrals” means the deferrals made by a Participant in accordance with Section 3.2 (Supplemental Deferrals).

(ww)“Valuation Date” means each business day of the Plan Year.

1.2Construction. The masculine gender, when appearing in the Plan, shall include the feminine gender (and vice versa), and the singular shall include the plural, unless the contract clearly states to the contrary. Headings and subheadings are for the purpose of reference only and are not to be considered in the construction of this Plan. If any provision of this Plan is determined to be for any reason invalid or unenforceable, the remaining provisions shall continue in full force and effect. All of the provisions of this Plan shall be construed and enforced

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according to the laws of the State of New Mexico and shall be administered according to the laws of such state, except as otherwise required by ERISA, the Code, or other Federal law.

ARTICLE IIELIGIBILITY; ADOPTION BY AFFILIATES

2.1The Eligible Class. The purpose of the Plan is to provide deferred compensation to a select group of management or highly compensated employees. This group of eligible employees is sometimes referred to as the “top hat group.”

2.2Selection of Participants. Any employee who is classified as an “officer” of the Company shall be eligible to participate in the Plan for a particular Plan Year. For this purpose, an “officer” is someone who occupies the position of Vice President or higher. The Plan Administrator, in the exercise of its discretion, and with the concurrence of the Compensation and Human Resources Committee and/or the Board of Directors, also may designate any other employee of the Company or any Adopting Affiliate as eligible to participate in the Plan for a particular Plan Year if the Plan Administrator concludes that the employee is a member of the top hat group and should be allowed to participate in the Plan. As noted in Section 2.1 (The Eligible Class), this Plan is intended to provide benefits only to members of the top hat group. The Company has determined that all current officers are properly includible in the top hat group.

2.3Election to Participate. In order to make Supplemental Deferrals and Matching Credits for a particular Plan Year, an otherwise eligible employee (as determined in accordance with Section 2.2 (Selection of Participants) must affirmatively elect to participate in the Plan for that Plan Year in accordance with such procedures as may be prescribed by the Plan Administrator. The election must be made at the same time as elections are made in accordance with Section 3.2(b) (Supplemental Deferrals – Timing of Elections).

2.4Discontinuance of Participation. As a general rule, once an individual is a Participant, he will continue as a Participant (but not necessarily an Active Participant) for all future Plan Years until his retirement or other Separation from Service. In addition, prior to retirement or other Separation from Service, the Plan Administrator shall discontinue an individual’s participation in the Plan effective as of the first day of the Plan Year following the Plan Year during which the Plan Administrator concludes, in the exercise of its discretion, that the individual is no longer properly included in the top hat group. If an individual’s participation is discontinued, the individual will no longer be eligible to make deferrals or receive credits under this Plan. In addition, the individual will no longer be considered to be a Participant in this Plan. Rather, such individual’s rights to receive payments in the future will be deemed to be payable pursuant to a separate agreement the terms of which are identical to, but separate from, the terms of this Plan. The individual will not be entitled to receive a distribution pursuant to the terms of the separate agreement until the occurrence of another event (e.g., Separation from Service) that entitles the Participant to receive a distribution. The Participant’s Accounts under this separate agreement will continue to be adjusted to reflect hypothetical investment earnings or losses in accordance with Section 5.1 (Adjustment of Accounts) until the Accounts are distributed.

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2.5Adoption by Affiliates. An employee of an Affiliate may not become a Participant in the Plan unless the Affiliate has previously adopted the Plan. An Affiliate of the Company may adopt this Plan only with the approval of the Board. By adopting this Plan, the Affiliate shall be deemed to have agreed to assume the obligations and liabilities imposed upon it by this Plan, agreed to comply with all of the other terms and provisions of this Plan, delegated to the Plan Administrator, the Benefits Department, the Benefits Governance Committee, and the Compensation and Human Resources Committee the power and responsibility to administer this Plan with respect to the Affiliate’s employees, and delegated to the Company the full power to amend or terminate this Plan with respect to the Affiliate’s employees.

ARTICLE IIIDEFERRALS AND CREDITS

3.1Supplemental Deferral Agreement. In order to make Supplemental Deferrals for a particular Plan Year, a Participant must affirmatively elect to participate in this Plan for the applicable Plan Year in accordance with Section 2.3 (Election to Participate) and must execute a Supplemental Deferral Agreement in the form prescribed by the Benefits Department from time to time. In the Supplemental Deferral Agreement, the Participant shall agree to reduce his Compensation in exchange for a Supplemental Deferral in the same amount. The Supplemental Deferral Agreement shall be delivered to the Benefits Department by the time specified in Section 3.2(b) (Supplemental Deferrals – Timing of Elections).

3.2Supplemental Deferrals.

(a)Amount. Any Participant who has elected to participate in this Plan for a particular Plan Year may elect to defer, pursuant to a Supplemental Deferral Agreement, the receipt of all or any portion (designated in whole percentages) of the Compensation otherwise payable to him or her by the Company or an Adopting Affiliate for the Plan Year. The amount deferred pursuant to this paragraph (a) shall be allocated to the Supplemental Deferral Account maintained for the Participant.

(b)Timing of Elections. As a general rule, the Supplemental Deferral Agreement shall be signed by the Participant and delivered to the Benefits Department prior to the beginning of the Plan Year in which the Compensation to be deferred is otherwise payable to the Participant. The Supplemental Deferral Agreement will be effective only for a single Plan Year. A new Supplemental Deferral Agreement will be required if the Participant chooses to participate in this Plan for any later Plan Year. For the Plan Year in which a Participant first becomes eligible to participate in the Plan, the Participant may elect to participate in this Plan and to make Supplemental Deferrals of Compensation with respect to services to be performed subsequent to the date of the election by signing and delivering a Supplemental Deferral Agreement within 30 days after the date the Participant becomes eligible to participate in the Plan. An election made by a Participant shall be irrevocable with respect to the Plan Year covered by the election.

3.3Matching and Standard Credits. The Recordkeeper shall allocate Matching and Standard Credits to the Participant’s Matching Credit Account and Standard Credit Account in accordance with the following provisions of this Section.

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(a)Matching Credit. If a Participant elects to make Supplemental Deferrals, the Participant will be entitled to a Matching Credit if the Participant has “Excess Compensation.” For this purpose, “Excess Compensation” is Compensation in excess of the limit imposed by Section 401(a)(17) of the Code for the relevant Plan Year. The Matching Credit shall be in an amount equal to 75% of the Participant’s Supplemental Deferrals, provided that the Matching Credit shall not exceed an amount equal to 75% of the first six percent of Excess Compensation. A Participant shall be eligible to receive a Matching Credit under this Plan only if such Participant has met the service requirements necessary to receive RSP Matching Contributions for that Plan Year.

(b)Standard Credit. The Standard Credit shall be an amount equal to (i) the RSP Employer Contribution that would have been made on the Participant’s behalf to the RSP for the Plan Year if the contributions were not limited by the Code (including, particularly, the limitations imposed by Sections 401(a)(17) and 415 of the Code), reduced by (ii) the RSP Employer Contribution actually made to the RSP on behalf of the Participant for the Plan Year. A Participant shall be eligible to receive a Standard Credit under this Plan only if such Participant has met the service requirements necessary to receive RSP Employer Contributions for that Plan Year.

3.4Supplemental Credits.

(a)General Rule. The Plan Administrator shall instruct the Recordkeeper to allocate Supplemental Credits to an Eligible Officer’s Supplemental Credits Account as of December 1 of each Plan Year. The Supplemental Credit shall be an amount calculated by the Plan Administrator pursuant to Section 3.4(b). The purpose of the Supplemental Credit is to provide the Eligible Officer with retirement income approximately equal to a specified target percentage (the “Target Replacement Income Percentage”) of the Eligible Officer’s anticipated pre‑retirement income. The relevant Target Replacement Income Percentage will be determined by the Plan Administrator, with the advance advice and consent of the Compensation and Human Resources Committee, and will be set forth in a letter or other written instrument provided by the Plan Administrator to the Eligible Officer. The Target Replacement Income Percentage may be modified from time to time in the same manner. In determining the Target Replacement Income Percentage for a particular Eligible Officer, the Plan Administrator, and the Compensation and Human Resources Committee, will act in their discretion and will not be bound by the Target Replacement Income Percentage determined for any other current or former Eligible Officer.

(b)Determination of Supplemental Credit. The Plan Administrator’s calculation of the Supplemental Credit shall be made on the basis of advice received by an actuarial or other consultant retained by the Plan Administrator and with the advice and consent of the Compensation and Human Resources Committee. In determining the amount of the Supplemental Credits necessary to achieve the desired Target Replacement Income Percentage, anticipated retirement income from the following sources shall be considered: (1) amounts attributable to Company credits to this Plan (including investment earnings on such amounts); (2) amounts attributable to Company contributions to the RSP (including investment earnings on such amounts); (3) benefits provided pursuant to the PNM Resources, Inc. Employees’ Retirement Plan; (4) benefits provided pursuant to the After-Tax Retirement Plan and any supplemental employee retirement plans or agreements (“SERPs”) entered into by the Eligible

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Officer and the Company or an Affiliate; (5) benefits provided pursuant to the Social Security Act; and (6) amounts provided pursuant to other employers’ benefit plans. When determining the amount of the Supplemental Credits, the Plan Administrator shall use actuarial assumptions (interest and mortality), compensation assumptions, rate of return assumptions and such other assumptions as it deems appropriate. All interest and investment earnings calculations will be based on an assumed rate set by the Plan Administrator in the exercise of its discretion. No adjustments will be made to reflect the difference between the assumed rate set by the Plan Administrator and the actual rate of return on the Participant’s Accounts calculated pursuant to Section 5.2(f) (Investment Direction – Rate of Return). The Plan Administrator will review all of the assumptions periodically and may change the assumptions as it deems appropriate. The assumptions used will have a significant impact on the amount of the Supplemental Credits. Because these assumptions (and the Target Replacement Income Percentage) may be altered at any time as described above, no Eligible Officer will have a contractual or other right to any particular level or amount of Supplemental Credit for any Plan Year until such Supplemental Credit is actually declared and allocated to the Eligible Officer’s Supplemental Credit Account.

(c)Termination During the Plan Year. An Eligible Officer must be employed on December 1 of the relevant Plan Year in order to receive the Supplemental Credit called for by Section 3.4 (Supplemental Credits) for that Plan Year. Notwithstanding the prior sentence, an Eligible Officer shall receive a pro-rata Supplemental Credit if the Eligible Officer incurs a Separation from Service before December 1 of any Plan Year under any of the following circumstances: (1) after reaching Normal Retirement Date; (2) under circumstances that entitle the Eligible Officer to receive benefits under the Officer Retention Plan; (3) due to Disability; or (4) due to the death of the Eligible Officer. The pro-rata Supplemental Credit shall be calculated based on the time elapsed between December 1 of the prior Plan Year and the date of the Eligible Officer’s Separation from Service as compared to 365 days and shall be credited to the Eligible Officer’s Supplemental Credit Account within thirty (30) days of the Eligible Officer’s Separation from Service. For example, if an Eligible Officer terminates employment on June 1, 2012 due to retirement, the Eligible Officer will receive 50% of the Supplemental Credits for the 2012 Plan Year and that amount will be credited to the Eligible Officer’s Supplemental Credit Account by July 1, 2012.

3.5Discretionary Credits. In its sole and absolute discretion, the Compensation and Human Resources Committee may instruct the Recordkeeper to allocate Discretionary Credits to a Participant’s Discretionary Credit Account at any time during a Plan Year in any amount that the Compensation and Human Resources Committee deems appropriate and on such terms and conditions (including deferred vesting provisions) as the Compensation and Human Resources Committee deems appropriate.

3.6Benefits Not Contingent. Deferrals and credits for any Participant under this Plan are not increased or decreased to the extent a Participant makes or does not make deferrals under the RSP.

3.7Allocation Among Affiliates. Each Adopting Affiliate shall bear the costs and expenses of providing benefits accrued by its employee-Participants during periods while they are employed by that Adopting Affiliate. Such costs and expenses shall be allocated among the Adopting Affiliates in accordance with (a) agreements entered into between the Company and

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any Adopting Affiliate, or (b) in the absence of such an agreement, procedures adopted by the Company.

ARTICLE IVVESTING

4.1Vesting in the Supplemental Deferral Account, the Matching Credit Account and the Standard Credit Account. Each Participant shall at all times be fully vested in all amounts credited to or allocable to his Supplemental Deferral Account, Matching Credit Account, Standard Credit Account and (except as noted below) Discretionary Credit Account and his rights and interest therein shall not be forfeitable for any reason. Consistent with Section 3.5 (Discretionary Credits), the Compensation and Human Resources Committee, in the exercise of its discretion, may impose vesting conditions on all or part of the amounts credited to the Discretionary Credit Account.

4.2Vesting in the Supplemental Credit Account. The Supplemental Credits for any Plan Year shall vest on a two-year cliff vesting schedule. For example, if a Supplemental Credit is allocated to a Participant’s Supplemental Credit Account on December 1, 2014, that amount will fully vest on December 1, 2016 and if a Supplemental Credit is allocated to a Participant’s Supplemental Credit Account on December 1, 2015, that amount will fully vest on December 1, 2017, and so on.

Notwithstanding the foregoing, each Eligible Officer shall be fully vested in all amounts credited to his Supplemental Credit Account on and after the first to occur of the following events:

(c)The Eligible Officer attaining age 55 with two Years of Service;

(d)The Eligible Officer’s Normal Retirement Date;

(e)The Eligible Officer’s Disability;

(f)The date of death of the Eligible Officer; or

(g)The termination (other than for “Cause”) or “Constructive Termination” of the Eligible Officer’s employment by the Company following a Change in Control. For this purpose, the terms “Constructive Termination” and “Cause” shall have the meanings ascribed to them under the Officer Retention Plan.

If an Eligible Officer Separates from Service before becoming vested in his Supplemental Credits, the Eligible Officer’s Supplemental Credits under this Plan will be forfeited.

4.3Acceleration of Vesting. In its sole and absolute discretion, the Compensation and Human Resources Committee may accelerate the vesting of any Participant’s Supplemental Credit Account.

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ARTICLE V

ADJUSTMENT OF ACCOUNTS

5.1Adjustment of Accounts. Except as otherwise provided elsewhere in the Plan, as of each Valuation Date, each Participant’s Accounts will be adjusted to reflect deferrals and credits under Article III (Deferrals and Credits) and the positive or negative rate of return on the Investment Funds selected by the Participant pursuant to Section 5.2(b) (Investment Direction – Participant Directions). The rate of return will be determined by the Recordkeeper pursuant to Section 5.2(f) (Investment Direction – Rate of Return) and will be credited or charged in accordance with written policies applied to all Participants. While the Accounts will be adjusted as of each Valuation Date, the Recordkeeper shall only post the adjustments as of the last business day of each month.

5.2Investment Direction.

(d)Investment Funds. Each Participant may direct the hypothetical investment of amounts credited to his Accounts in one or more of the Investment Funds. The Investment Funds shall include a Company Stock Fund and such other investment funds as may be available under the RSP. The Investment Funds may be changed from time to time by the Company’s Corporate Investment Committee, in its discretion.

(e)Participant Directions. Each Participant may direct that all of the amounts attributable to his Accounts be invested in a single Investment Fund or may direct that fractional (percentage) increments of his Accounts be invested in such fund or funds as he shall desire in accordance with such procedures as may be established by the Company’s Corporate Investment Committee. Unless the Corporate Investment Committee prescribes otherwise, such procedures shall mirror the procedures established under the RSP for participant investment direction except that any limitations or caps imposed on investment in a company stock fund under the RSP shall not apply to investment in the Company Stock Fund under the Plan. A Participant’s ability to direct investments into or out of the Company Stock Fund shall be subject to such procedures as the Company’s General Counsel (or his delegate) may prescribe from time to time to assure compliance with Rule 16b-3 promulgated under Section 16(b) of the Securities Exchange Act of 1934, as amended, and other applicable requirements. Such procedures also may limit or restrict a Participant’s ability to make (or modify previously made) elections.

(f)Changes and Intra-Fund Transfers. Participant investment directions may be changed, and amounts may be transferred from one hypothetical Investment Fund to another, in accordance with the procedures established by the Company’s Corporate Investment Committee (or, in the case of the Company Stock Fund, the Company’s General Counsel) pursuant to Section 5.2(b) (Investment Direction – Participant Directions). The designation will continue until changed by the timely submission of a new designation.

(g)Default Selection. In the absence of any designation, a Participant will be deemed to have directed the investment of his Accounts in such Investment Funds as the Company’s Corporate Investment Committee, in its sole and absolute discretion, shall determine.

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(h)Impact of Election. The Participant’s selection of Investment Funds shall serve only as a measurement of the value of the Participant’s Accounts pursuant to Section 5.1 (Adjustment of Accounts) and this Section 5.2 and neither the Company nor the Plan Administrator are required to actually invest a Participant’s Accounts in accordance with the Participant’s selections.

(i)Rate of Return. Accounts shall be adjusted on each Valuation Date to reflect investment gains and losses as if the Accounts were invested in the hypothetical Investment Funds selected by the Participants in accordance with this Section 5.2 and charged with any and all reasonable expenses related to the administration of the Plan including, but not limited to, the reasonable expenses of carrying out the hypothetical investment directions related to each account. The earnings and losses determined by the Recordkeeper in good faith and in its discretion pursuant to this Section shall be binding and conclusive on the Participant, the Participant’s beneficiary and all parties claiming through them.

(j)Charges. The Plan Administrator may direct the Recordkeeper to charge each Participant’s accounts for the reasonable expenses of carrying out investment instructions directly related to such accounts.

5.3Special Company Stock Fund Provisions.

(a)General. A Participant’s interest in the Company Stock Fund shall be expressed in whole and fractional hypothetical units of the Company Stock Fund. As a general matter, the Company Stock Fund shall track an investment in Company Stock in the same manner as the RSP’s company stock fund. Accordingly, the value of a unit in the Plan’s Company Stock Fund shall be the same as the value of a unit in the RSP’s company stock fund.

(b)Dividends and Stock Splits. If a cash dividend is declared on Company Stock, the hypothetical equivalent cash dividends attributable to the notional shares held in the Company Stock Fund shall be “reinvested” into the Company Stock Fund. If a stock dividend or share split is declared with respect to Company Stock, a hypothetical equivalent stock dividend or stock split attributable to the notional shares held in the Company Stock Fund, or any hypothetical securities issued with respect to the Company Stock Fund, shall be allocated to the Company Stock Fund. All such hypothetical dividends (cash or stock) or stock splits shall be reflected appropriately in the Participant’s Accounts.

5.4Compliance with Securities Laws. Any election by a Participant to hypothetically invest any amount in the Company Stock Fund, and any elections to transfer amounts from or to the Company Stock Fund to or from any other Investment Fund, shall be subject to all applicable securities law requirements, including but not limited to Rule 16b-3 of the Securities Exchange Act of 1934, as amended, promulgated by the Securities Exchange Commission. To the extent that any election violates any securities law, rule or regulation, the election shall be void.

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ARTICLE VI

DISTRIBUTIONS

6.1Distribution Events. A Participant shall be entitled to a distribution of his Accounts on the earliest of the following to occur:

(k)Separation from Service. Following a Participant’s Separation from Service for any reason other than death, the Participant’s vested interest in the Plan will be distributed to the Participant at the time and in the manner provided in Sections 6.4(a) (Timing of Distributions – Separation from Service, Disability and Death) and 6.2(a) (Form of Distribution – Distributions on Separation from Service and Disability).

(l)Disability. A Participant shall be entitled to full distribution of his vested interest in the Plan, at the time and in the manner provided in Sections 6.4(a) (Timing of Distributions – Separation from Service, Disability and Death) and 6.2(a) (Form of Distribution – Distributions on Separation from Service and Disability), if the Participant becomes Disabled.

(m)Death. If a Participant dies prior to receiving his entire interest in the Plan, the Participant’s Accounts will be distributed to the Participant’s beneficiary at the time and in the manner provided in Sections 6.4(a) (Timing of Distributions – Separation from Service, Disability and Death) and 6.2(b) (Form of Distribution – Distributions on Death).

(n)Specified Date. A Participant shall be entitled to distribution of all or a portion of his vested interest in the Plan, at the time and in the manner provided in Sections 6.4(b) (Timing of Distributions – Specified Date) and 6.2(c) (Form of Distribution – Distributions on Specified Date). Notwithstanding the foregoing, a specified date distribution will not be available for amounts credited to a Participant’s Accounts for Plan Years beginning on or after January 1, 2015.

6.2Form of Distribution.

(c)Distributions on Separation from Service and Disability. Subject to Section 6.2(e) (Form of Distribution – Distribution of Small Amounts), upon a Participant’s Separation from Service or Disability as described in Section 6.1(a) (Distribution Events – Separation from Service) and 6.1(b) (Distribution Events – Disability), the Participant’s Accounts shall be distributed to the Participant in a single lump sum payment or installments over a specified period of time. Installment distributions shall be subject to such uniform rules and procedures as may be adopted by the Plan Administrator from time to time, which rules and procedures shall be reflected in the Distribution Election Form or other forms prescribed by the Benefits Department. Installment distributions shall be limited to a period of five (5) years or ten (10) years for amounts credited to a Participant’s Accounts for Plan Years beginning on or after January 1, 2015. At all times, the right to each installment payment made pursuant to this Section 6.2(a) shall be treated as the right to a series of separate payments within the meaning of Treas. Reg. § 1.409A-2(b)(2)(iii).

The method of payment and the timing of payment shall be selected by the Participant in the initial Distribution Election Form (which may be contained in and be a part of a Supplemental Deferral Agreement) submitted by the Participant to the Benefits Department on

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entry into the Plan. A Participant may change his distribution election with respect to future years by filing a new Distribution Election Form with the Benefits Department prior to the first day of the first year to which the election relates. A Participant may change elections with respect to the current or a prior year in accordance with Section 6.2(f) (Form of Distribution – Changes in Time and Form of Distribution). If a revised Distribution Election Form is not honored because it was not timely filed, distributions shall be made pursuant to the most recent valid Distribution Election Form filed by the Participant. If no valid Distribution Election Form exists, the Participant’s Accounts will be distributed in a single lump sum.

(d)Distributions on Death. In the event of a Participant’s death prior to Separation from Service, the Participant’s Accounts shall be distributed to the Participant’s beneficiary in a single lump sum payment. Similarly, if a Participant dies while receiving installment payments under this Plan or after Separation from Service but prior to the commencement of the Participant’s benefit payments, the balance of the Participant’s Accounts shall be paid to the Participant’s beneficiary in the form of a lump sum payment.

(e)Distributions on Specified Date. If a Participant elects to receive all or a portion of his Accounts on a specified date as described in Section 6.1(d) (Distribution Events – Specified Date), the Participant’s Accounts shall be distributed to the Participant in a single lump sum payment or in substantially equal installments over a period not exceeding five years. Installment distributions shall be subject to such uniform rules and procedures as may be adopted by the Plan Administrator from time to time, which rules and procedures shall be reflected in the Distribution Election Form or other forms prescribed by the Benefits Department. At all times, the right to each installment payment made pursuant to this Section 6.2(c) shall be treated as the right to a series of separate payments within the meaning of Treas. Reg. § 1.409A-2(b)(2)(iii). If a Participant has commenced receiving all or a portion of his Accounts in installment payments pursuant to this Section 6.2(c) at the time of the Participant’s Separation from Service or Disability, the Participant will continue receiving such amounts in installment payments following the date of the Participant’s Separation from Service or Disability. The portion, if any, of the Participant’s Accounts which is not being distributed in installment payments pursuant to an election made pursuant to Section 6.1(d) (Distribution Events – Specified Date) shall be distributed in accordance with the remaining provisions of Section 6.1 (Distribution Events).

The method of payment and the timing of payment shall be selected by the Participant in the initial Distribution Election Form (which may be contained in and be a part of a Supplemental Deferral Agreement) submitted by the Participant to the Benefits Department on entry into the Plan. A Participant may change his distribution election with respect to future years by filing a new Distribution Election Form with the Benefits Department prior to the first day of the first year to which the election relates. A Participant may change elections with respect to the current or a prior year in accordance with Section 6.2(f) (Form of Distribution – Changes in Time and Form of Distribution). If a revised Distribution Election Form is not honored because it was not timely filed, distributions shall be made pursuant to the most recent valid Distribution Election Form filed by the Participant. If no valid Distribution Election Form exists, the Participant’s Accounts will be distributed in a single lump sum. Notwithstanding the foregoing, a specified date distribution will not be available for amounts credited to a Participant’s Accounts for Plan Years beginning on or after January 1, 2015.

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(f)Distributions of Company Stock Fund. The portion of a Participant’s Accounts that is allocated to the Company Stock Fund shall be distributed in the form of distribution (e.g., lump sum or installments) elected by the Participant pursuant to Section 6.2(a) (Form of Distribution – Distributions on Separation from Service and Disability) and/or Section 6.2(c) (Form of Distribution – Distributions on Specified Date) above in cash or in whole shares of Company Stock (with fractional shares paid for in cash) as elected by the Participant. Only amounts actually invested in the Company Stock Fund for the one-year period prior to the distribution, however, may be distributable in Company Stock. The election to receive cash or Company Stock shall be made at the time and in the manner provided in the form prescribed by the Benefits Department from time to time for that purpose. Any election made by a Participant pursuant to this Section with respect to a distribution from the Company Stock Fund shall be subject to all applicable securities law requirements, including, but not limited to, Rule 16b-3. Any election that may not be implemented due to the lack of any available exemption shall be void. The Benefits Department may then make the distribution in any fashion that will not result in a violation of any applicable securities law requirements. The Benefits Department also may delay the distribution if necessary. An exemption to the securities law requirements that is only available with the prior approval of the Board, the shareholders, or some other individual or individuals shall not be considered to be available unless such approval is actually granted in a timely manner.

(g)Distribution of Small Amounts. Notwithstanding any provision in this Plan to the contrary, in the event that the amount credited to the Participant’s Accounts as of the date his or her payments commence is less than the applicable dollar amount under Section 402(g)(1)(B) of the Code ($17,500 for 2014), the Benefits Governance Committee may elect to pay the amount credited to the Participant’s Accounts in a lump sum payment. The Benefits Governance Committee must inform the Participant in writing on or before the date of a distribution pursuant to this Section that the Committee has elected to distribute the Participant’s Accounts pursuant to this Section. Any payment to a Participant pursuant to this Section must represent the complete liquidation of the Participant’s interest in the Plan.

(h)Changes in Time and Form of Distribution. A new Distribution Election Form that changes the time or form of payment for amounts attributable to future years may be filed with the Benefits Department prior to the first day of the first year to which the election relates. A new Distribution Election Form that delays the time of a payment previously elected by a Participant or the form of payment previously selected by a Participant will be honored only if the following requirements are met:

(1)The new form will not take effect until at least 12 months after the date on which the new form is filed with the Benefits Department; and

(2)The election may not be made less than 12 months prior to the date of the first scheduled payment; and

(3)In the case of an election related to a payment not related to the Participant’s Disability or death, the first payment with respect to which the election is made must be deferred for a period of not less than five years from the date such payment would otherwise be made.

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The provisions of this paragraph are intended to comply with Section 409A(a)(4)(C) of the Code and shall be interpreted in a manner consistent with the requirements of such section and any regulations, rulings or other guidance issued pursuant thereto. As provided in Section 6.8 (Ban on Acceleration of Benefits), distributions may not be accelerated.

6.3Amount of Distribution. The amount distributed to a Participant shall equal the sum of the vested amounts credited to the Participant’s Accounts as of the quarterly Valuation Date preceding the date of the distribution. For purposes of this Plan, a “quarterly Valuation Date” is a Valuation Date that coincides with the last business day of a calendar quarter. If distributions are to be made in installments, the Participant’s Accounts will continue to be adjusted in accordance with Article V (Adjustment of Accounts) until the full Account balance has been distributed. Amounts invested in the Company Stock Fund that are distributed in cash shall be valued at the fair market value of the Company Stock on the relevant Valuation Date. Similarly, amounts that are distributed in the form of Company Stock shall be valued at the fair market value of the Company Stock on the relevant Valuation Date.

6.4Timing of Distributions. Distributions will be made on the earliest of the following to occur:

(a)Separation from Service, Disability and Death. As a general rule, funds will be distributed within ninety (90) days following (a) the Participant’s Separation from Service for any reason (including death) or Disability, or (b) in the case of a Participant who is a Specified Employee, the date which is six months after the Participant’s Separation from Service. The Participant may not elect the taxable year of the distribution. The six-month delay for a Specified Employee does not apply if the Specified Employee dies or becomes Disabled. Notwithstanding the foregoing, a Participant may elect to defer the distribution of funds in accordance with Section 6.2 (Form of Distribution).

(b)Specified Date. A Participant shall be entitled to a distribution of all or a portion of his vested interest in the Plan on the specified date chosen in the Supplemental Deferral Agreement filed with the Plan Administrator in accordance with Section 3.1 (Supplemental Deferral Agreement) or in an election form filed with the Plan Administrator pursuant to Section 6.2(f) (Form of Distribution – Changes in Time and Form of Distribution), as the case may be. For amounts credited to a Participant’s Accounts on or after January 1, 2009, the specified date distribution chosen by a Participant may not be prior to the date that all amounts credited for the relevant Plan Year, including Supplemental Credits, if any, are fully vested.

Payment to a Participant who has chosen to receive a distribution on a specified date pursuant to Section 6.1(d) (Distribution Events – Specified Date) shall be made within ten (10) business days following the specified date chosen by the Participant. Any amounts which are credited to the Participant’s Accounts or become vested after the specified date chosen by the Participant will be distributed to the Participant upon the Participant’s Separation from Service as described in Section 6.1(a) (Distribution Events – Separation from Service), Disability as described in Section 6.1(b) (Distribution Events – Disability) or death as described in Section 6.1(c) (Distribution Events – Death). Notwithstanding the foregoing, a specified date

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distribution will not be available for amounts credited to a Participant’s Accounts for Plan Years beginning on or after January 1, 2015.

6.5Beneficiary Designation. If a Participant should die before receiving a full distribution of his or her Accounts, distribution shall be made to the beneficiary designated by the Participant. If a Participant has not designated a beneficiary, or if no designated beneficiary is living on the date of distribution, such amounts shall be distributed to those persons entitled to receive distributions of the Participant’s Accounts under the RSP. The distributions made under this Plan shall be made in a lump sum.

6.6Withholding. All distributions will be subject to all applicable tax and withholding requirements.

6.7Deductibility. All amounts distributed from the Plan are intended to be deductible by the Company or the appropriate Adopting Affiliate. If all or any portion of a distribution will not be deductible under Section 162(m) of the Code, the payment will be delayed until the first year in which it is deductible.

6.8Ban on Acceleration of Benefits. Notwithstanding any other provision of this Plan to the contrary, neither the time nor the schedule of any payment under the Plan may be accelerated or subject to a further deferral except as provided in Treas. Reg. § 1.409A-3(j)(4).

6.9Distributions Treated as Made Upon a Designated Event. If the Company or any Adopting Affiliate fails to make any distribution, either intentionally or unintentionally, within the time period specified in the Plan, but the payment is made within the same calendar year, such distribution will be treated as made within the time period specified in the Plan pursuant to Treas. Reg. § 1.409A-3(d). In addition, if a distribution is not made due to a dispute with respect to such distribution, the distribution may be delayed in accordance with Treas. Reg. § 1.409A-3(g).

ARTICLE VII

TRANSFERS FROM ESP I

7.1Combination with ESP I. As of December 17, 2008, the ESP I was combined with the Plan, with the Plan being the surviving plan. As of December 17, 2008, all ESP I liabilities shall be transferred to and assumed by the Plan. All liabilities transferred from the ESP I shall be credited to the accounts established pursuant to this Plan in accordance with Section 7.2 (Accounting) of this Plan. As of December 17, 2008, any right, claim or other entitlement that an individual had pursuant to the ESP I shall be a right, claim or entitlement under this Plan and shall be paid in accordance with the terms and provisions of this Plan. As of December 17, 2008, no individual shall have any right, claim or other entitlement pursuant to the ESP I. Notwithstanding the foregoing, any distribution elections made pursuant to the ESP I shall remain in effect unless changed by the Participant pursuant to the terms of the Plan.

7.2Accounting. Following the combination of ESP I with and into the Plan, the account balances transferred to this Plan from the ESP I were allocated to the appropriate Participants’ accounts in accordance with the following rules:

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(a)Participant supplemental deferrals made on behalf of a participant pursuant to ESP I were allocated to the Participant’s Supplemental Deferral Account under this Plan;

(b)Any matching credits made on behalf of a participant pursuant to ESP I were allocated to the Participant’s Matching Credit Account under this Plan;

(c)Any standard credits made on behalf of a participant pursuant to ESP I were allocated to the Participant’s Standard Credit Account under this Plan; and

(d)Any discretionary credits made on behalf of a participant in the ESP I were allocated to the Participant’s Discretionary Credit Account under this Plan.

ARTICLE VIIIADMINISTRATION OF THE PLAN

8.1General Powers and Duties.

(e)General. The Plan Administrator shall perform the duties and exercise the powers and discretion given to it in this Plan document and its decisions and actions shall be final and conclusive as to all persons affected thereby. The Company and the Adopting Affiliates shall furnish the Plan Administrator with all data and information that the Plan Administrator may reasonably require in order to perform its functions. The Plan Administrator may rely without question upon any such data or information.

(f)Disputes. Any and all disputes that may arise involving Participants or beneficiaries shall be referred to the Plan Administrator and its decision shall be final. Furthermore, if any question arises as to the meaning, interpretation or application of any provisions of this Plan, the decision of the Plan Administrator shall be final.

(g)Agents. The Plan Administrator may engage agents, including actuaries, to assist it and may engage legal counsel who may be counsel for the Company. The Plan Administrator shall not be responsible for any action taken or omitted to be taken on the advice of such counsel, including written opinions or certificates of any agent, counsel or actuary.

(h)Insurance. At the Plan Administrator’s request, the Company shall purchase liability insurance to cover the Plan Administrator in its activities as the Plan Administrator.

(i)Allocations. The Plan Administrator is given specific authority to allocate responsibilities to the Benefits Department and to revoke such allocations. When the Plan Administrator has allocated authority pursuant to this paragraph, the Plan Administrator is not to be liable for the acts or omissions of the party to whom such responsibility has been allocated.

(j)Records. The Benefits Department shall supervise the establishment and maintenance of records by the Recordkeeper, the Company and each Adopting Affiliate containing all relevant data pertaining to any person affected hereby and his or her rights under this Plan. In addition, the Plan Administrator may, in its discretion, establish a system for

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complete or partial electronic administration of the Plan and may replace any written documents described in this Plan with electronic counterparts as it deems appropriate.

(k)Interpretations. The Plan Administrator, in its sole discretion, shall interpret and construe the provisions of the Plan (and any underlying documents or policies).

(l)Accounts. The Plan Administrator (or Recordkeeper, as appropriate) shall combine the various Accounts of a Participant if it deems such action appropriate. Furthermore, the Plan Administrator (or Recordkeeper, as appropriate) shall divide a Participant’s Accounts into sub-accounts if it deems such action appropriate.

The foregoing list of powers and duties is not intended to be exhaustive, and the Plan Administrator shall, in addition, exercise such other powers and perform such other duties as it may deem advisable in the administration of the Plan, unless such powers or duties are assigned to another pursuant to the provisions of the Plan.

8.2Claims.

(a)Initial Claim. A claim for benefits by a Participant, beneficiary or any other person (all of whom are referred to in this Section as a “Claimant”) under this Plan must be submitted to the Benefits Department. The Benefits Department will notify the Claimant of the disposition of the claim within 90 days after the request is filed with the Benefits Department. The Benefits Department may have an additional period of up to 90 days to decide the claim if the Benefits Department determines that special circumstances require an extension of time to decide the claim and the Benefits Department advises the Claimant in writing of the need for an extension (including an explanation of the special circumstances requiring the extension) and the date on which it expects to decide the claim. If, following the review, the claim is denied, in whole or in part, the notice of disposition shall set forth:

(1)the specific reason(s) for denial of the claim;

(2)reference to the specific Plan provisions upon which the determination is based;

(3)a description of any additional material or information necessary for the Claimant to perfect the claim and an explanation of why such material or information is necessary; and

(4)an explanation of the Plan’s appeal procedures, and an explanation of the time limits applicable to the Plan’s appeal procedures, including a statement of the Claimant’s right to bring a civil action under Section 502(a) of ERISA.

(b)Appeal of Adverse Benefit Determination.

(1)Within 60 days after receiving the written notice of the disposition of the claim described in paragraph (a), the Claimant, or the Claimant’s authorized representative, may appeal such denied claim. The Claimant may submit a written statement of his claim (including any written comments, documents, records and other information relating to

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the claim) and the reasons for granting the claim to the Benefits Governance Committee. The Benefits Governance Committee shall have the right to request of and receive from the Claimant such additional information, documents or other evidence as the Benefits Governance Committee may reasonably require. If the Claimant does not request an appeal of the denied claim within 60 days after receiving written notice of the disposition of the claim as described in paragraph (a), the Claimant shall be deemed to have accepted the disposition of the claim and such written disposition will be final and binding on the Claimant and anyone claiming benefits through the Claimant, unless the Claimant shall have been physically or mentally incapacitated so as to be unable to request review within the 60-day period. The appeal shall take into account all comments, documents, records and other information submitted by the Claimant relating to the claim, without regard to whether such documents, records or other information were submitted or considered in the initial benefit determination or the initial review.

(2)A decision on appeal to the Benefits Governance Committee shall be rendered in writing by the Benefits Governance Committee ordinarily not later than 60 days after the Claimant requests review. A written copy of the decision shall be delivered to the Claimant. If special circumstances require an extension of the ordinary period, the Benefits Governance Committee shall so notify the Claimant of the extension with such notice containing an explanation of the special circumstances requiring the extension and the date by which the Benefits Governance Committee expects to render a decision. Any such extension shall not extend beyond 60 days after the ordinary period. The period of time within which a benefit determination on review is required to be made shall begin at the time an appeal is filed in accordance with the provisions of paragraph (b)(1) above, without regard to whether all the information necessary to make a decision on appeal accompanies the filing.

If the appeal to the Benefits Governance Committee is denied, in whole or in part, the decision on appeal referred to in the first sentence of this paragraph (2) shall set forth:

(i)the specific reason(s) for denial of the claim;

(ii)reference to the specific Plan provisions upon which the denial is based;

(iii)a statement that the Claimant is entitled to receive, upon request and free of charge, reasonable access to, and copies of, all documents, records, and other information relevant to the Claimant’s claim for benefits; and

(iv)a statement of the Claimant’s right to bring a civil action under Section 502(a) of ERISA.

(c)Right to Examine Plan Documents and to Submit Materials. In connection with the determination of a claim, or in connection with review of a denied claim or appeal pursuant to this Section 8.2, the Claimant may examine this Plan and any other pertinent documents generally available to Participants relating to the claim and may submit written comments, documents, records and other information relating to the claim for benefits. The Claimant also will be provided, upon request and free of charge, reasonable access to, and copies

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of, all documents, records, and other information relevant to the Claimant’s claim for benefits with such relevance to be determined in accordance with Section 8.2(d) (Claims – Relevance).

(d)Relevance. For purpose of this Section 8.2, documents, records, or other information shall be considered “relevant” to a Claimant’s claim for benefits if such documents, records or other information:

(1)were relied upon in making the benefit determination;

(2)were submitted, considered, or generated in the course of making the benefit determination, without regard to whether such documents, records or other information were relied upon in making the benefit determination; or

(3)demonstrate compliance with the administrative processes and safeguards required pursuant to this Section 8.2 regarding the making of the benefit determination.

(e)Decisions Final; Procedures Mandatory. To the extent permitted by law, a decision on review or appeal shall be binding and conclusive upon all persons whomsoever. To the extent permitted by law, completion of the claims procedures described in this Section 8.2 shall be a mandatory precondition that must be complied with prior to commencement of a legal or equitable action in connection with the Plan by a person claiming rights under the Plan or by another person claiming rights through such a person. The Benefits Governance Committee may, in its sole discretion, waive these procedures as a mandatory precondition to such an action.

(f)Time For Filing Legal Or Equitable Action. Any legal or equitable action filed in connection with the Plan by a person claiming rights under the Plan or by another person claiming rights through such a person must be commenced not later than the earlier of: (1) the expiration of the shortest applicable statute of limitations provided by law; or (2) two years from the date the written copy of the Benefits Governance Committee’s decision on review is delivered to the Claimant in accordance with Section 8.2(b) (Claims – Appeal of Adverse Benefit Determination).

ARTICLE IX

AMENDMENT

9.1Amendment. The Company reserves the right to amend the Plan when, in the sole discretion of the Company, such amendment is advisable. Any such amendment shall be made pursuant to a resolution of the Board (or its delegate) and shall be effective as of the date of such resolution. Notwithstanding any provision of this Plan to the contrary, no amendment may be made if it will result in a violation of Section 409A of the Code and any such amendment shall at no time have any legal validity. Although this Plan has been designed to comply with the requirements of Section 409A of the Code, the Company specifically does not warrant such compliance.

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9.2Effect of Amendment. Any amendment of this Plan shall apply prospectively only and shall not directly or indirectly reduce the balance of any Plan account as of the effective date of such amendment.

9.3Termination. It is the expectation of the Company that this Plan will be continued indefinitely. However, continuance of the Plan is not assumed as a contractual obligation of the Company and the right is reserved at any time to terminate this Plan. Except as otherwise determined by the Company in compliance with Section 409A, the termination of the Plan shall not result in an immediate payment to Plan Participants. Rather, payments shall only be made in accordance with the provisions of Article VI (Distributions).

ARTICLE X

GENERAL PROVISIONS

10.1Participant’s Rights Unsecured. The Plan at all times shall be entirely unfunded and no provision shall at any time be made with respect to segregating any assets of the Company for payment of any distributions hereunder. The right of a Participant or his or her designated beneficiary to receive a distribution hereunder shall be an unsecured claim against the general assets of the Company, and neither the Participant nor a designated beneficiary shall have any rights in or against any specific assets of the Company. All amounts credited to a Participant’s Accounts shall constitute general assets of the Company and may be disposed of by the Company at such time and for such purposes as it may deem appropriate. Nothing in this Section shall preclude the Company from establishing a “Rabbi Trust,” but the assets in the Rabbi Trust must be available to pay the claims of the Company’s general creditors in the event of the Company’s insolvency.

10.2No Guaranty of Benefits. Nothing contained in the Plan shall constitute a guaranty by the Company or any other person or entity that the assets of the Company will be sufficient to pay any benefit hereunder.

10.3No Enlargement of Employee Rights. No Participant shall have any right to receive a distribution from the Plan except in accordance with the terms of the Plan. Establishment of the Plan shall not be construed to give any Participant the right to be retained in the service of the Company.

10.4Spendthrift Provision. No interest of any person or entity in, or right to receive a distribution under, the Plan shall be subject in any manner to sale, transfer, assignment, pledge, attachment, garnishment, or other alienation or encumbrance of any kind; nor shall any such interest or right to receive a distribution be taken, either voluntarily or involuntarily, for the satisfaction of the debts of, or other obligations or claims against, such person or entity, including claims in bankruptcy proceedings. This Section shall not preclude arrangements for the withholding of taxes from deferrals, credits, or benefit payments, arrangements for the recovery of benefit overpayments, arrangements for the transfer of benefit rights to another plan, or arrangements for direct deposit of benefit payments to an account in a bank, savings and loan association or credit union (provided that such arrangement is not part of an arrangement constituting an assignment or alienation).

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10.5Incapacity of Participant. If the Benefits Department is served with a court order holding that a Participant is incapable of personally receiving and giving a valid receipt for such distribution, the Benefits Department shall postpone payment until such time as a claim therefore shall have been made by a duly appointed guardian or other legal representative of such person. The Benefits Department is under no obligation to inquire or investigate as to the competency of any Participant. Any payment to an appointed guardian or other legal representative under this Section shall be a payment for the account of the incapacitated person and a complete discharge of any liability of the Company and the Plan therefore.

10.6Successors. This Plan shall be binding upon the successors and assigns of the Company and upon the heirs, beneficiaries and personal representatives of the individuals who become Participants hereunder.

10.7Unclaimed Benefit. Each Participant shall keep the Benefits Department informed of his or her current address and the current address of his or her designated beneficiary. The Benefits Department shall not be obligated to search for the whereabouts of any person. If the location of a Participant is not made known to the Benefits Department within three years after the date on which payment of the Participant’s Supplemental Deferral and Supplemental Employer Accounts may first be made, payment may be made as though the Participant had died at the end of the three-year period. If, within one additional year after such three-year period has elapsed, or, within three years after the actual death of a Participant, the designated beneficiary of the Participant has not been located, then there shall be no further obligation to pay any benefit hereunder to such Participant or designated beneficiary and such benefit shall be irrevocably forfeited.

10.8Limitations on Liability. Notwithstanding any of the preceding provisions of the Plan, neither the Plan Administrator, the Benefits Department, the Benefits Governance Committee, the Corporate Investment Committee, or the Compensation and Human Resources Committee, nor any individual acting as the Plan Administrator’s, the Benefits Department’s, the Benefits Governance Committee’s, the Corporate Investment Committee’s, the Compensation and Human Resources Committee’s, or the Company’s employee, agent, or representative shall be liable to any Participant, former Participant or other person for any claim, loss, liability or expense incurred in connection with the Plan.

10.9Conflicts. If any person holds a position under this Plan through which he or she is charged with making a decision about his or her own (or any immediate family member’s) Plan participation, including, without limitation, eligibility, account valuation, or investments, then such person shall be recused and the decision shall be made by the Plan Administrator. If a decision is required regarding the senior human resources officer’s Plan participation, including without limitation, eligibility, account valuation or investments, such decision shall be made by the Company’s Chief Executive Officer.

10.10Compliance with Section 409A. This Plan is intended to be administered in compliance with Section 409A of the Code and each provision of the Plan shall be interpreted, to the extent possible, to comply with Section 409A of the Code.

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IN WITNESS WHEREOF, the Company has caused this Plan to be executed by its duly authorized officer as of the _29^th_ day of _December____________, 2014.

PNM RESOURCES, INC.

By:    /s/ Patrick V. Apodaca

Senior Vice President and General Counsel

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TABLE OF CONTENTS

Page

ARTICLE I

DEFINITIONS

1.1 General1

1.2 Construction5

ARTICLE II

ELIGIBILITY; ADOPTION BY AFFILIATES

2.1 The Eligible Class6

2.2 Selection of Participants6

2.3 Election to Participate6

2.4 Discontinuance of Participation6

2.5 Adoption by Affiliates7

ARTICLE III

DEFERRALS AND CREDITS

3.1 Supplemental Deferral Agreement7

3.2 Supplemental Deferrals7

3.3 Matching and Standard Credits7

3.4 Supplemental Credits8

3.5 Discretionary Credits9

3.6 Benefits Not Contingent9

3.7 Allocation Among Affiliates9

ARTICLE IV

VESTING

4.1 Vesting in the Supplemental Deferral Account, the Matching Credit Account and the Standard Credit Account10

4.2 Vesting in the Supplemental Credit Account10

4.3 Acceleration of Vesting10

ARTICLE V

ADJUSTMENT OF ACCOUNTS

5.1 Adjustment of Accounts11

5.2 Investment Direction11

5.3 Special Company Stock Fund Provisions12

5.4 Compliance with Securities Laws12

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TABLE OF CONTENTS

(continued)

Page

ARTICLE VI

DISTRIBUTIONS

6.1 Distribution Events13

6.2 Form of Distribution13

6.3 Amount of Distribution16

6.4 Timing of Distributions16

6.5 Beneficiary Designation17

6.6 Withholding17

6.7 Deductibility17

6.8 Ban on Acceleration of Benefits17

6.9 Distributions Treated as Made Upon a Designated Event17

ARTICLE VII

TRANSFERS FROM ESP I

7.1 Combination with ESP I17

7.2 Accounting17

ARTICLE VIII

ADMINISTRATION OF THE PLAN

8.1 General Powers and Duties18

8.2 Claims19

ARTICLE IX

AMENDMENT

9.1 Amendment21

9.2 Effect of Amendment                            22

9.3 Termination22

ARTICLE X

GENERAL PROVISIONS

10.1 Participant’s Rights Unsecured22

10.2 No Guaranty of Benefits22

10.3 No Enlargement of Employee Rights                    22

10.4 Spendthrift Provision22

10.5 Incapacity of Participant23

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TABLE OF CONTENTS

(continued)

Page

10.6 Successors23

10.7 Unclaimed Benefit23

10.8 Limitations on Liability23

10.9 Conflicts23

10.10 Compliance with Section 409A23

iii

EX-10.2

Exhibit 10.2

EMPLOYEE RETENTION AGREEMENT

THIS AGREEMENT is entered into by and between PNM Resources, Inc. (“PNMR”) and Charles N. Eldred (the “Employee”) (collectively, the “Parties”).

RECITALS:

To incentivize Employee to continue employment through December 31, 2017 and meet certain performance measures, PNMR is offering Employee the Retention Bonuses and the Restricted Stock Rights Awards as specified in this Agreement.

TERMS AND CONDITIONS:

1.Effective Date of Agreement.

This Agreement shall be effective on January 1, 2015 (the “Effective Date”).

2.Scope of Agreement; At Will Employment.

All terms and conditions of Employee’s employment with PNMR Services Company (the “Company”) are unchanged and are determined pursuant to Company’s employment policies and practices unless otherwise specifically modified by this Agreement. For the avoidance of doubt, Employee remains eligible to participate in benefit plans and programs sponsored by PNMR and its affiliates that are generally available to officers of PNMR including but not limited to, the Officer Annual Incentive Plan, the Long-Term Incentive Plan and the Officer Retention Plan, subject to the terms and conditions of those plans. This Agreement is intended to supplement and not replace the benefit plans and programs sponsored by PNMR and its affiliates.

Employee acknowledges that Employee’s employment by Company remains “at-will” and that Employee or Company may terminate the employment relationship at any time for any reason. If the employment relationship ends during the term of this Agreement, this Agreement will only govern the terms of the payment of the Retention Bonuses and the Restricted Stock Rights Awards.

3.Retention Bonus and Restricted Stock Rights Award.

Employee shall be entitled to the Retention Bonuses and the Restricted Stock Rights Awards set forth below if: (1) Employee remains employed by Company through the applicable Retention Dates; (2) Employee continues to devote substantially all of Employee’s undivided working time, attention, knowledge, and skills to Employee’s job assignment as determined by the Chief Executive Officer in her discretion; (3) Employee completes or satisfies the Performance Deliverables listed on Appendix A prior to the applicable Retention Dates; and (4) Employee executes and does not revoke the release in accordance with Section 9 (Release).

If Employee satisfies the Performance Deliverables, Employee shall receive the Retention Bonus and the Restricted Stock Rights in the amounts specified in the tables below. Shortly after each Retention Date, the Chief Executive Officer will assess and certify to the PNMR Compensation and Human Resources Committee (the “Committee”) whether Employee has satisfied the Performance Deliverables. Within 60 days of each Retention Date, the

Committee will consider the Chief Executive Officer’s certification and make the final determination of the satisfaction of the Performance Deliverables.

If Employee does not satisfy the Performance Deliverables for Retention Bonus 1 and Restricted Stock Rights Award 1, but satisfies the Performance Deliverables for Retention Bonus 2 and Restricted Stock Rights Award 2, Employee shall be entitled to receive Retention Bonuses 1 and 2 and Restricted Stock Rights Awards 1 and 2 at the time Retention Bonus 2 and Restricted Stock Rights 2 would otherwise be paid (less any amounts Employee has already received pursuant to this Agreement).

If Employee does not satisfy the Performance Deliverables, the Committee, in its discretion, may award Employee a Retention Bonus and/or a Restricted Stock Rights Award in such amount as it deems appropriate. In no event is Employee entitled to either a Retention Bonus or a Restricted Stock Rights Award if Employee does not satisfy the Performance Deliverables.

	Retention Date	Amount
Retention Bonus 1	December 31, 2016	$175,000
Retention Bonus 2	December 31, 2017	$200,000

The Retention Bonus shall be “paid” by allocating Discretionary Credits to Employee under the PNM Resources, Inc. Executive Savings Plan II (the “ESP II”). The Discretionary Credits will be credited under the ESP II in accordance with Section 7 (Discretionary Credits Allocated to ESP II) below. Employee does not have the right to receive cash in lieu of a Discretionary Credit.

	Retention Date	Restricted Stock Rights
Restricted Stock Rights Award 1	December 31, 2016	Restricted Stock Rights equal to $100,000/the Fair Market Value of one share of PNMR Stock as of the Grant Date.
Restricted Stock Rights Award 2	December 31, 2017	Restricted Stock Rights equal to $275,000/the Fair Market Value of one share of PNMR Stock as of the Grant Date.

The Restricted Stock Rights Awards are granted pursuant to the 2014 Performance Equity Plan (the “PEP”). The terms of the PEP are hereby incorporated by reference. Capitalized terms used in this Agreement not otherwise defined in this Agreement shall have the meanings given to such terms in the PEP.

2

The Grant Date for Restricted Stock Rights Awards shall be the date on which the Committee makes a final determination of the Performance Deliverables, which generally will be at the Committee’s first regularly scheduled meeting in 2017 and 2018. If the Committee makes a determination of the satisfaction of the Performance Deliverables during a blackout period, the Grant Date will be the first trading day after expiration of the blackout period, as determined in accordance with PNMR’s Equity Compensation Policy.

Restricted Stock Rights Award 1 shall be paid in the form of Stock of PNMR during the period beginning on January 1, 2017 and ending on March 15, 2017, provided Employee has executed and not revoked the release required by Section 9 (Release). Restricted Stock Rights Award 2 shall be paid in the form of Stock of PNMR during the period beginning on January 1, 2018 and ending on March 15, 2018, provided Employee has executed and not revoked the release required by Section 9 (Release).

4.Termination of Employment.

(a)Termination by Company without Cause. Company may terminate Employee’s employment without “Cause” prior to the Retention Date (including following a Change in Control). If Company terminates Employee’s employment without Cause pursuant to this Section, Employee will receive a Pro Rata Retention Bonus (as defined below). Employee also shall be eligible for a Pro Rata Restricted Stock Rights Award (as defined below). In order to receive the Pro Rata Retention Bonus and the Pro Rata Restricted Stock Rights Award, Employee must execute and not revoke the release required by Section 9 (Release) at the time specified in Section 9 (Release). In such instance, Employee also may be entitled to receive severance or retention benefits pursuant to the PNM Resources, Inc. Non-Union Severance Pay Plan or the PNM Resources, Inc. Officer Retention Plan if the requirements of the plans are met.

(b)Termination by Company for Cause. If Company terminates Employee’s employment for “Cause” prior to a Retention Date, Employee will not be entitled to receive any Retention Bonus or any Restricted Stock Rights Award for any Retention Date after the date of Employee’s termination.

(c)Termination by Employee. If Employee terminates employment for any reason prior to a Retention Date, Employee will not be entitled to receive any Retention Bonus or any Restricted Stock Rights Award for any Retention Date after the date of Employee’s termination.

5.Disability.

If Employee becomes Disabled prior to the Retention Date, Employee will receive a Pro Rata Retention Bonus and a Pro Rata Restricted Stock Rights Award. As a condition to receiving the Pro Rata Retention Bonus and the Pro Rata Restricted Stock Rights Award, Employee must execute and not revoke the release required by Section 9 (Release) at the time specified in Section 9 (Release).

6.Death.

If Employee dies prior to a Retention Date, Employee will receive a Pro Rata Retention Bonus and a Pro Rata Restricted Stock Rights Award.

3

7.Discretionary Credits Allocated to ESP II.

If Employee satisfies the requirements of Section 3 (Retention Bonus and Restricted Stock Rights Award), Section 4(a) (Termination of Employment – Termination by Company without Cause), Section 5 (Disability) or Section 6 (Death), the Committee shall allocate Discretionary Credits equal to the applicable Retention Bonus or Pro Rata Retention Bonus to Employee’s Discretionary Credit Account in the ESP II as of the date set forth in Section 9 (Release). The Discretionary Credits shall be paid in the form of annual installments over five (5) years in accordance with the terms of the ESP II. If Employee dies before the expiration of the installment period, the remaining installment distributions will be paid in a single lump sum payment to Employee’s designated beneficiary. Distribution of the Discretionary Credits will begin on the earliest of Employee’s Separation from Service (as defined in ESP II), death or Disability (as defined in ESP II). If Employee is a Specified Employee (as defined in ESP II), distributions due to Separation from Service will begin on the date which is six months after Employee’s Separation from Service. Employee hereby agrees to the terms and provisions of the ESP II. Employee does not have the right to select the time and form of payment of the Discretionary Credits. If Employee does not execute the release as described in Section 9 (Release), such Discretionary Credits shall be forfeited.

8.Definitions.

The following words and phrases shall have the meanings set forth in this Section 8, unless a clearly different meaning is required by the context in which the word or phrase is used in this Agreement:

(a)“Cause.” For purposes of this Agreement, “Cause” shall have the meaning set forth in the PNM Resources, Inc. Officer Retention Plan.

(b)“Change in Control.” For purposes of this Agreement, “Change in Control” shall have the meaning set forth in the PNM Resources, Inc. Officer Retention Plan.

(c)“Disability.” For purposes of this Agreement, “Disability” or “Disabled” shall have the meaning set forth in the ESP II.

(d)“Pro Rata Retention Bonus.” Employee shall be entitled to receive a Pro Rata Retention Bonus if Employee is terminated without Cause or Employee dies or becomes Disabled. The amount of the “Pro Rata Retention Bonus” will equal $375,000 less any portion of Retention Bonus 1 previously paid to Employee multiplied by the following fraction:

The numerator of the fraction is the number of days that elapse between January 1, 2015 and the date on which Employee is terminated by Company without Cause, dies or becomes Disabled. The denominator of the fraction is 1,095.

The Pro Rata Retention Bonus shall be allocated to the ESP II as a Discretionary Credit in accordance with Section 7 (Discretionary Credits Allocated to ESP II). The Pro Rata Retention Bonus will be credited to the ESP II as of the date of Employee’s termination without Cause, death or Disability. Employee does not have the right to receive cash in lieu of the Pro Rata Retention Bonus.

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(e)“Pro Rata Restricted Stock Rights Award.” Employee shall be entitled to receive a Pro Rata Restricted Stock Rights Award if Employee is terminated without Cause or Employee dies or becomes Disabled. The Grant Date for the Pro Rata Restricted Stock Rights Award will be the date of Employee’s termination without Cause, death or Disability. The amount of the “Pro Rata Restricted Stock Rights Award” will equal Restricted Stock Rights Awards 1 and 2 less any portion of Restricted Stock Rights Award 1 previously paid to Employee multiplied by the following fraction:

The numerator of the fraction is number of days that elapse between January 1, 2015 and the date on which Employee is terminated by Company without Cause, dies or becomes Disabled. The denominator of the fraction is 1,095.

The Pro Rata Restricted Stock Rights Award shall be paid to Employee within sixty (60) days following the date of his termination of employment, death or Disability provided Employee has executed the release as required by Section 9 (Release). Payments of the Pro Rata Restricted Stock Rights Awards will be made in the form of Stock of PNMR.

9.Release.

The Retention Bonus or Pro Rata Retention Bonus shall be allocated as Discretionary Credits to the ESP II as of the earliest of (1) the applicable Retention Date, (2) Employee’s termination by Company without Cause (including death), or (3) Employee’s Disability (the “Crediting Date”). As a condition to receiving the Retention Bonus or Pro Rata Retention Bonus and the Restricted Stock Rights Award or the Pro Rata Restricted Stock Rights Award, Employee must execute and not revoke a full and general release, releasing all claims that Employee may have against Company and any Affiliate of Company arising out of and related to Employee’s employment or termination of employment with Company or its Affiliates. Such release shall be prepared by Company. Employee shall receive the Release within five (5) days of the Crediting Date. Employee shall have until the later of (1) 21 days or (2) the date on which the Employee is informed of the level of satisfaction of the Performance Deliverables to review the Release and sign it and return it to Company. In no event may Employee return the Release after March 7 of the calendar year following the Retention Date. Employee shall have seven (7) days to revoke the Release. If Employee does not sign the Release within the required time period or if Employee revokes the Release, the Discretionary Credits credited to Employee’s ESP II Account shall be forfeited and Employee will not receive the Restricted Stock Rights or the Pro Rata Restricted Stock Rights Award. For the avoidance of doubt, a Release will not be required in the event of Employee’s death.

10.Clawback.

The Retention Bonus and the Restricted Stock Rights Awards are subject to potential forfeiture or “clawback” to the fullest extent called for by applicable federal or state law or PNMR policy. Employee hereby agrees to return the full amount required by applicable law or PNMR policy.

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11.Binding Nature of Agreement.

This Agreement will be binding upon and inure to the benefit of Employee and PNMR, but neither this Agreement nor any rights arising hereunder may be assigned or pledged by Employee.

12.Severability.

If any provision of this Agreement as applied to either party or to any circumstance is adjudged by a court of competent jurisdiction to be void or unenforceable for any reason, the same will in no way affect any other provision of this Agreement or the validity or enforceability of this Agreement.

13.Amendment or Waiver.

No provision of this Agreement may be modified, waived or discharged unless such modification, waiver or discharge is agreed to in a writing signed by Employee and an authorized officer of PNMR. No waiver by either party hereto at any time of any breach by the other party hereto of any condition or provision of this Agreement to be performed by such other party will be deemed a waiver of any other condition or provision at any time.

14.Governing Law.

This Agreement will be governed in all respects, whether as to validity, construction, capacity, performance, or otherwise, by the laws of the State of New Mexico.

15.Entire Agreement.

This Agreement embodies the entire agreement of the Parties respecting the payment of a Retention Bonus and Restricted Stock Rights Award to Employee.

16.Further Assurances.

Each party agrees to cooperate fully with the other party and to execute such further instruments, documents and agreements, and to give such further written assurances, as may be reasonably requested by the other party to evidence and reflect the transactions described herein and contemplated hereby and to carry into effect the intent and purposes of this Agreement.

17.Counterparts.

This Agreement may be executed in counterparts, each of which shall be deemed an original, but all of which together will constitute one and the same instrument.

18.Dispute Resolution.

Any dispute over this Agreement must first be submitted in writing to the Vice President, Human Resources of PNMR, within ten (10) days of Employee becoming aware of the dispute. The President and Chief Executive Officer will issue a written decision on the dispute within ten (10) days of receipt. If Employee disagrees with the decision, Employee may appeal to the

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Committee within ten (10) days of receipt of the decision. The Committee will issue its decision on the appeal within ten (10) business days of receipt of the appeal. The decision of the Committee shall be final and binding on all Parties to this Agreement.

19.Section 409A Compliance.

(a)Ban on Acceleration or Deferral. Under no circumstances may the time or schedule of any payment made or benefit provided pursuant to this Agreement be accelerated or subject to a further deferral except as otherwise permitted or required pursuant to regulations and other guidance issued pursuant to Section 409A of the Code.

(b)No Elections. Employee does not have any right to make any election regarding the time or form of any payment due under this Agreement other than the elections made in Section 7 (Discretionary Credits Allocated to ESP II), which elections are irrevocable.

(c)Compliant Operation and Interpretation. This Agreement shall be administered in accordance with Section 409A or an exception thereto, and each provision of this Agreement shall be interpreted, to the extent possible, to comply with Section 409A or to qualify for an exception thereto. Although this Agreement has been designed to comply with Section 409A or to fit within an exception to the requirements of Section 409A, PNMR specifically does not warrant such compliance. Employee remains solely responsible for any adverse tax consequences imposed upon him by Section 409A.

IN WITNESS WHEREOF, PNMR and Employee have caused this Agreement to be executed as of the date set forth below.

PNM RESOURCES, INC

By: /s/ Patrick V. Apodaca    

Its: SVP and General Counsel

December 9, 2014    

Date

Charles N. Eldred    

Employee’s Name (printed)

/s/ Charles N. Eldred    

Employee’s Signature

December 9, 2014    

Date

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Appendix A

Performance Deliverables for December 31, 2016 Retention Date

Achieve a six percent (6%) rate of earnings growth between 1/1/15 to 12/31/2016. The rate of earnings growth is the number, expressed as a percentage, determined by dividing the Incentive Earnings Per Share for calendar year 2016 by the Incentive Earnings Per Share for calendar year 2014 and then subtracting 1 from the quotient.

The following is an example of the calculation:

•The Incentive Earnings Per Share in calendar year 2014 is 1.10.

•The Incentive Earnings Per Share in calendar year 2016 is 1.17.

•Divide 1.17 by 1.10 and subtract the result by 1.

•The result is 6%.

Incentive Earnings Per Share shall be as defined in the Officer Annual Incentive Plan for the applicable year.

Performance Deliverables for December 31, 2017 Retention Date

Achieve a nine percent (9%) rate of earnings growth between 1/1/15 to 12/31/2017. The rate of earnings growth is the number, expressed as a percentage, determined by dividing the Incentive Earnings Per Share for calendar year 2017 by the Incentive Earnings Per Share for calendar year 2014 and then subtracting 1 from the quotient.

The following is an example of the calculation:

•The Incentive Earnings Per Share in calendar year 2014 is 1.10.

•The Incentive Earnings Per Share in calendar year 2017 is 1.20.

•Divide 1.20 by 1.10 and subtract the result by 1.

•The result is 9%.

Incentive Earnings Per Share shall be as defined in the Officer Annual Incentive Plan for the applicable year.

A-1

EX-10.3

Exhibit 10.3

EXTENSION OF LOI DEADLINE

UNDER AMENDMENT NO. SIX TO

UNDERGROUND COAL SALES AGREEMENT

SAN JUAN COAL COMPANY, a Delaware corporation (“SJCC”), PUBLIC SERVICE COMPANY OF NEW MEXICO, a New Mexico corporation (“PNM”), and TUCSON ELECTRIC POWER COMPANY, an Arizona Corporation (“TEP” and together with PNM, the “Utilities”), all parties to that certain Amendment No. Six to Underground Coal Sales Agreement dated October 2, 2014 (“Amendment Six”), do hereby agree as follows.

RECITALS

A. All capitalized terms used but not defined herein shall have the meaning set forth in Amendment Six.

B. SJCC and the Utilities entered into Amendment Six.

C. Amendment Six contemplated negotiation of a Transaction involving the acquisition by the Purchaser Parties of the assets or stock of SJCC and SJTC, with the Purchaser Parties including one or more of the Utilities, an entity directly or indirectly wholly owned exclusively by either or both of the Utilities, or such other entity agreed to by the Parties.

D. Amendment Six includes an obligation to extend the LOI Deadline to a date no later than March 31, 2015, and pursuant to that obligation the Parties previously extended the LOI Deadline to January 31, 2015.

E. Since entering into Amendment Six, the Utilities now desire for SJCC, SJTC and BBNMC to negotiate with one or more third parties, as agreed by the Parties, as potential Purchaser Parties (each a “Third Party” and collectively, “Third Parties”), to extend the LOI Deadline to May 1, 2015, and to conclude a Purchase Agreement with a Third Party by no later than May 1, 2015.

F. SJCC, SJTC and BBNMC are willing to further extend the LOI Deadline until May 1, 2015 and to pursue negotiations of a Purchase Agreement with Third Parties identified by the Utilities under the terms and conditions set forth in this Agreement.

AGREEMENT

NOW THEREFORE, for good and valuable consideration, the receipt and sufficiency of which is hereby acknowledged, the parties hereto agree as follows:

1. The LOI Deadline under Amendment Six is extended until 5:00 p.m., Farmington, New Mexico time on May 1, 2015 under the following conditions:

a. The LOI Deadline is now understood to contemplate execution of a Purchase Agreement between SJCC, SJTC and BBNMC and a Third Party, rather than an LOI between SJCC, SJTC and BBNMC and the Utilities.

b. Purchaser Parties is understood to include Third Parties.

c. If no Purchase Agreement is entered into by the LOI Deadline, then the Parties have no further obligations (including those contemplated by the second paragraph of Section 12.6(A) of the UG-CSA) to negotiate a Purchase Agreement beyond the LOI Deadline unless mutually agreed in writing by the Parties.

d. In the sole judgment of BBNMC, SJCC and SJTC, for reasons, including, but not limited to, the consideration or other terms and conditions of the Purchase Agreement are unacceptable, BBNMC, SJCC and SJTC may elect not to continue with negotiations or enter into a Purchase Agreement. In addition, in the sole judgment of the Utilities, for reasons, including, but not limited to, the coal price under the proposed Coal Sales Agreement with a Third Party (“Coal Sales Agreement”) or other terms and conditions of the Coal Sales Agreement or Purchase Agreement are unacceptable, the Utilities may elect not to continue with negotiations or enter into a Coal Sales Agreement.

2. To the extent of any conflict between the terms of the Amendment Six and this Agreement, this Agreement shall control.

[SIGNATURE PAGES FOLLOW]

IN WITNESS WHEREOF, the Parties hereto have caused this Agreement to be executed on their behalf by their respective officers, thereunto duly authorized.

Public Service Company of New Mexico

By:_/s/ Charles N. Eldred____________

Name:_Charles N. Eldred___________

Title:_Executive Vice President_______

and Chief Financial Officer         Date:__February 20, 2015___

Tucson Electric Power Company

By:_/s/ Mark C. Mansfield____________

Name:_Mark C. Mansfield___________

Title:___VP Energy Resources_________                 Date:__20 Feb 2015_________

San Juan Coal Company

By:_/s/ Patrick Risner______________

Name:_Patrick Risner______________

Title:___President_________________                 Date:__18 Feb 2015_________

San Juan Transportation Company and BHP Billiton New Mexico Coal, Inc. hereby acknowledge and agree to the terms of this Extension of LOI Deadline with the understanding that this commitment does not make these entities a party to the UG-CSA for any purpose:

San Juan Transportation Company

By:_/s/ Patrick Risner______________

Name:_Patrick Risner______________

Title:___President_________________                 Date:__18 Feb 2015_________

BHP Billiton New Mexico Coal, Inc.

By:_/s/ Patrick Risner______________

Name:_Patrick Risner______________

Title:___President_________________                 Date:__18 Feb 2015_________

EX-10.4.1

Exhibit 10.4.1            

SHAREWORKS

Template Type Group: Grant Agreement

Template Type: Grant Agreement Template

Template Name: PNM Officer Performance Share Grant Agreement

Language (s): English

Label: Agreement

HTML:

Acknowledgment Form

###GRANT DATE###

###PARTICIPANT NAME###

Dear ###PARTICIPANT_ NAME###:

Pursuant to the PNM Resources, Inc. 20__ Long-Term Performance Plan (‘LTIP’), you have earned____ shares of stock of PNM Resources, Inc. as outlined below.

Employee ID:	_______________
Granted To:	_______________
Grant ID:	_______________
Grant Date:	_______________
Granted:	_______________
Grant Price:	$0.0000
Vesting Schedule	: 100% immediately

By my acceptance below, I hereby (1) accept delivery of the shares, which are being issued to me under the LTIP and the PNM Resources, Inc. Second Amended and Restated Omnibus Performance Equity Plan, as amended (the ‘Plan’) and (2) acknowledge my prior receipt of the LTIP and the Plan. If you need additional copies of the LTIP and the Plan, please contact Gail Vavruska-Marcum at 505-241-4631.

[I ACCEPT/ACCEPTANCE BUTTON]

EX-10.4.2

Exhibit 10.4.2        

SHAREWORKS

Template Type Group: Grant Agreement

Template Type: Grant Agreement Template

Template Name: PNM Officer RSA Grant Agreement

Language (s): English

Label: Agreement

HTML:

Acknowledgment Form

###GRANT_DATE###

###PARTICIPANT NAME###

Dear ###PARTICIPANT_ NAME###:

Pursuant to the PNM Resources, Inc. 20__ Long-Term Incentive Plan (the ‘LTIP’), you have been granted a Restricted Stock Rights Award for ____ shares of stock of PNM Resources, Inc. as outlined below.

Employee ID:	_______________
Granted To:	_______________
Grant ID:	_______________
Grant Date:	_______________
Granted:	_______________
Grant Price:	$0.0000
Vesting Schedule:	One-third per year for 3 years ### on 3/_/__ ### on 3/_/__ ### on 3/_/__

By my acceptance below, I hereby (1) acknowledge receipt of this Grant on the date shown above, which has been issued to me under the LTIP and the attached PNM Resources, Inc. 2014 Performance Equity Plan (the ‘Plan’), (2) acknowledge my prior receipt of the Plan and the LTIP, and (3) agree to conform to all of the terms and conditions of the Grant set forth in the Plan and the LTIP. For an additional copy of the LTIP, please contact Gail Vavruska-Marcum at 505-341-4631.

[I ACCEPT/ACCEPTANCE BUTTON]

EX-10.4.3

Exhibit 10.4.3            

SHAREWORKS

Template Type Group: Grant Agreement

Template Type: Grant Agreement Template

Template Name: PNM Director RSA Grant Agreement

Language (s): English

Label: Agreement

HTML:

Acknowledgment Form

###GRANT_DATE###

###PARTICIPANT NAME###

Dear ###PARTICIPANT_ NAME###:

Pursuant to the PNM Resources, Inc. 2014 Performance Equity Plan (the ‘Plan’), you have been granted a Restricted Stock Rights Award for ____ shares of stock of PNM Resources, Inc. as outlined below.

Employee ID:	_______________
Granted To:	_______________
Grant ID:	_______________
Grant Date:	_______________
Granted:	_______________
Grant Price:	$0.0000
Vesting Schedule:	One-third per year for 3 years ### on 5/__/__ ### on 5/__/__ ### on 5/__/__

By my acceptance below, I hereby (1) acknowledge receipt of this Grant on the date shown above, which has been issued to me under the attached Terms and Conditions and the Plan, (2) acknowledge receipt of the copy of the Plan and the Terms and Conditions of this Grant, and (3) agree to conform to all of the attached Terms and Conditions of the Grant and the Plan.

[I ACCEPT/ACCEPTANCE BUTTON]

Terms and Conditions of Restricted Stock Rights Award to Non-Employee Directors

Pursuant to the PNM Resources, Inc. 2014 Performance Equity Plan, you have been granted a Restricted Stock Rights Award for the number of shares specified on the Acknowledgment Form attached. The Acknowledgment Form and these Terms and Conditions are collectively referred to as the “Award Document.”

The Restricted Stock Rights Award is subject to all of the provisions set forth in the PNM Resources, Inc. 2014 Performance Equity Plan (the “Plan”) and this Award Document. Capitalized terms used in the Award Document that are not otherwise defined herein shall have the meanings given to such terms in the Plan.

1. Vesting.

(a) The Restricted Stock Rights Award shall vest in accordance with the vesting schedule on the Acknowledgment Form.

(b) If you have a Termination of Service as a Nonemployee Director, any nonvested Restricted Stock Rights Award will vest pursuant to Section 9.4 of the Plan.

2. Form and Timing of Delivery of Stock.

(a) If the Restricted Stock Rights vest as described on the Acknowledgment Form, you will receive the Stock payable with respect to such vested Restricted Stock Rights Award within ninety (90) days following the dates on which the Restricted Stock Rights vest.

(b) If any Restricted Stock Rights vest as described in Section 1(b), you will receive the Stock payable with respect to such Restricted Stock Rights within ninety (90) days following your Termination of Service.

3. Dividend Equivalents. You will not be entitled to receive a dividend equivalent for any of the Restricted Stock Rights granted hereunder.

4. Voting Rights. You will have no voting rights with respect to nonvested Restricted Stock Rights.

5. Clawback. All or any portion of this Restricted Stock Rights Award is subject to recapture or “clawback” to the extent necessary to comply with Company policy or applicable law. By accepting this Award, you agree to be bound by, and comply with, the terms of any such recapture or clawback provisions and with any Company request or demand for a recapture or clawback.

6. Waiver and Modification. The provisions of this Award Document may not be waived or modified unless such waiver or modification is in writing signed by the Company.

MANY OF THE PROVISIONS OF THIS AWARD DOCUMENT ARE SUMMARIES OF SIMILAR OR PERTINENT PROVISIONS OF THE PLAN. TO THE EXTENT THIS AWARD DOCUMENT IS SILENT ON AN ISSUE OR THERE IS A CONFLICT BETWEEN THE PLAN AND THIS AWARD DOCUMENT, THE PLAN PROVISIONS SHALL CONTROL

EX-10.4.4

Exhibit 10.4.4

EMPLOYEE RETENTION AGREEMENT

THIS AGREEMENT is entered into by and between PNMR Services Company (the “Company”) and Thomas G. Sategna (the “Employee”) (collectively, the “Parties”).

RECITALS:

The Employee has provided notice to the Company that he wants to voluntarily retire. The Company wishes to have Employee continue providing his services and continue his employment through December 31, 2015. The parties agree that Employee may step down from his position of Vice President and Corporate Controller as of March 31, 2015 but will continue his employment through December 31, 2015.

To incentivize Employee to continue through the Retention Date, meet certain performance measures, and ensure that Employee will not provide services for a competing business in accordance with the terms hereof, Employee will be eligible for a “Retention Bonus” and a “Performance Bonus” as specified by this Agreement.

TERMS AND CONDITIONS:

1.Effective Date of Agreement.

This Agreement shall be effective on January 1, 2015 (the “Effective Date”).

2.Scope of Agreement; At Will Employment.

Other than expressly set forth in this Agreement, all terms and conditions of the Employee’s employment are unchanged and are determined pursuant to Company’s employment policies and practices unless otherwise specifically modified by this Agreement.

During the term of this Agreement, Employee will continue to devote substantially all of Employee’s undivided working time, attention, knowledge, and skills to Employee’s current job assignment, or as may be assigned from time to time.

Employee acknowledges that Employee’s employment by the Company remains “at-will” and that Employee or the Company may terminate the employment relationship at any time for any reason. If the employment relationship between the parties ends during the term of this Agreement, this Agreement will only govern the terms of the payment of the Retention Bonus and the Performance Bonus.

3.Retention Bonus and Performance Bonus.

Employee shall be entitled to a Retention Bonus of $222,000, if: (1) Employee remains employed by the Company through the Retention Date, (2) Employee continues to devote substantially all of Employee’s undivided working time, attention, knowledge, and skills to Employee’s job assignment as determined by management in its discretion, (3) Employee executes and does not revoke the release called for by Section 11 (Release) and (4) Employee complies with the terms of the Restrictive Covenant Agreement described in Section 12 (Supplemental Restrictive Covenant Agreement) and Appendix B.

Employee also shall be entitled to a Performance Bonus if (1) Employee remains employed by the Company through the Retention Date, (2) Employee continues to devote substantially all of Employee’s undivided working time, attention, knowledge, and skills to Employee’s job assignment as determined by management in its discretion, (3) Employee completes the Performance Deliverables listed on Appendix A prior to the Retention Date, (4) Employee executes and does not revoke the release in accordance with Section 11 (Release) and (5) Employee complies with the terms of the Supplemental Restrictive Covenant Agreement described in Section 12 (Supplemental Restrictive Covenant Agreement) and Appendix B.

If, in the discretion of the Company’s Chief Financial Officer, the Performance Deliverables are achieved at an exceptional level as determined by the Chief Financial Officer, the Performance Bonus shall be in an amount equal to $125,000. If, in the discretion of the Company’s Chief Financial Officer, the Performance Deliverables are achieved at an acceptable level as determined by the Chief Financial Officer, the Performance Bonus shall be in an amount equal to $75,000. If, in the discretion of the Chief Financial Officer, the Performance Deliverables are achieved, but at a less than acceptable level as determined by the Chief Financial Officer, the Chief Financial Officer has the full discretion and authority to reduce the Performance Bonus to an amount between $0 and $75,000.

The Retention Bonus and the Performance Bonus payments made pursuant to this Agreement shall be subject to withholding of applicable income and employment taxes. The Retention Bonus and the Performance Bonus will be classified for payroll and other purposes as Employee Recognition Awards (“ERA”).

4.Termination of Employment.

(a)Termination by Company without Cause. Company may terminate Employee’s employment without “Cause” prior to the Retention Date (including following a Change in Control), by providing Employee with 30 days advance written notice of termination. The notice of termination shall be accompanied by the release required by Section 11 (Release). Company may prohibit or restrict Employee’s access to Company premises during the 30-day notice period and may place Employee on a paid leave of absence during all or any portion of the notice period. Employee’s termination of employment will be effective on the last day of the notice period. If Company terminates Employee’s employment without Cause pursuant to this Section, Employee will receive a Pro Rata Bonus (as defined below) which shall be payable on Employee’s last day of employment, provided Employee executes and does not revoke the release required by Section 11 (Release) at the time specified in Section 11 (Release). In such instance, Employee will not be entitled to receive benefits pursuant to the PNM Resources, Inc. Non-Union Severance Pay Plan.

(b)Termination by Company for Cause. If the Company terminates Employee’s employment for “Cause” prior to the Retention Date, Employee will not be entitled to receive the Retention Bonus or the Performance Bonus.

(c)Termination by Employee. If Employee terminates employment for any reason prior to the Retention Date, the Employee will not be entitled to receive the Retention Bonus or the Performance Bonus.

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5.Disability.

If Employee becomes Disabled prior to the Retention Date, Employee will receive a Pro Rata Bonus. As a condition to receiving the Pro Rata Bonus, Employee must execute and not revoke the release required by Section 11 (Release) at the time specified in Section 11 (Release). If Employee becomes Disabled and entitled to a payment pursuant to this Section, the Company will not terminate Employee’s employment until at least 30 days following the effective date of Employee’s Disability.

6.Death.

If Employee dies prior to the Retention Date, Employee shall receive a Pro Rata Bonus. In such instance, the Pro Rata Bonus will not be deferred into the ESP II pursuant to Section 7 (Deferral into Executive Savings Plan II) and instead will be paid in a single lump sum within thirty (30) days of the date of the Employee’s death.

7.Deferral into Executive Savings Plan II

If Employee receives the Retention Bonus and Performance Bonus, or a Pro Rata Bonus, due to the events listed in Sections 3 (Retention Bonus and Performance Bonus), 4(a) (Termination of Employment – Termination by Company without Cause) or 5 (Disability), Employee hereby elects to defer 100% of the Retention Bonus and 100% of the Performance Bonus into the PNM Resources, Inc. Executive Savings Plan II (the “ESP II”) as a Supplemental Deferral. This Supplemental Deferral shall be referred to as Employee’s “Retention Bonus Supplemental Deferral.” Employee hereby elects to have his Retention Bonus Supplemental Deferral paid in the form of annual installments over five (5) years in accordance with the terms of the ESP II. If Employee dies before the expiration of the installment period, the remaining installment distributions will be paid in a single lump sum payment to Employee’s designated beneficiary. Distribution of Employee’s Retention Bonus Supplemental Deferral will begin on the earliest of Employee’s Separation from Service (as defined in ESP II), death or Disability (as defined in ESP II). If Employee is a Specified Employee (as defined in ESP II), distributions due to Separation from Service will begin on the date which is six months after Employee’s Separation from Service. Employee hereby agrees to the terms and provisions of the ESP II. Employee understands that his elections are irrevocable.

8.Participation in Incentive Plans.

Notwithstanding anything in any incentive plan to the contrary, Employee acknowledges that he will not be eligible to participate in the PNM Resources, Inc. 2015 Annual Incentive Plan, the PNM Resources, Inc. 2015 Officer Annual Incentive Plan or the PNM Resources, Inc. 2015 Long-Term Incentive Plan. Employee also acknowledges that pursuant to the terms of the PNM Resources, Inc. 2014 Long-Term Incentive Plan (“2014 LTIP”), he is not eligible to receive any awards under the 2014 LTIP.

For the avoidance of doubt, Employee also acknowledges that he is not eligible under the terms of the PNM Resources, Inc. 2013 Long-Term Incentive Plan (the “2013 LTIP”) to receive a grant of time vested Restricted Stock Rights pursuant to the 2013 LTIP.

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Employee shall be eligible to receive a grant of time vested Restricted Stock Rights pursuant to the PNM Resources, Inc. 2012 Long-Term Incentive Plan (the “2012 LTIP”), subject to the terms and conditions of the 2012 LTIP.

Employee shall be eligible to receive a Performance Share Award pursuant to the 2013 LTIP and the 2012 LTIP, subject to the terms and conditions of the 2013 LTIP and 2012 LTIP.

9.Definitions.

The following words and phrases shall have the meanings set forth in this Section 9, unless a clearly different meaning is required by the context in which the word or phrase is used in this Agreement:

(a)“Cause.” For purposes of this Agreement, “Cause” shall have the meaning set forth in the PNM Resources, Inc. Officer Retention Plan.

(b)“Change in Control.” For purposes of this Agreement, “Change in Control” has the meaning ascribed to that term in the Retention Plan in which the Employee participates (i.e., the Officer Retention Plan or the Employee Retention Plan) at the time of the closing of a transaction or the occurrence of an event that results in the Change in Control.

(c)“Disability.” For purposes of this Agreement, “Disability” or “Disabled” shall have the meaning set forth in the ESP II.

(d)“Effective Date.” The “Effective Date” of this Agreement is January 1, 2015.

(e)“Pro Rata Bonus.” A Pro Rata Bonus will be paid to the Employee if he is terminated without Cause or the Employee dies or becomes Disabled. The amount of the “Pro Rata Bonus” will equal $297,000 multiplied by a fraction. The numerator of the fraction is the number of days that elapse between the April 1, 2015 and the date on which the Employee is terminated by the Company without Cause, dies or becomes Disabled. The denominator of the fraction is 275. If Employee terminates employment for any reason prior to April 1, 2015, Employee shall not be entitled to a Pro Rata Bonus.

(f)“Retention Date.” The “Retention Date” for purposes of this Agreement is December 23, 2015.

10.Confidentiality.

Employee understands and agrees that the terms of this Agreement are to remain confidential and are to be made known only to his immediate family, attorneys, tax authorities upon request, and tax advisors and accountants for purposes of any tax preparation or reporting that may be required. Employee will not divulge or discuss, directly or indirectly, in any newspaper, electronic media, or other public or private forum, or with any third parties (including current or former employees of the Company or its affiliates) the terms of this Agreement unless specifically ordered to do so by a court of competent jurisdiction (in which case the Company will be first notified and given a reasonable opportunity to challenge the order or proposed court order). Furthermore, Employee will use all reasonable efforts to ensure that

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his agents, other family members, friends, co-workers, former co-workers and acquaintances do not discover or publicize the terms of this Agreement. Employee understands and agrees that this confidentiality provision is a material term of this Agreement.

11.Release.

As a condition to receiving the Retention Bonus and the Performance Bonus or a Pro Rata Bonus, Employee must execute and not revoke a full and general release, releasing all claims that Employee may have against the Company and any affiliate of the Company arising out of and related to Employee’s employment or termination of employment with the Company or its affiliates. Such release shall be prepared by the Company. In no event will a payment be made pursuant to this Agreement after March 31, 2016.

(a)Voluntary Termination at the End of the Retention Period. If Employee remains employed through the Retention Date, Employee will receive the Release no later than November 23, 2015 and must sign the Release and return it to the Company on December 14, 2015. Employee shall have until 9:00 a.m. MST on December 22, 2015 to revoke the Release after execution. If Employee does not revoke the Release, Employee shall be eligible to “receive” the Retention Bonus and the Performance Bonus on December 23, 2015, but such Retention Bonus and Performance Bonus shall be deferred into the ESP II pursuant to Section 7 (Deferral into Executive Savings Plan II).

(b)Termination by Company without Cause. If Employee’s employment is terminated by the Company without Cause prior to the Retention Date, Employee shall receive the Release at the time the notice of termination is provided to Employee. Employee shall have 21 calendar days to review the Release and sign it and return it to the Company. Employee shall have seven (7) calendar days to revoke the Release. If Employee does not revoke the Release, Employee shall be eligible to “receive” the Pro Rata Bonus on his last day of employment, but such Pro Rata Bonus shall be deferred into the ESP II pursuant to Section 7 (Deferral into Executive Savings Plan II).

(c)Disability. If Employee becomes Disabled, Employee will receive the Release on the effective date of his Disability. Employee will have twenty-one (21) calendar days to consider the Release and return it to the Company. Employee shall have seven (7) calendar days to revoke the Release after execution. If Employee does not revoke the Release, Employee shall be eligible to “receive” the Pro Rata Bonus on the expiration of the Release revocation period, but such Pro Rata Bonus shall be deferred into the ESP II pursuant to Section 7 (Deferral into Executive Savings Plan II).

12.Supplemental Restrictive Covenant Agreement.

In addition to satisfying the requirements of Section 3 (Retention Bonus and Performance Bonus), in order to be eligible for both the Retention Bonus and the Performance Bonus or a Pro Rata Bonus, Employee must comply with the terms and conditions of the Supplemental Restrictive Covenant Agreement, which is attached as Appendix B. If Employee violates the terms and conditions of the Supplemental Restrictive Covenant Agreement, a total of $50,000 of the Retention Bonus, the Performance Bonus, and/or the Pro Rata Bonus not yet paid to Employee will be forfeited and will be deemed to compensate the Company for some, but not all,

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of the damages sustained by the Company. The parties acknowledge and agree that in the event Employee breaches the Supplemental Restrictive Covenant Agreement, the Company will sustain no less than $50,000 in damages. The parties further acknowledge and agree that this $50,000 is not intended to be, and is not to be construed as, liquidated damages and that, if Employee breaches the Supplemental Restrictive Covenant Agreement, the Company will also suffer irreparable harm that can only be remedied by injunctive relief prohibiting Employee from engaging in activities that would continue to breach the Supplemental Restrictive Covenant Agreement. The parties further acknowledge and agree that nothing herein is intended to restrict or otherwise modify the Company’s right to seek injunctive relief and/or additional monetary damages for a violation of the Supplemental Restrictive Covenant Agreement.

13.Clawback.

The Retention Bonus and the Performance Bonus are subject to potential forfeiture or “clawback” to the fullest extent called for by applicable federal or state law or Company policy. The Employee hereby agrees to return the full amount required by applicable law or Company policy.

14.Binding Nature of Agreement.

This Agreement will be binding upon and inure to the benefit of Employee and Company, but neither this Agreement nor any rights arising hereunder may be assigned or pledged by Employee.

15.Severability.

If any provision of this Agreement as applied to either party or to any circumstances is adjudged by a court of competent jurisdiction to be void or unenforceable for any reason, the same will in no way affect any other provision of this Agreement or the validity or enforceability of this Agreement.

16.Amendment or Waiver.

No provision of this Agreement may be modified, waived or discharged unless such modification, waiver or discharge is agreed to in a writing signed by Employee and an authorized officer of Company. No waiver by either party hereto at any time of any breach by the other party hereto of any condition or provision of this Agreement to be performed by such other party will be deemed a waiver of any other condition or provision at any time.

17.Governing Law.

This Agreement will be governed in all respects, whether as to validity, construction, capacity, performance, or otherwise, by the laws of the State of New Mexico.

18.Entire Agreement.

This Agreement embodies the entire agreement of the Parties respecting the payment of a Retention Bonus and a Performance Bonus to Employee, and the other terms expressly set forth in this Agreement.

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19.Further Assurances.

Each party agrees to cooperate fully with the other party and to execute such further instruments, documents and agreements, and to give such further written assurances, as may be reasonably requested by the other party to evidence and reflect the transactions described herein and contemplated hereby and to carry into effect the intent and purposes of this Agreement.

20.Counterparts.

This Agreement may be executed in counterparts, each of which shall be deemed an original, but all of which together will constitute one and the same instrument.

21.Dispute Resolution.

Any dispute over this Agreement must first be submitted in writing to the Vice President, Human Resources of the Company, within ten (10) days of the Employee becoming aware of the dispute. The Vice President, Human Resources will issue a written decision on the dispute within ten (10) days of receipt. If the Employee disagrees with the decision, the Employee may appeal to the PNM Resources, Inc. Benefits Governance Committee within ten (10) days of receipt of the decision. The Benefits Governance Committee will issue its decision on the appeal within ten (10) business days of receipt of the appeal. The decision of the PNM Resources, Inc. Benefits Governance Committee shall be final and binding on all parties to this Agreement.

22.Section 409A Compliance.

(a)Ban on Acceleration or Deferral. Under no circumstances may the time or schedule of any payment made or benefit provided pursuant to this Agreement be accelerated or subject to a further deferral except as otherwise permitted or required pursuant to regulations and other guidance issued pursuant to Section 409A of the Code.

(b)No Elections. Employee does not have any right to make any election regarding the time or form of any payment due under this Agreement other than the elections made in Section 7 (Deferral into Executive Savings Plan II), which elections are irrevocable.

(c)Compliant Operation and Interpretation. This Agreement shall be administered in accordance with Section 409A or an exception thereto, and each provision of this Agreement shall be interpreted, to the extent possible, to comply with Section 409A or to qualify for an exception thereto. Although this Agreement has been designed to comply with Section 409A or to fit within an exception to the requirements of Section 409A of the Code, the Company specifically does not warrant such compliance. Employee remains solely responsible for any adverse tax consequences imposed upon him by Section 409A.

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IN WITNESS WHEREOF, the Company and Employee have caused this Agreement to be executed as of the date set forth below.

PNMR SERVICES COMPANY

By: /s/ CN Eldred    

Its: Chief Financial Officer and Executive VP

12-9-2014    

Date

Thomas G. Sategna    

Employee’s Name (printed)

/s/ Tom Sategna    

Employee’s Signature

12/9/2014    

Date

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Appendix A

Performance Deliverable

1. Mentor named VP and Corporate Controller throughout Retention period and provide guidance as needed.

2. Review and discuss monthly financial statements with named VP and Corporate Controller, including variance analysis and write-up for CEO and CFO on results of operation.

3. Review quarterly results and attend quarterly variance meetings for income statement and balance sheet reviews in preparation for filing 1^st, 2^nd and 3^rd quarter 10-Q filings with the SEC.

4. Attend quarterly due diligence meetings in connection with 1^st, 2^nd, and 3^rd quarter 10-Q filings.

5. Review and provide comments to the 1^st, 2^nd, and 3^rd quarter 10-Q filings.

6. Work on year-end reporting issues/requirements with named VP and Corporate Controller in anticipation of 2015 year-end close and filing of the 2015 10-K.

7. Leverage regulatory experience in assisting with any of PNM’s regulatory filings, including reviewing testimony, participating in strategic decisions for filings, etc.

8. Leverage staff and intervener relationships regarding settlements of any regulatory proceedings before the NMPRC, as requested.

9. Work on special assignments from CFO as requested.

10. Attend and participate in VP and all officer meetings as appropriate.

11. Other duties as requested.

The Chief Financial Officer has the full discretion and authority to determine if each Performance Deliverable has been met by Employee. The Chief Financial Officer has the full discretion to increase or reduce the Performance Bonus based on the level of attainment of the Performance Deliverables, within the parameters described in Section 3 (Retention Bonus and Performance Bonus) of the Agreement.

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Appendix B

SUPPLEMENTAL RESTRICTIVE COVENANT AGREEMENT

This Supplemental Restrictive Covenant Agreement (this “Agreement”), is entered into effective as of January 1, 2015 by and between PNMR Services Company (the “Company”) and Thomas G. Sategna (“Employee”).

RECITALS

In exchange for the Performance Bonus and the Retention Bonus or a Pro Rata Bonus described in the attached Agreement and other good and valuable consideration, the sufficiency of which is hereby acknowledged, Employee understands and agrees to the terms set forth in this Agreement.

The purpose of this Agreement is to supplement the existing Restrictive Covenant Agreement dated May 15, 2012.

AGREEMENT

NOW, THEREFORE, Company and Employee agree as follows:

1.NON-COMPETITION. Employee agrees that for the duration of the “Restricted Period” (as defined below) Employee will not, without the prior written consent of Company: (1) engage in a “Competing Business” (as defined below) in the “Restricted Territory” (as defined below).

For purposes of this Agreement, Employee shall be deemed to be engaged in a Competing Business if, in any capacity, including but not limited to, proprietor, shareholder, partner, officer, lender, guarantor of debts or obligations, director, employee, or agent, Employee engages or participates directly or indirectly in the operation, ownership or management of any proprietorship, partnership, corporation, limited liability company, or other business entity that engages in any Competing Business within the Restricted Territory. A “Competing Business” is any person or entity that has negotiated or will negotiate with PNM Resources, Inc. (“PNMR”), or otherwise has engaged or will engage in efforts, to acquire all or part of PNMR or any of its Affiliates, including but not limited to acquisition through the purchase of stock, assets, or any other type of direct or indirect acquisition of PNMR or any of its Affiliates, whether or not such acquisition is successful.

2.RESTRICTED TERRITORY DEFINED. For purposes of Section 1, Section 2, and Section 3 (collectively, the “Restrictive Covenants”), the term “Restricted Territory” shall mean the continent of North America.

3.RESTRICTED PERIOD DEFINED. For purposes of the Restrictive Covenants, the term “Restricted Period” shall mean the period during Employee’s employment with the Company and continuing for the 24-month period following the termination of such employment. In the event that a court of competent jurisdiction determines that the Restricted Period described in the preceding sentence is excessive, the parties agree that the Restricted

B-1

Period shall mean the period during Employee’s employment with the Company and continuing for the 18-month period following the termination of such employment. In the event that a court of competent jurisdiction determines that the Restricted Period as modified in the preceding sentence is still excessive, the parties agree that the Restricted Period shall mean the period during Employee’s employment with the Company and continuing for the 12-month period following the termination of such employment.

4.REMEDIES; REASONABLENESS. Employee acknowledges and agrees that a breach by Employee of the Restrictive Covenants of this Agreement will constitute irreparable damage to Company, the exact amount of which will be impossible to ascertain and, for that reason, agrees that Company will be entitled to an injunction to be issued by any court of competent jurisdiction restraining and enjoining Employee from violating the provisions of the Restrictive Covenants. If Employee violates the terms and conditions of this Agreement, a total of $50,000 of the Retention Bonus, the Performance Bonus, and/or the Pro Rata Bonus (pursuant to the Employee Retention Agreement) not yet paid to Employee will be forfeited and will be deemed to compensate the Company for some, but not all, of the damages sustained by the Company. The parties acknowledge and agree that in the event Employee breaches this Agreement, the Company will sustain no less than $50,000 in damages. The parties further acknowledge and agree that this $50,000 is not intended to be, and is not to be construed as, liquidated damages and that, if Employee breaches this Agreement, the Company will also suffer irreparable harm that can only be remedied by injunctive relief prohibiting Employee from engaging in activities that would continue to breach this Agreement. The parties further acknowledge and agree that nothing herein is intended to restrict or otherwise modify the Company’s right to seek injunctive relief and/or additional monetary damages for a violation of this Agreement.

Employee expressly acknowledges and agrees that: (1) the provisions of the Restrictive Covenants contained herein are reasonable as to time and geographical area and do not place an unreasonable burden upon Employee, (2) Employee will be able to continue earning a livelihood while still complying with the Restrictive Covenants, (3) the public will not be harmed as a result of enforcement of these Restrictive Covenants, and (4) Employee understands and hereby agrees to each and every term and condition of the Restrictive Covenants set forth in this Agreement.

5.CONFIDENTIAL INFORMATION.

(a)Proprietary Information. Employee and Company hereby acknowledge and agree that in connection with the performance of Employee’s services, Employee shall be provided with or shall otherwise be exposed to or receive certain proprietary information of Company. Such proprietary information shall include, without limitation, any written, oral, electronic or any other form of information including the following: (1) past, present and future customer lists, consultant lists, and customer information as compiled by Company, including proposals for services, pricing, customer contact information, customer lists, sale and contract terms and conditions, contract expirations, and other compiled customer information; (2) Company’s own internal practices, procedures, and strategies; (3) Company’s financial condition and financial results of operation; (4) credit information and technical environments concerning Company or Company’s clients; (5) supply of material information, including sources and costs; (6) information in any form relating to Trade Secrets (as defined below), Intellectual Property (as defined below), confidential information, ideas, designs, products, descriptions, parts, test data, reports, recommendations, the Company’s research

B-2

and development, strategic planning, finance, marketing, and promotional activities and strategies, whether now existing, or planned, developed, or made available anytime in the future to the Company; (7) acquisition plans and other strategic plans; (8) all information which is designated as confidential, which the Employee has a reasonable basis to consider confidential or which is treated by the Company as confidential, including confidential or proprietary information from third parties, Company Customers, or Company Vendors; and (9) any and all information that has independent economic value to the Company, that is not generally known to and not readily ascertainable by proper means by an individual or entity who can obtain economic value from its disclosure or use (all of the foregoing shall be deemed “Proprietary Information” for purposes of this Agreement). The term “Proprietary Information” does not include information which (1) becomes generally available to the public other than as a result of a disclosure by Employee contrary to the terms of this Agreement, (2) was available on a non-confidential basis prior to its disclosure, or (3) becomes available on a non-confidential basis from a source other than Employee, provided that such source is not contractually obligated to keep such information confidential. Employee hereby agrees that, without the prior written consent of Company, any and all Proprietary Information shall be and shall forever remain the property of Company, and that during and after the Employee’s employment with Company, Employee shall not in any way disclose or reveal the Proprietary Information other than to Company’s Employees, officers and other employees and agents in the normal course of Employee’s employment, or as required pursuant to an order issued by a court of competent jurisdiction or other governmental agency.

(b)Trade Secrets. Employee, prior to and during this Agreement, has had and will have access to and become acquainted with various trade secrets which are owned by Company and are regularly used in the operation of its business and which may give Company an opportunity to obtain an advantage over competitors who do not know or use such trade secrets. Employee agrees and acknowledges that Employee has been granted access to these valuable trade secrets only by virtue of the confidential relationship created by Employee’s employment with Company. Employee shall not disclose any of the aforesaid trade secrets, directly or indirectly, or use them in any way, either during the Employee’s employment with Company or at any time thereafter, except as required in the course of employment by Company and for its benefit, or as required pursuant to an order issued by a court of competent jurisdiction or other governmental agency.

(c)Intellectual Property. “Intellectual Property” shall include inventions (whether or not patentable), patents, copyrights, trademarks (together with the good will of the business symbolized by said trademarks), domain names, trade secrets, rights of publicity, database rights, works of authorship, mask works, moral rights, designs, discoveries, know-how, show-how, ideas and information made or conceived or reduced to practice and all related or other intellectual and industrial property rights of any sort throughout the world, including all improvements and/or derivative works growing out of or relating to the foregoing, in whole or in part, conceived, created, developed, discovered or reduced to practice during the term of employment with Company and, to the extent allowed by law, during the Restricted Period, so far as it (1) relates, directly or indirectly, to Company’s Business, (2) results from or are suggested by any work assigned to or performed by Employee for Company, or (3) is used to develop or improve any Company equipment, supplies, facility, product, software, service, or trade secret, whether or not such Intellectual Property is developed entirely on Employee’s own time and with or without use of Company property.

B-3

Employee acknowledges and agrees that all Intellectual Property, whether the same is derived from the use of Proprietary Information or otherwise developed or conceived of by Employee, shall be and shall remain the exclusive property of Company. Employee further agrees that for a period of 12 months after the employment period, there shall be an irrebuttable presumption that all Intellectual Property that relates to services rendered hereunder developed, formulated, created, or conceived by Employee were derived from the use of Proprietary Information or were otherwise developed, formulated, created, or conceived of by Employee during the Employee’s employment with Company, and, as such, the same shall be and shall remain the exclusive property of Company. Employee shall promptly disclose to Company all written and graphic materials, computer software, inventions, discoveries and improvements authored, prepared, conceived or made by, for or at the direction of Employee during the Employee’s employment with Company and which are related to the Intellectual Property or the business of Company, and shall execute all such documents and instruments, including but not limited to any assignments and invention disclosure documents, as Company may reasonably determine are necessary or desirable in order to give effect to the preceding sentence or to preserve, protect or enforce Company’s rights with respect to any such work and any Intellectual Property therein.

(d)Ownership of Documents. Company shall own all papers, records, books, drawings, documents, manuals, and anything of a similar nature (collectively, the “Documents”) prepared by Employee in connection with the Employee’s employment. The Documents shall be the property of Company and are not to be used on other projects except upon Company’s prior written consent. Upon termination of the Employee’s employment, or as may be requested earlier by the Company, Employee shall surrender to Company any and all Documents or other property of whatsoever kind now or hereafter in Employee’s possession, custody, or control which contain or reflect in any manner whatsoever Proprietary Information or information which in any way relates to Company’s business.

6.GENERAL PROVISIONS.

(a)No Conflicting Agreements. Employee acknowledges that he has no commitments or obligations inconsistent with this Agreement and hereby agrees to indemnify and hold the Company harmless against any and all loss, damage, liability, or expense arising from any claim based upon circumstances alleged to be inconsistent with such acknowledgement.

(b)Severability. In the event that a court of competent jurisdiction determines that any portion of this Agreement is in violation of any statute or public policy, then only the portions of this Agreement which violate such statute or public policy shall be stricken. All portions of this Agreement which do not violate any statute or public policy shall continue in full force and effect. Further, any court order striking any portion of this Agreement shall modify the stricken terms to give as much effect as possible to the intentions of the parties under this Agreement.

(c)At-Will Employment. Nothing herein shall affect the “at-will” nature of Employee’s relationship with Company. As such, Employee may leave the Employee’s employment with Company at any time with or without notice or cause. In addition, Employee’s employment may be terminated by Company at any time with or without notice or cause.

B-4

(d)Governing Law. The validity, interpretation, construction and performance of this Agreement shall be governed by the laws of the State of New Mexico.

(e)Counterparts. This Agreement may be executed in several counterparts, each of which shall be deemed to be an original, but all of which together shall constitute one and the same instrument.

(f)Survival of Terms. The terms and conditions set forth in this Agreement shall survive this Agreement and continue to be binding upon Employee after the expiration or termination of this Agreement, whether by passage of time or otherwise.

(g)Entire Agreement. This Agreement embodies the entire agreement and understanding between the parties hereto with respect to the subject matter hereof and supersedes all prior oral or written agreements and understandings relating to the subject matter hereof. No statement, representation, warranty, covenant or agreement of any kind not expressly set forth in this Agreement shall affect, or be used to interpret, change or restrict, the express terms and provisions of the Agreement.

(h)Interpretative Matters. No provision of this Agreement will be interpreted in favor of, or against, any of the parties hereto by reason of the extent to which any such party or its counsel participated in the drafting thereof or by reason of the extent to which any such provision is inconsistent with any prior draft hereof or thereof.

7.“COMPANY” INCLUDES AFFILIATES. For purposes of this Agreement, the term “Company” shall mean PNM Resources, Inc. and any Affiliate of PNM Resources, Inc. The term “Affiliate” shall be given the meaning ascribed to it in the PNM Resources, Inc. Executive Savings Plan II.

8.IMPACT ON PRIOR AGREEMENT. Employee previously executed a Restrictive Covenant Agreement dated May 15, 2012. This Agreement supplements and does not supersede the terms of the Restrictive Covenant Agreement dated May 15, 2012.

IN WITNESS WHEREOF, the parties have executed and sealed this Supplemental Restrictive Covenant Agreement to be signed by its duly authorized representative and Employee as of the 9^th day of December, 2014.

PNMR SERVICES COMPANY

By /s/ CN Eldred                    

Its: CFO and Executive Vice President

EMPLOYEE

Signature /s/ Tom Sategna                

Thomas G. Sategna                    

Printed Name

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EX-12.1

	Exhibit 12.1
PNM RESOURCES, INC. AND SUBSIDIARIES
Ratio of Earnings to Fixed Charges
(In thousands, except ratio)
		Year Ended December 31,
		2014				2013				2012			2011				2010
	Fixed charges, as defined by the Securities and Exchange Commission:
	Interest expensed and capitalized	$	117,337			$	118,880			$	125,379		$	122,998			$	123,633
	Amortization of debt premium, discount, and expenses	4,194				3,716				4,023			3,695				4,627
	Estimated interest factor of lease rental charges	4,686				5,847				5,585			6,665				6,888
	Preferred dividend requirements of subsidiary	809				800				769			864				1,075
	Total Fixed Charges	$	127,026			$	129,243			$	135,756		$	134,222			$	136,223
	Earnings, as defined by the Securities and Exchange Commission:
	Earnings (loss) from continuing operations before income taxes and non-controlling interest	$	200,647			$	175,069			$	175,035		$	321,469			$	(63,379	)
	(Earnings) loss of equity investee	—				—				—			—				15,223
	Earnings (loss) from continuing operations before income taxes, non-controlling interest, and investee earnings	200,647				175,069				175,035			321,469				(48,156		)
	Fixed charges as above	127,026				129,243				135,756			134,222				136,223
	Interest capitalized	(6,256		)		(5,209		)		(5,432		)	(2,697		)		(3,401		)
	Non-controlling interest in earnings of Valencia	(14,127		)		(14,521		)		(14,050		)	(14,047		)		(13,563		)
	Preferred dividend requirements of subsidiary	(809		)		(800		)		(769		)	(864		)		(1,075		)
	Earnings Available for Fixed Charges	$	306,481			$	283,782			$	290,540		$	438,083			$	70,028
	Ratio of Earnings to Fixed Charges	2.41			1	2.20			1	2.14			3.26			2	0.51			3
	1 Earnings (loss) from continuing operations before income taxes and non-controlling interest for the years ended December 31, 2014 and December 31, 2013 include pre-tax losses of $1.1 million and $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 2.42 for 2014 and 2.29 for 2013.
	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)
	Year Ended December 31,
	2014				2013				2012			2011				2010
Fixed charges, as defined by the Securities and Exchange Commission:
Interest expensed and capitalized	$	79,834			$	79,769			$	82,864		$	75,217			$	73,423
Amortization of debt premium, discount, and expenses	1,944				1,879				1,818			1,325				1,274
Estimated interest factor of lease rental charges	2,541				3,732				3,743			4,139				4,103
Total Fixed Charges	$	84,319			$	85,380			$	88,425		$	80,681			$	78,800
Earnings, as defined by the Securities and Exchange Commission:
Earnings (loss) from continuing operations before income taxes and non-controlling interest	$	154,086			$	151,480			$	156,314		$	105,965			$	107,288
Fixed charges as above	84,319				85,380				88,425			80,681				78,800
Non-controlling interest in earnings of Valencia	(14,127		)		(14,521		)		(14,050		)	(14,047		)		(13,563		)
Interest capitalized	(5,211		)		(4,420		)		(4,314		)	(1,761		)		(2,811		)
Earnings Available for Fixed Charges	$	219,067			$	217,919			$	226,375		$	170,838			$	169,714
Ratio of Earnings to Fixed Charges	2.60			1	2.55			1	2.56			2.12			2	2.15
1 Earnings (loss) from continuing operations before income taxes and non-controlling interest for the years ended December 31, 2104 and December 31, 2013 include pre-tax losses of $1.1 million and $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 2.61 for 2014 and 2.70 for 2013.
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 $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)
	Year Ended December 31,
	2014			2013			2012			2011				2010
Fixed charges, as defined by the Securities and Exchange Commission:
Interest expensed and capitalized	$	24,941		$	24,481		$	26,233		$	27,914			$	28,632
Amortization of debt premium, discount, and expenses	1,195			1,159			1,493			1,679				2,683
Estimated interest factor of lease rental charges	1,311			1,241			956			1,202				1,246
Total Fixed Charges	$	27,447		$	26,881		$	28,682		$	30,795			$	32,561
Earnings, as defined by the Securities and Exchange Commission:
Earnings from continuing operations before income taxes	$	60,330		$	46,711		$	42,099		$	36,138			$	26,026
Fixed charges as above	27,447			26,881			28,682			30,795				32,561
Interest capitalized	(609		)	(361		)	(706		)	(593		)		(158		)
Earnings Available for Fixed Charges	$	87,168		$	73,231		$	70,075		$	66,340			$	58,429
Ratio of Earnings to Fixed Charges	3.18			2.72			2.44			2.15			1	1.79
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-21

EXHIBIT 21

Subsidiaries of PNM Resources, Inc.

As of December 31, 2014, PNM Resources, Inc. directly or indirectly owns all of the voting securities of the following subsidiaries:

Public Service Company of New Mexico, a New Mexico corporation that does business under the names “Public Service Company of New Mexico” and “PNM”.

Texas-New Mexico Power Company, a Texas corporation that does business under the name “Texas-New Mexico Power Company” and “TNMP”.

TNP Enterprises, Inc., a Texas corporation that does business under its corporate name.

The remaining subsidiaries of PNM Resources, Inc. considered in the aggregate as a single subsidiary, do not constitute a "significant subsidiary" (as defined in Rule 1-02(w) of Regulation S-X) as of the end of the year covered by this report.

EX-23.1

Exhibit 23.1

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

The Board of Directors

PNM Resources, Inc:

We consent to the incorporation by reference in the registration statement No. 333-183180 on Form S-3 and registration statement Nos. 333-76288, 333-139108, 333-129454, 333-03289-99, 333-88372, 333-121371, 333-125010, 333-141282, 333-156243, 333-159361, 333-159362, 333-168797 and 333-195974 on Form S-8 of PNM Resources, Inc and subsidiaries of our reports dated February 27, 2015, with respect to the consolidated balance sheets of PNM Resources, Inc and subsidiaries as of December 31, 2014 and 2013, and the related consolidated statements of earnings, consolidated statements of comprehensive income, consolidated statements of changes in equity, and consolidated statements of cash flows for each of the years in the two-year period ended December 31, 2014, and all related financial statement schedules, and the effectiveness of internal control over financial reporting as of December 31, 2014, which reports appear herein.

/s/ KPMG LLP

Albuquerque, New Mexico

February 27, 2015

EX-23.2

Exhibit 23.2

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

The Board of Directors

Public Service Company of New Mexico:

We consent to the incorporation by reference in the registration statement No. 333-195979 on Form S-3 of Public Service Company of New Mexico and subsidiaries of our reports dated February 27, 2015, with respect to the consolidated balance sheets of Public Service Company of New Mexico and subsidiaries as of December 31, 2014 and 2013, and the related consolidated statements of earnings, consolidated statements of comprehensive income, consolidated statements of changes in equity, and consolidated statements of cash flows for each of the years in the two-year period ended December 31, 2014, and the related financial statement schedule, which reports appear herein.

/s/ KPMG LLP

Albuquerque, New Mexico

February 27, 2015

EX-23.3

Exhibit 23.3

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We consent to the incorporation by reference in Registration Statement No. 333-183180 on Form S-3 and Registration Statements Nos. 333-76288, 333-139108, 333-129454, 333-03289-99, 333-88372, 333-121371, 333-125010, 333-141282, 333-156243, 333-159361, 333-159362, 333-168797, and 333-195974 on Form S-8 of our reports dated March 1, 2013, relating to the consolidated financial statements and financial statement schedules of PNM Resources, Inc. and subsidiaries, appearing in this Annual Report on Form 10-K of PNM Resources, Inc. and subsidiaries for the year ended December 31, 2014.

/s/ DELOITTE & TOUCHE LLP

Phoenix, Arizona

February 27, 2015

EX-23.4

Exhibit 23.4

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We consent to the incorporation by reference in Registration Statement No. 333-195979 on Form S-3 of our reports dated March 1, 2013, relating to the consolidated financial statements and financial statement schedule of Public Service Company of New Mexico and subsidiaries appearing in this Annual Report on Form 10-K of Public Service Company of New Mexico and subsidiaries for the year ended December 31, 2014.

/s/ DELOITTE & TOUCHE LLP

Phoenix, Arizona

February 27, 2015

EX-31.1

EXHIBIT 31.1

CERTIFICATION

I, Patricia K. Collawn, certify that:

1. I have reviewed this Annual Report on Form 10-K 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;

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:	February 27, 2015	By:	/s/ Patricia K. Collawn
			Patricia K. Collawn
			President and Chief Executive Officer
			PNM Resources, Inc.

EX-31.2

EXHIBIT 31.2

CERTIFICATION

I, Charles N. Eldred, certify that:

1. I have reviewed this Annual Report on Form 10-K 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;

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;

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:	February 27, 2015	By:	/s/ Charles N. Eldred
			Charles N. Eldred
			Executive Vice President and
			Chief Financial Officer
			PNM Resources, Inc.

EX-31.3

EXHIBIT 31.3

CERTIFICATION

I, Patricia K. Collawn, certify that:

1. I have reviewed this Annual Report on Form 10-K 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;

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:	February 27, 2015	By:	/s/ Patricia K. Collawn
			Patricia K. Collawn
			President and Chief Executive Officer
			Public Service Company of New Mexico

EX-31.4

EXHIBIT 31.4

CERTIFICATION

I, Charles N. Eldred, certify that:

1. I have reviewed this Annual Report on Form 10-K 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;

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:	February 27, 2015	By:	/s/ Charles N. Eldred
			Charles N. Eldred
			Executive Vice President and
			Chief Financial Officer
			Public Service Company of New Mexico

EX-31.5

EXHIBIT 31.5

CERTIFICATION

I, Patricia K. Collawn, certify that:

1. I have reviewed this Annual Report on Form 10-K 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 in order 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 (the 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;

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:	February 27, 2015	By:	/s/ Patricia K. Collawn
			Patricia K. Collawn
			Chief Executive Officer
			Texas-New Mexico Power Company

EX-31.6

EXHIBIT 31.6

CERTIFICATION

I, Thomas G. Sategna, certify that:

1. I have reviewed this Annual Report on Form 10-K 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 in order 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 (the 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;

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:	February 27, 2015	By:	/s/ Thomas G. Sategna
			Thomas G. Sategna
			Vice President and Controller
			Texas-New Mexico Power Company

EX-32.1

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 Annual Report on Form 10-K for the period ended December 31, 2014, for PNM Resources, Inc. (“Company”), as filed with the Securities and Exchange Commission on February 27, 2015 (“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:	February 27, 2015	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
			PNM Resources, Inc.

EX-32.2

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 Annual Report on Form 10-K for the period ended December 31, 2014, for Public Service Company of New Mexico (“Company”), as filed with the Securities and Exchange Commission on February 27, 2015 (“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:	February 27, 2015	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
			Public Service Company of New Mexico

EX-32.3

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 Annual Report on Form 10-K for the period ended December 31, 2014, for Texas-New Mexico Power Company (“Company”), as filed with the Securities and Exchange Commission on February 27, 2015 (“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:	February 27, 2015	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, Controller
			Texas-New Mexico Power Company

XML

Variable Interest Entities (Tables)

12 Months Ended

Dec. 31, 2014

Variable Interest Entities [Abstract]

Noncontrolling Interest Summarized Financial Information

Summarized financial information for Valencia is as follows:

Results of Operations
	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Operating revenues	$	20,247		$	20,166		$	19,585
Operating expenses	(6,120		)	(5,645		)	(5,535		)
Earnings attributable to non-controlling interest	$	14,127		$	14,521		$	14,050

Financial Position
	December 31,
	2014		2013
	(In thousands)
Current assets	$	2,513	$	2,658
Net property, plant and equipment	72,321		75,137
Total assets	74,834		77,795
Current liabilities	1,288		766
Owners’ equity – non-controlling interest	$	73,546	$	77,029

XML

Sale of First Choice (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Gain on sale of First Choice	$ 0	$ 0	$ 1,012
Other Income [Member] | First Choice [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Gain on sale of First Choice			$ 1,000

XML

Quarterly Operating Results (Unaudited) (Tables)

12 Months Ended

Dec. 31, 2014

Quarterly Financial Data [Abstract]

Schedule of Quarterly Financial Information

Unaudited operating results by quarters for 2014 and 2013 are presented below. In the opinion of management of the Company, all adjustments (consisting of normal recurring accruals) necessary for a fair statement of the results of operations for such periods have been included.

	Quarter Ended
	March 31		June 30		September 30		December 31
	(In thousands, except per share amounts)
PNMR
2014
Operating revenues	$	328,897	$	346,160	$	413,951	$	346,845
Operating income	48,753		71,296		116,799		62,849
Net earnings	16,131		33,181		59,486		22,111
Net earnings attributable to PNMR	12,468		29,141		55,653		18,992
Net Earnings Attributable to PNMR per Common Share:
Basic	0.16		0.37		0.70		0.24
Diluted	0.16		0.36		0.69		0.24
2013
Operating revenues	$	317,665	$	347,599	$	399,730	$	322,929
Operating income	50,704		77,867		117,739		40,532
Net earnings	13,962		31,383		58,814		11,397
Net earnings attributable to PNMR	10,626		27,678		54,555		7,648
Net Earnings Attributable to PNMR per Common Share:
Basic	0.13		0.35		0.68		0.10
Diluted	0.13		0.34		0.68		0.10
PNM
2014
Operating revenues	$	262,736	$	275,704	$	334,993	$	274,481
Operating income	31,304		49,806		90,615		40,988
Net earnings	11,205		24,254		49,052		16,942
Net earnings attributable to PNM	7,674		20,346		45,351		13,955
2013
Operating revenues	$	257,894	$	279,690	$	326,026	$	252,702
Operating income	37,239		58,302		95,217		18,427
Net earnings	14,773		29,697		51,950		6,256
Net earnings attributable to PNM	11,569		26,124		47,823		2,639
TNMP
2014
Operating revenues	$	66,161	$	70,456	$	78,958	$	72,364
Operating income	17,262		21,265		25,873		21,188
Net earnings	6,803		9,534		12,355		9,115
2013
Operating revenues	$	59,771	$	67,909	$	73,704	$	70,227
Operating income	13,054		19,667		22,254		17,210
Net earnings	3,726		8,339		10,106		6,919

XML

Fair Value of Derivative and Other Financial Instruments, Recurring (Details) (PNMR and PNM [Member], USD $) In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	$ 250,145	$ 226,855
Measured on a recurring basis [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	250,145	226,855
Measured on a recurring basis [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	169,919	158,180
Measured on a recurring basis [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	80,226	68,675
Cash and equivalents [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	8,276	3,356
Cash and equivalents [Member] | Measured on a recurring basis [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	8,276	3,356
Cash and equivalents [Member] | Measured on a recurring basis [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	8,276	3,356
Cash and equivalents [Member] | Measured on a recurring basis [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	0	0
Domestic value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	45,340	39,460
Domestic value [Member] | Measured on a recurring basis [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	45,340	39,460
Domestic value [Member] | Measured on a recurring basis [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	45,340	39,460
Domestic value [Member] | Measured on a recurring basis [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	0	0
Domestic growth [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	74,053	76,292
Domestic growth [Member] | Measured on a recurring basis [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	74,053	76,292
Domestic growth [Member] | Measured on a recurring basis [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	74,053	76,292
Domestic growth [Member] | Measured on a recurring basis [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	0	0
International and other [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	16,599	16,633
International and other [Member] | Measured on a recurring basis [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	16,599	16,633
International and other [Member] | Measured on a recurring basis [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	16,599	16,633
International and other [Member] | Measured on a recurring basis [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	0	0
U.S. Government [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	22,563	21,941
U.S. Government [Member] | Measured on a recurring basis [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	22,563	21,941
U.S. Government [Member] | Measured on a recurring basis [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	20,808	20,194
U.S. Government [Member] | Measured on a recurring basis [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	1,755	1,747
Municipals [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	68,973	58,568
Municipals [Member] | Measured on a recurring basis [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	68,973	58,568
Municipals [Member] | Measured on a recurring basis [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	0	0
Municipals [Member] | Measured on a recurring basis [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	68,973	58,568
Corporate and other [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	14,341	10,605
Corporate and other [Member] | Measured on a recurring basis [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	14,341	10,605
Corporate and other [Member] | Measured on a recurring basis [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	4,843	2,245
Corporate and other [Member] | Measured on a recurring basis [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities, Fair value	9,498	8,360
Commodity Contract [Member] | Measured on a recurring basis [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity derivative instruments, Assets	11,232	7,066
Commodity derivative instruments, Liabilities	(1,686)	(3,793)
Commodity derivative instruments, Net	9,546	3,273
Commodity Contract [Member] | Measured on a recurring basis [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 derivative instruments, Net	0	0
Commodity Contract [Member] | Measured on a recurring basis [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity derivative instruments, Assets	11,232	7,066
Commodity derivative instruments, Liabilities	(1,686)	(3,793)
Commodity derivative instruments, Net	$ 9,546	$ 3,273

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Regulatory Assets and Liabilities (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Regulatory Assets
Regulatory Assets, Current	$ 47,855	$ 24,416
Regulatory Assets, Noncurrent	491,007	523,955
Regulatory Liabilities
Regulatory Liability, Current	(1,703)	(1,081)
Regulatory liabilities, Noncurrent	(466,143)	(460,649)
Public Service Company of New Mexico [Member]
Regulatory Assets
Regulatory Assets, Current	43,980	19,394
Regulatory Assets, Noncurrent	357,045	384,217
Regulatory Assets	401,025	403,611
Regulatory Liabilities
Regulatory Liability, Current	(1,703)	(1,081)
Regulatory liabilities, Noncurrent	(425,481)	(414,611)
Regulatory Liabilities	(427,184)	(415,692)
Texas-New Mexico Power Company [Member]
Regulatory Assets
Regulatory Assets, Current	3,875	5,022
Regulatory Assets, Noncurrent	133,962	139,738
Regulatory Assets	137,837	144,760
Regulatory Liabilities
Regulatory liabilities, Noncurrent	(40,662)	(46,038)
Removal Costs [Member] | Public Service Company of New Mexico [Member]
Regulatory Liabilities
Regulatory liabilities, Noncurrent	(277,148)	(266,075)
Removal Costs [Member] | Texas-New Mexico Power Company [Member]
Regulatory Liabilities
Regulatory liabilities, Noncurrent	(29,391)	(30,863)
Deferred Income Tax Charge [Member] | Public Service Company of New Mexico [Member]
Regulatory Liabilities
Regulatory liabilities, Noncurrent	(75,941)	(80,495)
Deferred Income Tax Charge [Member] | Texas-New Mexico Power Company [Member]
Regulatory Liabilities
Regulatory liabilities, Noncurrent	(3,923)	(4,563)
Asset Retirement Obligation Costs [Member] | Public Service Company of New Mexico [Member]
Regulatory Liabilities
Regulatory liabilities, Noncurrent	(35,834)	(37,567)
Renewable Energy Program [Member] | Public Service Company of New Mexico [Member]
Regulatory Liabilities
Regulatory liabilities, Noncurrent	(24,854)	(26,011)
Other Regulatory Assets (Liabilities) [Member] | Public Service Company of New Mexico [Member]
Regulatory Liabilities
Regulatory liabilities, Noncurrent	(11,704)	(4,463)
Other Regulatory Assets (Liabilities) [Member] | Texas-New Mexico Power Company [Member]
Regulatory Liabilities
Regulatory liabilities, Noncurrent	(2,121)	(3,361)
Advanced Metering Infrastructure Costs [Member] | Texas-New Mexico Power Company [Member]
Regulatory Liabilities
Regulatory liabilities, Noncurrent	(5,227)	(7,251)
Regulatory Assets, Transmission Cost Recovery [Member] | Texas-New Mexico Power Company [Member]
Regulatory Assets
Regulatory Assets, Current	2,482	4,250
Other Regulatory Assets (Liabilities) [Member] | Public Service Company of New Mexico [Member]
Regulatory Assets
Regulatory Assets, Noncurrent	5,929	9,345
Other Regulatory Assets (Liabilities) [Member] | Texas-New Mexico Power Company [Member]
Regulatory Assets
Regulatory Assets, Current	1,393	772
Regulatory Assets, Noncurrent	1,155	1,627
Stranded costs [Member] | Texas-New Mexico Power Company [Member]
Regulatory Assets
Regulatory Assets, Noncurrent	55,292	63,606
Environmental Restoration Costs [Member] | Public Service Company of New Mexico [Member]
Regulatory Assets
Regulatory Assets, Noncurrent	34,224	40,144
Deferred Income Tax Charge [Member] | Public Service Company of New Mexico [Member]
Regulatory Assets
Regulatory Assets, Noncurrent	63,645	61,850
Deferred Income Tax Charge [Member] | Texas-New Mexico Power Company [Member]
Regulatory Assets
Regulatory Assets, Noncurrent	10,556	10,868
Loss on reacquired debt [Member] | Public Service Company of New Mexico [Member]
Regulatory Assets
Regulatory Assets, Noncurrent	25,439	27,490
Loss on reacquired debt [Member] | Texas-New Mexico Power Company [Member]
Regulatory Assets
Regulatory Assets, Noncurrent	36,703	38,616
Pension and Other Postretirement Plans Costs [Member] | Public Service Company of New Mexico [Member]
Regulatory Assets
Regulatory Assets, Noncurrent	222,545	206,691
Pension and Other Postretirement Plans Costs [Member] | Texas-New Mexico Power Company [Member]
Regulatory Assets
Regulatory Assets, Noncurrent	23,803	19,938
Fuel and purchased power adjustment clause [Member] | Public Service Company of New Mexico [Member]
Regulatory Assets
Regulatory Assets, Noncurrent	0	25,386
Renewable Energy Program [Member] | Public Service Company of New Mexico [Member]
Regulatory Assets
Regulatory Assets, Noncurrent	5,263	13,311
Advanced Metering Infrastructure Costs [Member] | Texas-New Mexico Power Company [Member]
Regulatory Assets
Regulatory Assets, Noncurrent	$ 6,453	$ 5,083

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Income Taxes Summary of Income Tax Contingencies (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Unrecognized Tax Benefits - Beginning	$ 19,889,000	$ 19,198,000	$ 19,580,000
Additions based on tax positions	623,000	(54,000)	2,046,000
Additions (reductions) for tax positions of prior years	(5,481,000)		(2,428,000)
Additions for tax positions of prior years		745,000
Settlement payments	0	0	0
Unrecognized Tax Benefits - End	15,031,000	19,889,000	19,198,000
Public Service Company of New Mexico [Member]
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Unrecognized Tax Benefits - Beginning	11,073,000	10,382,000	10,752,000
Additions based on tax positions	623,000	(54,000)	1,152,000
Additions (reductions) for tax positions of prior years			(1,522,000)
Additions for tax positions of prior years	532,000	745,000
Settlement payments	0	0	0
Unrecognized Tax Benefits - End	12,228,000	11,073,000	10,382,000
Unrecognized tax benefits that would impact effective tax rate	1,900,000
Texas-New Mexico Power Company [Member]
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Unrecognized Tax Benefits - Beginning	6,796,000	6,796,000	7,701,000
Additions based on tax positions	0	0	0
Additions (reductions) for tax positions of prior years	(6,796,000)		(905,000)
Additions for tax positions of prior years		0
Settlement payments	0	0	0
Unrecognized Tax Benefits - End	0	6,796,000	6,796,000
PNMR [Member]
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Unrecognized tax benefits that would impact effective tax rate	$ 4,700,000

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Schedule I - Condensed Financial Information of Parent Company (Balance Sheets) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Assets
Cash and cash equivalents	$ 28,274	$ 2,533	$ 8,985	$ 15,091
Income taxes receivable	6,360	7,066
Other, net	58,471	34,590
Total current assets	432,817	401,539
Property, plant and equipment, net of accumulated depreciation of $10,251 and $9,167	4,270,006	3,933,911
Other long-term assets	1,762	1,835
Total Assets	5,829,325	5,500,210	5,372,583
Liabilities and Stockholders’ Equity
Short-term debt	105,600	149,200
Current maturities of long-term debt	333,066	75,000
Accrued interest and taxes	53,863	49,600
Other current liabilities	70,194	77,105
Total current liabilities	704,282	492,671
Long-term Debt	1,642,024	1,670,420
Total liabilities	4,022,704	3,738,083
Common stock (no par value; 120,000,000 shares authorized; issued and outstanding 79,653,624 shares)	1,173,845	1,178,369
Accumulated other comprehensive income (loss), net of tax	(61,755)	(58,140)	(81,630)	(66,856)
Retained earnings	609,456	553,340
Total PNMR common stockholders’ equity	1,721,546	1,673,569
Total liabilities and stockholders' equity	5,829,325	5,500,210
PNM Resources [Member]
Assets
Cash and cash equivalents	382	92	29	241
Intercompany receivables	107,619	136,387
Income taxes receivable	29	14,989
Other, net	8,115	8,544
Total current assets	116,145	160,012
Property, plant and equipment, net of accumulated depreciation of $10,251 and $9,167	27,076	26,601
Investment in subsidiaries	1,757,650	1,683,321
Other long-term assets	70,939	53,892
Total long-term assets	1,855,665	1,763,814
Total Assets	1,971,810	1,923,826
Liabilities and Stockholders’ Equity
Short-term debt	100,600	100,000
Short-term debt-affiliate	8,819	8,819
Current maturities of long-term debt	118,766	0
Accrued interest and taxes	2,816	2,797
Other current liabilities	16,320	16,876
Total current liabilities	247,321	128,492
Long-term Debt	0	118,766
Other long-term liabilities	2,943	2,999
Total liabilities	250,264	250,257
Common stock (no par value; 120,000,000 shares authorized; issued and outstanding 79,653,624 shares)	1,173,845	1,178,369
Accumulated other comprehensive income (loss), net of tax	(61,755)	(58,140)
Retained earnings	609,456	553,340
Total PNMR common stockholders’ equity	1,721,546	1,673,569
Total liabilities and stockholders' equity	$ 1,971,810	$ 1,923,826

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Related Party Transactions (Tables)

12 Months Ended

Dec. 31, 2014

Related Party Transactions [Abstract]

Schedule of Related Party Transactions

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

	Year Ended December 31,
	2014		2013		2012
			(In thousands)
Services billings:
PNMR to PNM	$	86,871	$	92,597	$	99,986
PNMR to TNMP	28,349		28,937		29,110
PNM to TNMP	524		562		595
TNMP to PNMR	31		7		15
Income tax sharing payments:
PNMR to TNMP	—		—		1,951
PNMR to PNM	—		77,433		63,114
TNMP to PNMR	—		3,643		—
Interest payments:
PNM to PNMR	65		4		1
TNMP to PNMR	309		481		137

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Summary of the Business and Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2014

Accounting Policies [Abstract]

Schedule of Inventory, Current

Inventories consisted of the following at December 31:

	PNMR				PNM				TNMP
	2014		2013		2014		2013		2014		2013
	(In thousands)
Coal	$	17,525	$	24,872	$	17,525	$	24,872	$	—	$	—
Materials and supplies	46,103		42,351		43,334		39,648		2,769		2,703
	$	63,628	$	67,223	$	60,859	$	64,520	$	2,769	$	2,703

Schedule of Average Rates Used Allocated Between Depreciation Expense and Construction Expense Projects Based on Use of Equipment

Average straight-line rates used were as follows:

	Year ended December 31
	2014		2013		2012
PNM
Electric plant	2.26	%	2.27	%	2.25	%
Common, intangible, and general plant	4.64	%	4.87	%	5.35	%
TNMP	3.59	%	3.66	%	3.56	%

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Income Taxes Interest Expense (Income) Related to Income Taxes (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Taxes [Line Items]
Interest income related to income taxes	$ 146	$ 242	$ 243
Public Service Company of New Mexico [Member]
Income Taxes [Line Items]
Interest income related to income taxes	148	251	244
Texas-New Mexico Power Company [Member]
Income Taxes [Line Items]
Interest income related to income taxes	$ (2)	$ (2)	$ (3)

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Earnings and Dividends Per Share (Details) (USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Earnings Per Share [Abstract]
Earnings Attributable to PNMR	$ 18,992	$ 55,653	$ 29,141	$ 12,468	$ 7,648	$ 54,555	$ 27,678	$ 10,626	$ 116,254		$ 100,507		$ 105,547
Average Number of Common Shares:
Outstanding during year									79,654,000		79,654,000		79,654,000
Vested awards of restricted stock									134,000		191,000		145,000
Average Shares – Basic									79,788,000		79,845,000		79,799,000
Dilutive Effect of Common Stock Equivalents:
Stock options and restricted stock									491,000	[1]	586,000	[1]	618,000	[1]
Average Shares – Diluted									80,279,000	[1]	80,431,000	[1]	80,417,000	[1]
Net Earnings Per Share of Common Stock:
Basic (dollars per share)	$ 0.24	$ 0.70	$ 0.37	$ 0.16	$ 0.10	$ 0.68	$ 0.35	$ 0.13	$ 1.46		$ 1.26		$ 1.32
Diluted (dollars per share)	$ 0.24	$ 0.69	$ 0.36	$ 0.16	$ 0.10	$ 0.68	$ 0.34	$ 0.13	$ 1.45		$ 1.25		$ 1.31
Common Stock, Dividends, Per Share, Declared									$ 0.755		$ 0.68		$ 0.58
Share Based Compensation Arrangement by Share Based Payment Award Options Outstanding Shares Above Entities Stock Price (in shares)									254,050

[1] Excludes out-of-the-money options for 254,050 shares of common stock at December 31, 2014. See Note 13.

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Pension and Other Postretirement Benefits Other Postretirement Benefits (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Other Retirement Plans, 401 (k) plan [Member]
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]
Expenses recognized	$ 16,703	$ 16,785	$ 16,185
Other Retirement Plans, 401 (k) plan [Member] | Public Service Company of New Mexico [Member]
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]
Expenses recognized	12,745	12,952	12,427
Other Retirement Plans, 401 (k) plan [Member] | Texas-New Mexico Power Company [Member]
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]
Expenses recognized	3,958	3,953	3,739
Other Retirement Plans, Key Employees, Non-qualified Plan [Member]
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]
Compensation expense	2,257	2,204	1,491
Other Retirement Plans, Key Employees, Non-qualified Plan [Member] | Public Service Company of New Mexico [Member]
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]
Compensation expense	1,722	1,691	1,143
Other Retirement Plans, Key Employees, Non-qualified Plan [Member] | Texas-New Mexico Power Company [Member]
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]
Compensation expense	$ 535	$ 513	$ 327

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Financing (Details) (USD $)	12 Months Ended			0 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Apr. 03, 2013	Sep. 30, 2011	Dec. 27, 2012	Apr. 22, 2013	Mar. 05, 2014	Dec. 22, 2014	Mar. 06, 2013	Dec. 14, 2012	Sep. 30, 2012	Dec. 09, 2013	Feb. 20, 2015
Debt Instrument [Line Items]
Repayments of Unsecured Debt		$ 26,900,000
Loss on reacquired debt	0	3,253,000	0
Short-term debt	105,600,000	149,200,000
Proceeds from Short-term Debt			100,000,000
Long-term Debt	1,975,090,000	1,745,420,000
Unsecured Debt [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		9.25%
Public Service Company of New Mexico [Member]
Debt Instrument [Line Items]
Long-term Debt	1,490,657,000	1,290,618,000
Short-term debt - affiliate	0	32,500,000
Public Service Company of New Mexico [Member] | Unsecured Debt [Member]
Debt Instrument [Line Items]
Debt Instrument, Shelf Registration Statement for Unsecured Debt	500,000,000
Public Service Company of New Mexico [Member] | PNM 2014 Term Loan Agreement [Member]
Debt Instrument [Line Items]
Long-term Debt								175,000,000
Debt Instrument, Interest Rate, Effective Percentage	1.11%
Public Service Company of New Mexico [Member] | PNM 2014 Multi-Draw Term Loan Agreement [Member]
Debt Instrument [Line Items]
Long-term Debt									125,000,000
Debt Instrument, Interest Rate, Effective Percentage	0.75%
Proceeds from (Repayments of) Debt	100,000,000
Debt Instrument, Unused Borrowing Capacity, Amount	25,000,000
Texas-New Mexico Power Company [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount										1,000
Long-term Debt	365,667,000	336,036,000
Debt Instrument, Cash Offered for Debt Exchanged										140
Repayments of Debt	30,000,000
Short-term debt - affiliate	22,700,000	29,400,000
Texas-New Mexico Power Company [Member] | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Debt Instrument, Cash Paid for Debt Exchanged				13,000,000
Texas-New Mexico Power Company [Member] | 2011 Term Loan Agreement [Member]
Debt Instrument [Line Items]
Proceeds from Bank Debt					50,000,000
Repayments of Debt	50,000,000
Senior unsecured notes, 9.25% due 2015 [Member] | Senior unsecured notes, 9.25% due 2015 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		23,800,000
PNMR Term Loan Agreement [Member]
Debt Instrument [Line Items]
Short-term debt	100,000,000	100,000,000
PNMR Term Loan Agreement [Member] | Notes Payable to Banks [Member]
Debt Instrument [Line Items]
Short-term debt											100,000,000
Proceeds from Short-term Debt						100,000,000
Repayments of Lines of Credit						100,000,000
2.54% Maturing of September First, 2042 with a Mandatory Tender on June First, 2017 [Member] | Public Service Company of New Mexico [Member] | Pollution Control Revenue Bonds [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount												20,000,000
Debt Instrument, Interest Rate, Stated Percentage												2.54%
5.15% Percent Maturing in 2037 [Member] | Public Service Company of New Mexico [Member] | Pollution Control Revenue Bonds [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage												5.15%
Debt Instrument, Refunded Amount Redeemed at Par and Retired												20,000,000
PNM Term Loan Agreement [Member] | Notes Payable to Banks [Member]
Debt Instrument [Line Items]
Short-term debt							75,000,000
Repayments of Lines of Credit							75,000,000
First Mortgage Bonds Due 2014, Series 2009A, at 9 point 50 percent [Member] | Texas-New Mexico Power Company [Member] | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount										265,500,000
Debt Instrument, Interest Rate, Stated Percentage	9.50%	9.50%		9.50%						9.50%
First Mortgage Bonds 6 Point 95 Percent, due 2043, Series 2013A [Member] | Texas-New Mexico Power Company [Member] | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount				93,200,000
Debt Instrument, Interest Rate, Stated Percentage	6.95%	6.95%		6.95%						6.95%
Debt Instrument, Unamortized Premium				23,200,000
First Mortgage Bonds Due 2024, Series 2014A, at 4 point 03 percent [Member] [Member] | Texas-New Mexico Power Company [Member] | Pollution Control Revenue Bonds [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount													80,000,000
Debt Instrument, Interest Rate, Stated Percentage													4.03%
First Mortgage Bonds Due 2024, Series 2014A, at 4 point 03 percent [Member] [Member] | Texas-New Mexico Power Company [Member] | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.03%
Borrowings from PNMR [Member] | Public Service Company of New Mexico [Member]
Debt Instrument [Line Items]
Short-term debt - affiliate														0
Borrowings from PNMR [Member] | Texas-New Mexico Power Company [Member]
Debt Instrument [Line Items]
Short-term debt - affiliate														17,300,000
Subsequent Event [Member] | Public Service Company of New Mexico [Member] | PNM 2014 Multi-Draw Term Loan Agreement [Member]
Debt Instrument [Line Items]
Debt Instrument, Unused Borrowing Capacity, Amount														25,000,000
Maximum [Member]
Debt Instrument [Line Items]
Short-term debt - affiliate	100,000,000
Fair Value, Inputs, Level 2 [Member] | Cash Flow Hedging [Member] | Texas-New Mexico Power Company [Member] | 2011 Term Loan Agreement [Member]
Debt Instrument [Line Items]
Interest Rate Derivative Liabilities, at Fair Value		$ 200,000

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Income Taxes Schedule of Deferred Tax Assets and Liabilities (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Deferred tax assets:
Net operating loss	$ 153,858	$ 134,418
Regulatory liabilities related to income taxes	78,858	83,838
Deferred Tax Assets, Tax Credit Carryforwards	54,748	40,708
Other	68,566	75,832
Total deferred tax assets	356,030	334,796
Deferred tax liabilities:
Depreciation and plant related	(914,926)	(814,671)
Investment tax credit	(36,790)	(25,855)
Regulatory assets related to income taxes	(67,910)	(66,352)
Stranded costs	(19,352)	(22,262)
Pension	(66,498)	(58,780)
Other	(115,282)	(115,458)
Total deferred tax liabilities	(1,220,758)	(1,103,378)
Current accumulated deferred income tax (asset) liability	(864,728)	(768,582)
Deferred Tax Assets (Liabilities), Net [Abstract]
Current accumulated deferred income tax (asset) liability	(26,383)	(58,681)
Non-current accumulated deferred income tax liability	(891,111)	(827,263)
Public Service Company of New Mexico [Member]
Deferred tax assets:
Net operating loss	108,505	99,247
Regulatory liabilities related to income taxes	74,293	78,849
Deferred Tax Assets, Tax Credit Carryforwards	35,259	22,509
Other	35,681	37,008
Total deferred tax assets	253,738	237,613
Deferred tax liabilities:
Depreciation and plant related	(733,519)	(661,239)
Investment tax credit	(36,790)	(25,855)
Regulatory assets related to income taxes	(57,637)	(55,844)
Pension	(58,474)	(52,104)
Other	(70,714)	(75,838)
Total deferred tax liabilities	(957,134)	(870,880)
Current accumulated deferred income tax (asset) liability	(703,396)	(633,267)
Deferred Tax Assets (Liabilities), Net [Abstract]
Current accumulated deferred income tax (asset) liability	(12,418)	(43,827)
Non-current accumulated deferred income tax liability	(715,814)	(677,094)
Texas-New Mexico Power Company [Member]
Deferred tax assets:
Regulatory liabilities related to income taxes	4,565	4,988
Other	13,429	23,479
Total deferred tax assets	17,994	28,467
Deferred tax liabilities:
Depreciation and plant related	(174,510)	(151,581)
Regulatory assets related to income taxes	(10,197)	(10,509)
Loss on reacquired debt	(12,846)	(13,516)
Stranded costs	(19,352)	(22,262)
Other	(12,636)	(14,295)
Total deferred tax liabilities	(229,541)	(212,163)
Current accumulated deferred income tax (asset) liability	(211,547)	(183,696)
Deferred Tax Assets (Liabilities), Net [Abstract]
Current accumulated deferred income tax (asset) liability	(6,398)	(6,501)
Non-current accumulated deferred income tax liability	$ (217,945)	$ (190,197)

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Pension and Other Postretirement Benefits Assumptions Used (Details)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	4.00%
Public Service Company of New Mexico [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate for determining December 31	4.48%	5.27%	4.30%
Discount rate for determining net periodic benefit cost (income)	5.27%	4.30%	5.67%
Expected return on plan assets	7.20%	7.65%	8.25%
Public Service Company of New Mexico [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate for determining December 31	4.45%	5.21%	4.26%
Discount rate for determining net periodic benefit cost (income)	5.21%	4.26%	5.70%
Expected return on plan assets	8.50%	8.50%	8.50%
Public Service Company of New Mexico [Member] | Executive Retirement Program [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate for determining December 31	4.48%	5.27%	4.30%
Discount rate for determining net periodic benefit cost (income)	5.27%	4.30%	5.67%
Texas-New Mexico Power Company [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate for determining December 31	4.39%	5.06%	4.19%
Discount rate for determining net periodic benefit cost (income)	5.06%	4.19%	5.69%
Expected return on plan assets	7.20%	7.65%	8.25%
Texas-New Mexico Power Company [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate for determining December 31	4.45%	5.21%	4.26%
Discount rate for determining net periodic benefit cost (income)	5.21%	4.26%	5.70%
Expected return on plan assets	6.50%	6.50%	6.50%
Texas-New Mexico Power Company [Member] | Executive Retirement Program [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate for determining December 31	4.39%	5.06%	4.19%
Discount rate for determining net periodic benefit cost (income)	5.06%	4.19%	5.69%

XML

Income Taxes Carryforwards (Details) (USD $)	1 Months Ended	12 Months Ended
	May 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Operating Loss Carryforwards [Line Items]
Additional Income Tax Expense, Impairment of NM Wind Credits			$ 2,400,000	$ 700,000
Deferred Tax Assets, Operating Loss Carryforwards, State and Local, Decrease			1,500,000
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			23,900,000
Increase in income tax expense due to change in state corporate tax rate			1,200,000
Decrease in regulatory liabilities due to change in state corporate tax rate		(4,600,000)
Decrease in deferred tax asset due to change in state corporate tax rate		200,000
Investment tax credit, Impairment		900,000
State Net Operating Loss Carryforward, Impairment		3,100,000
Deferred Tax Assets, Valuation Allowance		5,500,000
Valuation Allowance, Deferred Tax Asset, Increase (Decrease), Amount		900,000	3,900,000	700,000
Federal Tax Refund	96,200,000
New Accounting Pronouncements Not Yet Adopted, Effect on Deferred Tax Asset			19,900,000
Income Taxes		69,738,000	59,513,000	54,910,000
Internal Revenue Service (IRS) [Member]
Operating Loss Carryforwards [Line Items]
Federal Net Operating Loss Carryforwards to Expire in 2030		405,700,000
Federal Tax Credit Carryforwards that Expire Beginning in 2023		54,700,000
Internal Revenue Service (IRS) [Member]
Operating Loss Carryforwards [Line Items]
Income Taxes		(1,300,000)
Public Service Company of New Mexico [Member]
Operating Loss Carryforwards [Line Items]
Increase in deferred tax asset not related to regulatory activity, as a result of tax rate change		100,000
Decrease in income tax expense due to tax rate change		300,000
State Net Operating Loss Carryforward, Impairment		1,000,000
Federal Tax Refund	77,400,000
New Accounting Pronouncements Not Yet Adopted, Effect on Deferred Tax Asset			11,200,000
Income Taxes		52,633,000	48,804,000	50,713,000
Public Service Company of New Mexico [Member] | Internal Revenue Service (IRS) [Member]
Operating Loss Carryforwards [Line Items]
Income Taxes		1,100,000
PNM and TNMP [Domain]
Operating Loss Carryforwards [Line Items]
Deferred Tax Assets, Valuation Allowance		0
Other Subsidiaries [Member]
Operating Loss Carryforwards [Line Items]
State Net Operating Loss Carryforward, Impairment		2,100,000
Texas-New Mexico Power Company [Member]
Operating Loss Carryforwards [Line Items]
New Accounting Pronouncements Not Yet Adopted, Effect on Deferred Tax Asset			6,800,000
Income Taxes		22,523,000	17,621,000	15,352,000
PNM Resources [Member]
Operating Loss Carryforwards [Line Items]
Income Taxes		(5,389,000)	(6,870,000)	(11,168,000)
PNM Resources [Member] | Internal Revenue Service (IRS) [Member]
Operating Loss Carryforwards [Line Items]
Income Tax Examination, Liability (Refund) Adjustment from Settlement with Taxing Authority		(2,000,000)
Income Taxes		$ (200,000)

XML

Pension and Other Postretirement Benefits Pension Benefit Payments are Expected to be Paid (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2014
Public Service Company of New Mexico [Member] | Pension Plan [Member]
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]
2015	$ 53,472
2016	53,468
2017	51,241
2018	49,640
2019	48,560
Years 2019 - 2023	213,759
Public Service Company of New Mexico [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]
2015	6,560
2016	6,635
2017	6,718
2018	6,875
2019	6,950
Years 2019 - 2023	34,585
Public Service Company of New Mexico [Member] | Executive Retirement Program [Member]
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]
2015	1,528
2016	1,510
2017	1,490
2018	1,468
2019	1,445
Years 2019 - 2023	6,722
Texas-New Mexico Power Company [Member] | Pension Plan [Member]
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]
2015	5,997
2016	5,667
2017	5,351
2018	5,585
2019	5,188
Years 2019 - 2023	23,600
Texas-New Mexico Power Company [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]
2015	801
2016	822
2017	838
2018	860
2019	882
Years 2019 - 2023	4,717
Texas-New Mexico Power Company [Member] | Executive Retirement Program [Member]
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]
2015	93
2016	92
2017	91
2018	89
2019	86
Years 2019 - 2023	$ 384

XML

Income Taxes Schedule of Deferred Income Tax Components (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Taxes [Line Items]
Net change in deferred income tax liability per above table	$ 96,146
Change in tax effects of income tax related regulatory assets and liabilities	(6,538)
Tax effect of mark-to-market adjustments	(1,612)
Tax effect of excess pension liability	3,993
Reclassification of unrecognized tax benefits	(4,858)
Unrecognized Tax Benefits	15,031
Other	381
Deferred income taxes	72,481	60,430	56,243
Public Service Company of New Mexico [Member]
Income Taxes [Line Items]
Net change in deferred income tax liability per above table	70,129
Change in tax effects of income tax related regulatory assets and liabilities	(6,349)
Tax effect of mark-to-market adjustments	(1,470)
Tax effect of excess pension liability	3,993
Reclassification of unrecognized tax benefits	1,155
Unrecognized Tax Benefits	12,228
Other	557
Deferred income taxes	55,787
Texas-New Mexico Power Company [Member]
Income Taxes [Line Items]
Net change in deferred income tax liability per above table	27,851
Change in tax effects of income tax related regulatory assets and liabilities	(111)
Reclassification of unrecognized tax benefits	(6,796)
Other	(395)
Deferred income taxes	$ 20,549

XML

Fair Value of Derivative and Other Financial Instruments, Defined Benefit Plans Disclosure (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Long-term debt	$ 2,173,117	$ 1,905,230
Investment in PVNGS lessor notes	32,836	57,279
Other investments	2,375	3,196
Fair value of plan assets at end of year	657,319	623,543
Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Long-term debt	1,624,222	1,382,938
Investment in PVNGS lessor notes	32,836	57,279
Other investments	397	445
Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Long-term debt	427,356	390,814
Other investments	242	245
Cash and Cash Equivalents [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	15,645	16,281
Equity Securities, International Funds [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	23,282	24,471
Equity Securities, Domestic Value [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	41,778	41,451
Equity Securities, Domestic Growth [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	28,370	36,805
Equity Securities, Other Funds [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	29,719	22,522
Fixed Income Securities, Corporate [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	242,742	202,897
Fixed Income Securities, U.S. Government [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	106,634	99,748
Fixed Income Securities, Municipals [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	20,156	17,259
Fixed Income Securities, Other Funds [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	74,136	66,286
Private Equity Funds [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	37,220	39,122
Hedge Funds [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	23,876	34,912
Real Estate [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	13,761	21,789
Fair Value, Inputs, Level 1 [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Long-term debt	0	0
Investment in PVNGS lessor notes	0	0
Other investments	639	690
Fair value of plan assets at end of year	138,491	164,021
Fair Value, Inputs, Level 1 [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Long-term debt	0	0
Investment in PVNGS lessor notes	0	0
Other investments	397	445
Fair Value, Inputs, Level 1 [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Long-term debt	0	0
Other investments	242	245
Fair Value, Inputs, Level 1 [Member] | Cash and Cash Equivalents [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	15,645	16,281
Fair Value, Inputs, Level 1 [Member] | Equity Securities, International Funds [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	24,471
Fair Value, Inputs, Level 1 [Member] | Equity Securities, Domestic Value [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	41,778	41,451
Fair Value, Inputs, Level 1 [Member] | Equity Securities, Domestic Growth [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	28,370	36,805
Fair Value, Inputs, Level 1 [Member] | Equity Securities, Other Funds [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Fair Value, Inputs, Level 1 [Member] | Fixed Income Securities, Corporate [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	363
Fair Value, Inputs, Level 1 [Member] | Fixed Income Securities, U.S. Government [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	52,537	44,541
Fair Value, Inputs, Level 1 [Member] | Fixed Income Securities, Municipals [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Fair Value, Inputs, Level 1 [Member] | Fixed Income Securities, Other Funds [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	161	109
Fair Value, Inputs, Level 1 [Member] | Private Equity Funds [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Fair Value, Inputs, Level 1 [Member] | Hedge Funds [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Fair Value, Inputs, Level 1 [Member] | Real Estate [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Fair Value, Inputs, Level 2 [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Long-term debt	2,173,117	1,905,230
Investment in PVNGS lessor notes	0	0
Other investments	0	0
Fair value of plan assets at end of year	443,244	363,523
Fair Value, Inputs, Level 2 [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Long-term debt	1,624,222	1,382,938
Investment in PVNGS lessor notes	0	0
Other investments	0	0
Fair Value, Inputs, Level 2 [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Long-term debt	427,356	390,814
Other investments	0	0
Fair Value, Inputs, Level 2 [Member] | Cash and Cash Equivalents [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Fair Value, Inputs, Level 2 [Member] | Equity Securities, International Funds [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	23,282	0
Fair Value, Inputs, Level 2 [Member] | Equity Securities, Domestic Value [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Fair Value, Inputs, Level 2 [Member] | Equity Securities, Domestic Growth [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Fair Value, Inputs, Level 2 [Member] | Equity Securities, Other Funds [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	29,719	22,522
Fair Value, Inputs, Level 2 [Member] | Fixed Income Securities, Corporate [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	242,015	202,358
Fair Value, Inputs, Level 2 [Member] | Fixed Income Securities, U.S. Government [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	54,097	55,207
Fair Value, Inputs, Level 2 [Member] | Fixed Income Securities, Municipals [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	20,156	17,259
Fair Value, Inputs, Level 2 [Member] | Fixed Income Securities, Other Funds [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	73,975	66,177
Fair Value, Inputs, Level 2 [Member] | Private Equity Funds [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Fair Value, Inputs, Level 2 [Member] | Hedge Funds [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Fair Value, Inputs, Level 2 [Member] | Real Estate [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Fair Value, Inputs, Level 3 [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Long-term debt	0	0
Investment in PVNGS lessor notes	32,836	57,279
Other investments	1,736	2,506
Fair value of plan assets at end of year	75,584	95,999
Fair Value, Inputs, Level 3 [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Long-term debt	0	0
Investment in PVNGS lessor notes	32,836	57,279
Other investments	0	0
Fair Value, Inputs, Level 3 [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Long-term debt	0	0
Other investments	0	0
Fair Value, Inputs, Level 3 [Member] | PNMR Master Trust [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	75,584	95,999
Fair Value, Inputs, Level 3 [Member] | PNMR Master Trust [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at beginning of year	80,991	79,017
Actual return on assets sold during the period	10,376	3,303
Actual return on assets still held at period end	(5,731)	3,361
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Purchases	8,832	15,110
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales	(28,843)	(19,800)
Fair value of plan assets at end of year	65,625	80,991
Fair Value, Inputs, Level 3 [Member] | PNMR Master Trust [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at beginning of year	15,008	14,171
Actual return on assets sold during the period	3,409	1,400
Actual return on assets still held at period end	(1,883)	1,425
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Purchases	2,902	6,408
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales	(9,477)	(8,396)
Fair value of plan assets at end of year	9,959	15,008
Fair Value, Inputs, Level 3 [Member] | Cash and Cash Equivalents [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Fair Value, Inputs, Level 3 [Member] | Equity Securities, International Funds [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Fair Value, Inputs, Level 3 [Member] | Equity Securities, Domestic Value [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Fair Value, Inputs, Level 3 [Member] | Equity Securities, Domestic Growth [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Fair Value, Inputs, Level 3 [Member] | Equity Securities, Other Funds [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Fair Value, Inputs, Level 3 [Member] | Fixed Income Securities, Corporate [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at beginning of year	176	0
Actual return on assets sold during the period	0	1
Actual return on assets still held at period end	(20)	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Purchases	608	175
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales	(37)	0
Fair value of plan assets at end of year	727	176
Fair Value, Inputs, Level 3 [Member] | Fixed Income Securities, U.S. Government [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Fair Value, Inputs, Level 3 [Member] | Fixed Income Securities, Municipals [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Fair Value, Inputs, Level 3 [Member] | Fixed Income Securities, Other Funds [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Fair Value, Inputs, Level 3 [Member] | Private Equity Funds [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at beginning of year	39,122	38,212
Actual return on assets sold during the period	5,355	4,677
Actual return on assets still held at period end	(296)	1,162
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Purchases	3,656	3,117
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales	(10,617)	(8,046)
Fair value of plan assets at end of year	37,220	39,122
Fair Value, Inputs, Level 3 [Member] | Hedge Funds [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at beginning of year	34,912	31,277
Actual return on assets sold during the period	8,667	135
Actual return on assets still held at period end	(7,536)	3,500
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Purchases	5,500	16,151
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales	(17,667)	(16,151)
Fair value of plan assets at end of year	23,876	34,912
Fair Value, Inputs, Level 3 [Member] | Real Estate [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at beginning of year	21,789	23,699
Actual return on assets sold during the period	(236)	(109)
Actual return on assets still held at period end	237	123
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Purchases	1,971	2,076
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales	(10,000)	(4,000)
Fair value of plan assets at end of year	13,761	21,789
Fair Value, Inputs, Level 3 [Member] | Private Equity, Hedge and Real Estate Funds [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at beginning of year	95,999	93,188
Actual return on assets sold during the period	13,786	4,704
Actual return on assets still held at period end	(7,615)	4,785
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Purchases	11,735	21,519
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales	(38,321)	(28,197)
Fair value of plan assets at end of year	75,584	95,999
Pension Plan [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at beginning of year			518,095
Fair value of plan assets at end of year	587,909	556,353	518,095
Pension Plan [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at beginning of year			66,540
Fair value of plan assets at end of year	69,177	66,118	66,540
Pension Plan [Member] | PNMR Master Trust [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	588,112	557,258
Pension Plan [Member] | PNMR Master Trust [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	69,207	66,285
Pension Plan [Member] | Fair Value, Inputs, Level 1 [Member] | PNMR Master Trust [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	123,668	145,364
Pension Plan [Member] | Fair Value, Inputs, Level 1 [Member] | PNMR Master Trust [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	14,823	18,657
Pension Plan [Member] | Fair Value, Inputs, Level 2 [Member] | PNMR Master Trust [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	398,819	330,903
Pension Plan [Member] | Fair Value, Inputs, Level 2 [Member] | PNMR Master Trust [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	44,425	32,620
Pension Plan [Member] | Fair Value, Inputs, Level 3 [Member] | PNMR Master Trust [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	65,625	80,991
Pension Plan [Member] | Fair Value, Inputs, Level 3 [Member] | PNMR Master Trust [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	9,959	15,008
Other Postretirement Benefits [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Total Assets Owned At the End of Period	79,018	74,133
Fair value of plan assets at beginning of year			64,464
Fair value of plan assets at end of year	78,175	73,565	64,464
Other Postretirement Benefits [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Total Assets Owned At the End of Period	10,211	9,734
Fair value of plan assets at beginning of year			8,643
Fair value of plan assets at end of year	10,094	9,601	8,643
Other Postretirement Benefits [Member] | Cash and Cash Equivalents [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	1,242	1,152
Other Postretirement Benefits [Member] | Cash and Cash Equivalents [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	168	302
Other Postretirement Benefits [Member] | Equity Securities, International Funds [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	10,332	11,634
Other Postretirement Benefits [Member] | Equity Securities, International Funds [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	1,277	1,334
Other Postretirement Benefits [Member] | Equity Securities, Domestic Value [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	8,365	6,388
Other Postretirement Benefits [Member] | Equity Securities, Domestic Value [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	403	381
Other Postretirement Benefits [Member] | Equity Securities, Domestic Growth [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	5,960	24,135
Other Postretirement Benefits [Member] | Equity Securities, Domestic Growth [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	1,024	4,171
Other Postretirement Benefits [Member] | Equity Securities, Other Funds [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	30,997	14,028
Other Postretirement Benefits [Member] | Equity Securities, Other Funds [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	3,790	1,844
Other Postretirement Benefits [Member] | Fixed income securities, Mutual funds [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	22,122	16,796
Other Postretirement Benefits [Member] | Fixed income securities, Mutual funds [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	3,549	1,702
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 1 [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Total Assets Owned At the End of Period	37,689	31,430
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 1 [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Total Assets Owned At the End of Period	5,144	4,233
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 1 [Member] | Cash and Cash Equivalents [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	1,242	1,152
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 1 [Member] | Cash and Cash Equivalents [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	168	302
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 1 [Member] | Equity Securities, International Funds [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 1 [Member] | Equity Securities, International Funds [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 1 [Member] | Equity Securities, Domestic Value [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	8,365	6,388
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 1 [Member] | Equity Securities, Domestic Value [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	403	381
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 1 [Member] | Equity Securities, Domestic Growth [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	5,960	7,094
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 1 [Member] | Equity Securities, Domestic Growth [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	1,024	1,848
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 1 [Member] | Equity Securities, Other Funds [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 1 [Member] | Equity Securities, Other Funds [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 1 [Member] | Fixed income securities, Mutual funds [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	22,122	16,796
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 1 [Member] | Fixed income securities, Mutual funds [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	3,549	1,702
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 2 [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Total Assets Owned At the End of Period	41,329	42,703
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 2 [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Total Assets Owned At the End of Period	5,067	5,501
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 2 [Member] | Cash and Cash Equivalents [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 2 [Member] | Cash and Cash Equivalents [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 2 [Member] | Equity Securities, International Funds [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	10,332	11,634
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 2 [Member] | Equity Securities, International Funds [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	1,277	1,334
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 2 [Member] | Equity Securities, Domestic Value [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 2 [Member] | Equity Securities, Domestic Value [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 2 [Member] | Equity Securities, Domestic Growth [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	17,041
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 2 [Member] | Equity Securities, Domestic Growth [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	2,323
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 2 [Member] | Equity Securities, Other Funds [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	30,997	14,028
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 2 [Member] | Equity Securities, Other Funds [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	3,790	1,844
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed income securities, Mutual funds [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed income securities, Mutual funds [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 3 [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Total Assets Owned At the End of Period	0	0
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 3 [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Total Assets Owned At the End of Period	0	0
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 3 [Member] | Cash and Cash Equivalents [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 3 [Member] | Cash and Cash Equivalents [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 3 [Member] | Equity Securities, International Funds [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 3 [Member] | Equity Securities, International Funds [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 3 [Member] | Equity Securities, Domestic Value [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 3 [Member] | Equity Securities, Domestic Value [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 3 [Member] | Equity Securities, Domestic Growth [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 3 [Member] | Equity Securities, Domestic Growth [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 3 [Member] | Equity Securities, Other Funds [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 3 [Member] | Equity Securities, Other Funds [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed income securities, Mutual funds [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Other Postretirement Benefits [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed income securities, Mutual funds [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	0	0
Carrying (Reported) Amount, Fair Value Disclosure [Member] | PNMR [Member]
Defined Benefit Plan Disclosure [Line Items]
Long-term debt	1,975,090	1,745,420
Investment in PVNGS lessor notes	31,232	52,958
Other investments	1,762	1,835
Carrying (Reported) Amount, Fair Value Disclosure [Member] | Public Service Company of New Mexico [Member]
Defined Benefit Plan Disclosure [Line Items]
Long-term debt	1,490,657	1,290,618
Investment in PVNGS lessor notes	31,232	52,958
Other investments	397	445
Carrying (Reported) Amount, Fair Value Disclosure [Member] | Texas-New Mexico Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Long-term debt	365,667	336,036
Other investments	$ 242	$ 245

XML

Regulatory and Rate Matters

12 Months Ended

Dec. 31, 2014

Regulated Operations [Abstract]

Regulatory and Rate Matters

Regulatory and Rate Matters

The Company is involved in various regulatory matters, some of which contain contingencies that are subject to the same uncertainties as those described in Note 16.

PNM

2014 Electric Rate Case

On December 11, 2014, PNM filed an application for revision of electric retail rates based upon a calendar year 2016 future year test period. The application proposes a revenue increase of $107.4 million, effective January 1, 2016. PNM’s proposed ROE is 10.5%. The requested base rate increase, combined with other rate changes, represent an average bill increase of 7.69%. PNM requested this increase to account for infrastructure investments made since the last rate case and investments needed in the next two years to provide reliable service to PNM’s retail customers, as well as to reflect the declining sales growth in PNM’s service territory. The primary driver of PNM’s identified revenue deficiency, accounting for approximately 92% of the rate increase, is related to infrastructure investments and the recovery of those investment dollars, including depreciation. PNM’s success with energy efficiency programs is a contributing factor to the decline in PNM’s energy sales since the last rate case and accounts for the balance of the rate increase after accounting for offsetting cost reductions. PNM is proposing several changes to rate design to establish fair and equitable pricing across rate classes and to better align cost recovery with cost causation. Specific rate design proposals include increased customer and demand charges, a revenue decoupling pilot program applicable to residential and small power customers, an access charge to customers installing photovoltaic systems after December 31, 2015, a re-allocation of revenue among PNM’s customer classes, a new economic development rate, and continuation of PNM’s renewable energy rider. A public hearing on the rate case is expected to begin in July 2015 and an order from the NMPRC is expected in the fourth quarter of 2015.

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.

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. Currently, the RCT is set at 3% of customers’ annual electric charges.

PNM’s renewable energy procurement plan for 2012 requested a variance from the RPS due to RCT limitations. The plan was diversity-compliant based on the reduced RPS, except for non-wind/non-solar resources, which were not available. In December 2011, the NMPRC approved PNM’s 2012 plan, but ordered PNM to spend an additional $0.9 million on renewable procurements in 2012. The NMPRC also required PNM to file its 2013 renewable energy procurement plan by April 30, 2012. The 2013 plan proposed procurements for 2013 and 2014 of 20 MW of PNM-owned solar PV facilities, at an estimated cost of $45.5 million, wind and solar REC purchases in 2013, and a PPA for the output of the Lightning Dock Geothermal facility. The plan also included an additional procurement of 2 MW of PNM-owned solar PV facilities at an estimated cost of $4.5 million to supply the energy sold under PNM’s voluntary renewable energy tariff. The plan enabled PNM to comply with the statutory RPS in 2013, but required a variance from the NMPRC’s diversity requirements in 2013 while the proposed geothermal facilities were being constructed. The NMPRC approved the plan in December 2012, but reduced the additional solar PV procurement from 2 MW to 1.5 MW. In 2013, PNM made renewable procurements consistent with the 2013 plan approved by the NMPRC. Construction of the solar PV facilities was completed in 2013 at a cost of $48.9 million. The geothermal 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 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 generator 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 filed its 2015 renewable energy procurement plan on June 2, 2014. The plan meets RPS and diversity requirements within the RCT in 2015 and 2016. PNM’s proposed new procurements included the construction by December 31, 2015 of 40 MW of PNM-owned solar PV facilities at a cost of $79.3 million. The proposed 40 MW solar facilities are identified as being a cost-effective resource in PNM’s application to retire SJGS Units 2 and 3 (Note 16). On September 25, 2014, a stipulated settlement was filed by PNM, staff of the NMPRC, the NMAG, NMIEC, Coalition for Clean Affordable Energy, and Western Resource Advocates. The stipulation proposed approval of PNM’s procurement proposals; however, the costs for the 40 MW of solar would be included in base rates to be set in PNM’s next general rate case rather than through PNM’s renewable energy rider. Under the agreement, PNM would be required to make additional renewable energy procurements in the event that the prior year’s actual renewable energy procurements did not meet the RPS for that year based on actual retail sales and the actual RCT. The parties also agreed to have additional discussions to attempt to reach agreement on RPS and large customer adjustment calculations to be used in future PNM renewable procurement plans. A public hearing on the stipulation was held on October 27, 2014. On November 26, 2014, the NMPRC issued an order approving the stipulation with a modification that revised the not-to-exceed price from $4.25 per MWh to $3.00 per MWh for any additional necessary procurements to meet the RPS requirement in 2013 or 2014. In December 2014, PNM procured an additional 44,000 MWh of renewable resources to meet the 2013 RPS requirement at an average cost of $1.75 per MWh.

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. Preliminary calculations indicate PNM’s jurisdictional equity return did not exceed 10.5% in 2014.

PNM recorded revenues from the rider of $34.3 million, $23.7 million, and $6.4 million in 2014, 2013, and 2012. In PNM’s 2015 renewable energy procurement plan case, the NMPRC approved a rate, which is designed to collect $44.7 million in 2015.

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.

On October 6, 2014, PNM filed an energy efficiency program application for programs proposed to be offered beginning in June 2015. The filing included proposed program costs of $25.8 million plus a proposed profit incentive. The proposed energy efficiency budget and plan are consistent with the 2013 amendments to the Efficient Use of Energy Act. PNM and the NMPRC staff filed a stipulation on January 30, 2015. If approved, the stipulation would establish program budgets and incentive amounts, assuming a threshold level of energy savings are achieved, for 2015 and 2016. Two parties filed statements in opposition to the stipulation. A public hearing on the stipulation was held in February 2015.

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.

In June 2011, the NMPRC approved PNM-specific incentives for savings. PNM collected approximately $1.3 million, on an annual basis, in incentive revenues through November 2013 consistent with this order. On March 27, 2013, PNM filed its reconciliation for actual energy efficiency program costs, associated incentives, and actual collections for calendar year 2012. The reconciliation filing showed a net over-recovery of $0.2 million, composed of an over-recovery of $1.0 million of program costs and an under-recovery of incentives of $0.8 million. PNM subsequently revised the estimated incentive under-recovery to $0.5 million. PNM and the NMPRC staff filed a motion seeking to substitute the new reconciliation filing with a proposed effective date of May 28, 2013. On April 24, 2013, the NMPRC issued an order granting the motion. PNM implemented the new rate on May 28, 2013. In PNM’s 2014 energy efficiency program application, PNM proposed an energy efficiency incentive of $2.1 million. PNM’s proposed incentive was based upon a shared benefits methodology and is similar in amount to previous PNM incentives authorized by the NMPRC. Under the terms of the January 30, 2015 stipulation discussed above, the incentive amount would be $1.7 million in 2015 and $1.8 million in 2016 assuming threshold level of savings are achieved. A public hearing was held in February 2015. The NMPRC has not yet acted upon PNM’s application.

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 utility’s WACC times its approved annual program costs. The NMPRC received comments and a public hearing was held on November 20, 2013. The NMPRC issued an order on October 8, 2014, adopting the proposed rule.

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. 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 mine fire incident discussed in Note 16, resolves the ratemaking treatment for coal pre-treatment at SJGS until the next rate case, required PNM to write-off $10.5 million of the under-collected balance in its FPPAC balancing account, and required 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.

The NMPRC approval of the amended stipulation in PNM’s 2010 Electric Rate Case limited the amount that could be recovered on an annual basis for fuel costs during certain years. Costs in excess of the limits were deferred, without carrying costs, for recovery in future periods. The fuel cost caps were $38.8 million for the FPPAC year beginning July 1, 2012 and $36.2 million for the FPPAC year beginning July 1, 2013. The fuel cost caps ended on June 30, 2014. The resulting under-recovery as of April 30, 2014 was $63.5 million. Consistent with the order approved in PNM’s FPPAC Continuation Application, PNM is recovering this under-collection, net of the write-off agreed to in the settlement, over an 18 month period beginning July 1, 2014.

Integrated Resource Plan

NMPRC rules require that investor owned utilities file an IRP every three years. The IRP is required to cover a 20-year planning period and contain an action plan covering the first four years of that period. PNM filed its 2014 IRP on July 1, 2014. The four-year action plan was consistent with the replacement resources identified in PNM’s application to retire SJGS Units 2 and 3. PNM indicated that it planned to meet its anticipated long-term load growth with a combination of additional renewable energy resources, energy efficiency, and natural gas-fired facilities. Consistent with statute and NMPRC rule, PNM incorporated a public advisory process into the development of its 2014 IRP. On July 31, 2014, several parties requested the NMPRC not to accept the 2014 IRP as compliant with NMPRC rule because to do so could affect the pending proceeding on PNM’s application to abandon SJGS Units 2 and 3 and for CCNs for certain replacement resources (Note 16) and because they assert that the IRP does not conform to the NMPRC’s IRP rule. Certain parties also ask that further proceedings on the IRP be held in abeyance until the conclusion of the pending abandonment/CCN proceeding. The NMPRC issued an order in August 2014 that dockets a case to determine whether the IRP complies with applicable NMPRC rules. The order also holds the case in abeyance pending the issuance of final, non-appealable orders in PNM’s 2015 renewable energy procurement plan case and its application to retire SJGS Units 2 and 3.

San Juan Generating Station Units 2 and 3 Retirement

On December 20, 2013, PNM filed an application at the NMPRC to retire SJGS Units 2 and 3 on December 31, 2017. On October 1, 2014, PNM and certain parties to the case filed a stipulation with the NMPRC proposing a settlement of this case. Other parties are opposing the stipulated agreement. Additional information concerning the NMPRC filing, including a summary of the terms of the stipulation is set forth in Note 16. A public hearing in the NMPRC case was held in January 2015. 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.

Four Corners Right of First Refusal

On February 17, 2015, PNM received notice from EPE that EPE has entered into an agreement to sell its 7% interest in Four Corners to APS, thereby triggering PNM’s ability to exercise its right of first refusal (“ROFR”) to acquire a portion of EPE’s interest in Four Corners. PNM intends to inform the NMPRC about receipt of the notice and advise the NMPRC that PNM does not intend to exercise its rights under the ROFR. If not exercised, the ROFR will expire 120 days from the date of the notice.

Transmission Rate Case

In October 2010, PNM filed a notice with FERC to increase its wholesale electric transmission revenues by $11.1 million annually, based on a return on equity of 12.25%. The filing also sought to revise certain Open Access Transmission Tariff provisions and bi-lateral contractual terms.  In December 2010, FERC issued an order accepting PNM’s filing and suspending the proposed tariff revisions for five months. The proposed rates were implemented on June 1, 2011, subject to refund. The rate increase applied to all of PNM’s wholesale electric transmission service customers, which include other utilities, electric cooperatives, and entities that use PNM’s transmission system to transmit power at the wholesale level.  The rate increase did not impact PNM’s retail customers. On January 2, 2013, FERC approved an unopposed settlement agreement, which increases transmission service revenues by $2.9 million annually. In addition, the parties agreed that if PNM files for a formula based rate change within one year from FERC’s approval of the settlement agreement, no party will oppose the general principle of a formula rate, although the parties may still object to particular aspects of the formula. PNM refunded amounts collected in excess of the settled rates in January 2013, concluding this matter.

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. The 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. The proposed $3.2 million rate increase would be in addition to the $2.9 million rate increase approved by the FERC on January 2, 2013.

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 apply to all of PNM’s wholesale electric transmission service 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 then current rates. PNM filed the updated rate request with FERC on May 30, 2014, at which time the new rates became effective, subject to refund. The parties have engaged in settlement negotiations and PNM anticipates that a settlement will be filed with FERC in the near future. There is no required time frame for FERC to act upon a settlement. PNM is unable to predict the outcome of this proceeding.

Firm-Requirements Wholesale Customers

Navopache Electric Cooperative, Inc. Rate Case

In September 2011, PNM filed an unexecuted amended sales agreement between PNM and NEC with FERC. The agreement proposed a cost of service based rate for the electric service and ancillary services PNM provides to NEC, which would result in an annual increase of $8.7 million or a 39.8% increase over existing rates. PNM also requested a FPPAC and full recovery of certain third-party transmission charges PNM incurs to serve NEC. NEC filed a protest to PNM’s filing with FERC. In November 2011, FERC issued an order accepting the filing, suspending the effective date to be effective April 14, 2012, subject to refund, and set the proceeding for settlement. The parties finalized a settlement agreement and PNM filed for the necessary FERC approval on December 6, 2012. The settlement agreement provided for an annual increase of $5.3 million and an extension of the contract for 10 years through December 31, 2035. On April 5, 2013, FERC approved the settlement agreement. PNM has refunded the amounts collected in excess of the settled rates concluding this matter.

City of Gallup, New Mexico Contract

PNM provided 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.

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 ended on June 29, 2014.  PNM’s revenues for power sold under the Gallup contract were $6.1 million in the six months ended June 30, 2014 and totaled $11.7 million during 2013.  PNM’s 2014 Electric Rate Case discussed above reflects a reallocation of costs among regulatory jurisdictions reflecting the termination of the contract to serve Gallup.

TNMP

Advanced Meter System Deployment

In July 2011, the PUCT approved a settlement and authorized an AMS deployment plan that permits TNMP to collect $113.4 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 requested comments and held a public meeting on 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 were 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 sought recovery of $0.2 million through proposed initial fees ranging from $142.84 to $247.48 and an additional $0.5 million in annual ongoing expenses via a proposed monthly charge of $38.99. On June 20, 2014, the PUCT approved a settlement among the parties permitting TNMP to recover $0.2 million in costs through initial fees ranging from $63.97 to $168.61 and ongoing annual expenses of $0.5 million collected through a $36.78 monthly fee. The settlement presumes up to 1,081 consumers will elect the non-standard meter service, but preserves TNMP’s rights to adjust the fees if the number of anticipated consumers differs from that estimate. TNMP notified all appropriate customers that they could elect non-standard metering. As of February 20, 2015, 89 customers have made the election. TNMP does not expect the implementation of non-standard metering service to have a material impact on its financial position, results of operations, or cash flows.

Remand of ERCOT Transmission Rates for 1999 and 2000

Following various appeals, the ERCOT transmission rates approved for the fourth quarter of 1999 and 2000 were remanded back to the PUCT. In October 2011, TNMP joined in a non-unanimous settlement relating to resettlement of the fourth quarter of 1999. In January 2012, the PUCT approved the non-unanimous settlement awarding TNMP $1.6 million. In June 2012, TNMP filed its transmission cost recovery factor filing (“TCRF”) seeking $3.2 million in additional transmission costs. The PUCT staff requested a hearing asserting the settlement proceeds from the 1999 remand settlement must be credited against the costs TNMP requested in its TCRF. After further discussion, PUCT staff agreed that no credit was required since TNMP had not recovered those costs in 1999. The PUCT staff agreed to interim rate relief permitting TNMP to add $1.6 million in uncontested costs to its existing TCRF. TNMP implemented the interim rates on September 1, 2012. On November 19, 2012, the PUCT ordered that the $1.6 million in interim rates were final and authorized TNMP to institute a surcharge in March 2013 to collect the additional $1.6 million in initially disputed costs plus interest.

Energy Efficiency

TNMP recovers the costs of its energy efficiency programs through an energy efficiency cost recovery factor, which includes projected program costs, under or over collected costs from prior years, rate case expenses, and performance bonuses (if the programs exceed expectations). In September 2011, the PUCT approved a settlement that allows TNMP to collect the estimated 2012 energy efficiency program costs of $3.4 million and a $0.3 million bonus for 2010. TNMP’s new rates were effective January 1, 2012. 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, including a performance bonus for 2012 of $0.7 million, beginning March 1, 2014. On May 30, 2014, TNMP filed its 2015 energy efficiency cost recovery factor application with the PUCT requesting recovery of $5.7 million to be collected beginning March 1, 2015. The request included an incentive bonus of $1.5 million for having achieved demand savings for the 2013 program year that exceeded the goal. On August 6, 2014, the parties filed a stipulation resolving TNMP’s application. The PUCT approved the settlement on September 11, 2014 permitting TNMP to collect $5.7 million beginning March 1, 2015. TNMP recorded the $1.5 million incentive bonus for 2013 upon approval by 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. The following sets forth TNMP’s most recent interim transmission cost rate increases:

Effective Date	Approved Increase in Rate Base		Annual Increase in Revenue
	(in millions)
September 27, 2012	$	26.4	$	2.5
March 20, 2013	21.9		2.9
September 17, 2013	18.1		2.8
March 13, 2014	18.2		2.9
September 8, 2014	25.2		4.2

In January 2015, TNMP filed an application to further update its transmission rates to reflect an increase in total rate base of $27.1 million, which would increase revenues by $4.4 million annually. The application is pending before the PUCT.

Periodic Distribution Rate Adjustment

In September 2011, the PUCT approved a new rule permitting interim rate adjustments to reflect changes in investments in distribution assets. The rule permits distribution utilities to file for a periodic rate adjustment between April 1 and April 8 of each year as long as the electric utility is not earning more than its authorized rate of return using weather-normalized data.

Consolidated Tax Savings Adjustment

On June 14, 2013, the Governor of Texas signed into law a bill eliminating the consolidated tax savings adjustment (“CTSA”) from electric utility ratemaking in Texas. Previously, the CTSA required electric utilities to artificially reduce their respective tax expenses due to the losses incurred by their affiliates. The bill became effective on September 1, 2013.

XML

Summary of the Business and Significant Accounting Policies (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 1986 Operating_Leases	Dec. 31, 2004	Dec. 31, 2003	Dec. 31, 1985 Operating_Leases
Accounting Policies Disclosures [Line Items]
Debt, Weighted Average Interest Rate	6.60%	6.90%	6.60%
Interest costs incurred, capitalized	$ 1.6	$ 1.5	$ 1.2
Public Service Company of New Mexico [Member]
Accounting Policies Disclosures [Line Items]
Allowance for funds used during construction, capitalized interest	4.2	3.3	3.5
Public Utilities, Allowance for Funds Used During Construction, Capitalized Cost of Equity	5.6	4.4	3.8
Interest costs incurred, capitalized	1.1	1.1	0.8
Impairment losses on securities held in the NDT	4.8	3.5	4.8
Texas-New Mexico Power Company [Member]
Accounting Policies Disclosures [Line Items]
Allowance for funds used during construction, capitalized interest	0.5	0.4	0.7
Public Utilities, Allowance for Funds Used During Construction, Capitalized Cost of Equity	0	0	0.6
Interest costs incurred, capitalized	$ 0.1	$ 0	$ 0
Palo Verde Nuclear Generating Station [Member] | Public Service Company of New Mexico [Member]
Accounting Policies Disclosures [Line Items]
Number of operating leases (in ones)	8			11
EIP Transmission Line [Member] | Public Service Company of New Mexico [Member]
Accounting Policies Disclosures [Line Items]
Number of operating leases (in ones)							2
Ownership percentage acquired (as a percent)					40.00%	60.00%
10.3% Lessor Notes [Member] | Public Service Company of New Mexico [Member]
Accounting Policies Disclosures [Line Items]
Notes receivable, stated percentage rate (as a percent)	10.30%
10.15% Lessor Notes [Member] | Public Service Company of New Mexico [Member]
Accounting Policies Disclosures [Line Items]
Notes receivable, stated percentage rate (as a percent)	10.15%
10.25% EIP Lessor Note Maturing in 2012 [Member] | EIP Transmission Line [Member] | Public Service Company of New Mexico [Member]
Accounting Policies Disclosures [Line Items]
Notes receivable, stated percentage rate (as a percent)	10.25%

XML

Pension and Other Postretirement Benefits (Tables)

12 Months Ended

Dec. 31, 2014

Defined Benefit Plan Disclosure [Line Items]

Schedule of Defined Benefit Plans Disclosures

A reconciliation of the changes in Level 3 fair value measurements is as follows:

	Year Ended December 31,
	2014			2013
Level 3 Fair Value Assets and Liabilities	(In thousands)
PNM Pension	Master Trust			Master Trust
Balance at beginning of period	$	80,991		$	79,017
Actual return on assets sold during the period	10,376			3,303
Actual return on assets still held at period end	(5,731		)	3,361
Purchases	8,832			15,110
Sales	(28,843		)	(19,800		)
Balance at end of period	65,625			80,991
TNMP Pension
Balance at beginning of period	$	15,008		$	14,171
Actual return on assets sold during the period	3,409			1,400
Actual return on assets still held at period end	(1,883		)	1,425
Purchases	2,902			6,408
Sales	(9,477		)	(8,396		)
Balance at end of period	9,959			15,008
Total	$	75,584		$	95,999

Additional information concerning changes in Level 3 fair value measurements for the PNMR Master Trust is as follows:

Level 3 Fair Value Assets and Liabilities

PNMR Master Trust	Private equity funds			Hedge funds			Real estate funds			Fixed income - corporate			Total
				(In thousands)
Balance at December 31, 2012	$	38,212		$	31,277		$	23,699		$	—		$	93,188
Actual return on assets sold during the period	4,677			135			(109		)	1			4,704
Actual return on assets still held at period end	1,162			3,500			123			—			4,785
Purchases	3,117			16,151			2,076			175			21,519
Sales	(8,046		)	(16,151		)	(4,000		)	—			(28,197		)
Balance at December 31, 2013	39,122			34,912			21,789			176			95,999
Actual return on assets sold during the period	5,355			8,667			(236		)	—			13,786
Actual return on assets still held at period end	(296		)	(7,536		)	237			(20		)	(7,615		)
Purchases	3,656			5,500			1,971			608			11,735
Sales	(10,617		)	(17,667		)	(10,000		)	(37		)	(38,321		)
Balance at December 31, 2014	$	37,220		$	23,876		$	13,761		$	727		$	75,584

Schedule of Effect of One-Percentage-Point Change in Assumed Health Care Cost Trend Rates

The following table shows the impact of a one-percentage-point change in assumed health care cost trend rates:

	PNM Plan
	1-Percentage- Point  Increase		1-Percentage- Point  Decrease
	(In thousands)
Effect on total of service and interest cost	$	350	$	(281	)
Effect on APBO	$	5,305	$	(4,622	)

Schedule of Net Funded Status

For the executive retirement programs, the following table presents information about the PBO and funded status of the plans:

	PNM Plan						TNMP Plan
	Year Ended December 31,						Year Ended December 31,
	2014			2013			2014			2013
	(In thousands)
PBO at beginning of year	$	16,363		$	17,467		$	823		$	902
Service cost	—			—			—			—
Interest cost	822			720			39			36
Actuarial (gain) loss	2,040			(330		)	110			(21		)
Benefits paid	(1,495		)	(1,494		)	(94		)	(94		)
PBO at end of year – funded status	17,730			16,363			878			823
Less current liability	1,528			1,536			94			94
Non-current liability	$	16,202		$	14,827		$	784		$	729

Schedule of Defined Contribution Plan Expenses

A summary of expenses for these other retirement plans is as follows:

	Year Ended December 31,
	2014		2013		2012
	(In thousands)
PNMR
401(k) plan	$	16,703	$	16,785	$	16,185
Non-qualified plan	$	2,257	$	2,204	$	1,491
PNM
401(k) plan	$	12,745	$	12,952	$	12,427
Non-qualified plan	$	1,722	$	1,691	$	1,143
TNMP
401(k) plan	$	3,958	$	3,953	$	3,739
Non-qualified plan	$	535	$	513	$	327

Pension Plan [Member]

Defined Benefit Plan Disclosure [Line Items]

Schedule of Defined Benefit Plans Disclosures

The following table presents information about the PBO, fair value of plan assets, and funded status of the plans:

	PNM Plan						TNMP Plan
	Year Ended December 31,						Year Ended December 31,
	2014			2013			2014			2013
	(In thousands)
PBO at beginning of year	$	599,537		$	675,549		$	66,159		$	76,640
Service cost	—			—			—			—
Interest cost	30,163			28,142			3,193			3,087
Plan amendment	—			(6,346		)	—			—
Actuarial (gain) loss	72,524			(56,533		)	8,466			(7,820		)
Benefits paid	(44,667		)	(41,275		)	(5,513		)	(5,748		)
PBO at end of year	657,557			599,537			72,305			66,159
Fair value of plan assets at beginning of year	556,353			518,095			66,118			66,540
Actual return on plan assets	76,223			19,533			8,572			4,326
Employer contributions	—			60,000			—			1,000
Benefits paid	(44,667		)	(41,275		)	(5,513		)	(5,748		)
Fair value of plan assets at end of year	587,909			556,353			69,177			66,118
Funded status – asset (liability) for pension benefits	$	(69,648	)	$	(43,184	)	$	(3,128	)	$	(41	)

Schedule of Amounts in Accumulated Other Comprehensive Income (Loss) to be Recognized over Next Fiscal Year

The following table presents pre-tax information about prior service cost and net actuarial (gain) loss in AOCI as of December 31, 2014.

	PNM Plan						TNMP Plan
	December 31, 2014						December 31, 2014
	Prior service cost			Net actuarial (gain) loss			Net actuarial (gain) loss
	(In thousands)
Amounts in AOCI not yet recognized in net periodic benefit cost (income) at beginning of year	$	(2,665	)	$	139,256		$	—
Experience loss (gain)	—			34,345			4,420
Regulatory asset (liability) adjustment	—			(19,920		)	(4,420		)
Amortization recognized in net periodic benefit cost (income)	405			(5,469		)	—
Amounts in AOCI not yet recognized in net periodic benefit cost (income) at end of year	$	(2,260	)	$	148,212		$	—
Amortization expected to be recognized in 2015	$	(405	)	$	6,224		$	—

Schedule of Net Benefit Costs

The following table presents the components of net periodic benefit cost (income):

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
PNM Plan
Service cost	$	—		$	—		$	—
Interest cost	30,163			28,142			32,232
Expected return on plan assets	(38,044		)	(41,930		)	(41,301		)
Amortization of net (gain) loss	13,020			14,840			10,516
Amortization of prior service cost	(965		)	76			317
Net periodic benefit cost	$	4,174		$	1,128		$	1,764
TNMP Plan
Service cost	$	—		$	—		$	—
Interest cost	3,193			3,087			3,635
Expected return on plan assets	(4,526		)	(4,849		)	(5,324		)
Amortization of net (gain) loss	665			1,049			462
Amortization of prior service cost	—			—			—
Net periodic benefit cost (income)	$	(668	)	$	(713	)	$	(1,227	)

Schedule of Assumptions Used

The following significant weighted-average assumptions were used to determine the PBO and net periodic benefit cost (income). Should actual experience differ from actuarial assumptions, the PBO and net periodic benefit cost (income) would be affected.

	Year Ended December 31,
PNM Plan	2014		2013		2012
Discount rate for determining December 31 PBO	4.48	%	5.27	%	4.30	%
Discount rate for determining net periodic benefit cost (income)	5.27	%	4.30	%	5.67	%
Expected return on plan assets	7.20	%	7.65	%	8.25	%
Rate of compensation increase	N/A		N/A		N/A
TNMP Plan
Discount rate for determining December 31 PBO	4.39	%	5.06	%	4.19	%
Discount rate for determining net periodic benefit cost (income)	5.06	%	4.19	%	5.69	%
Expected return on plan assets	7.20	%	7.65	%	8.25	%
Rate of compensation increase	N/A		N/A		N/A

Schedule of Expected Benefit Payments

The following pension benefit payments are expected to be paid:

	PNM Plan		TNMP Plan
	(In thousands)
2015	$	53,472	$	5,997
2016	53,468		5,667
2017	51,241		5,351
2018	49,640		5,585
2019	48,560		5,188
2020 – 2024	213,759		23,600

Other Postretirement Benefits [Member]

Defined Benefit Plan Disclosure [Line Items]

Schedule of Defined Benefit Plans Disclosures

The following table presents information about the APBO, the fair value of plan assets, and the funded status of the plans:

	PNM Plan						TNMP Plan
	Year Ended December 31,						Year Ended December 31,
	2014			2013			2014			2013
	(In thousands)
APBO at beginning of year	$	92,165		$	99,613		$	12,266		$	13,678
Service cost	181			260			237			299
Interest cost	4,630			4,113			619			566
Participant contributions	2,582			2,537			366			373
Actuarial (gain) loss	4,455			(4,566		)	1,639			(1,080		)
Benefits paid	(8,838		)	(9,792		)	(1,057		)	(1,570		)
APBO at end of year	95,175			92,165			14,070			12,266
Fair value of plan assets at beginning of year	73,565			64,464			9,601			8,643
Actual return on plan assets	7,334			12,780			841			1,813
Employer contributions	3,532			3,576			343			342
Participant contributions	2,582			2,537			366			373
Benefits paid	(8,838		)	(9,792		)	(1,057		)	(1,570		)
Fair value of plan assets at end of year	78,175			73,565			10,094			9,601
Funded status – asset (liability)	$	(17,000	)	$	(18,600	)	$	(3,976	)	$	(2,665	)

Schedule of Amounts in Accumulated Other Comprehensive Income (Loss) to be Recognized over Next Fiscal Year

In the year ended December 31, 2014, actuarial losses of $2.8 million and $1.3 million were recorded in regulatory assets for the PNM Plan and TNMP Plan. There were no prior service costs recorded for the year ended December 31, 2014.

Schedule of Net Benefit Costs

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

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
PNM Plan
Service cost	$	181		$	260		$	217
Interest cost	4,630			4,113			5,293
Expected return on plan assets	(5,638		)	(5,043		)	(4,901		)
Amortization of net (gain) loss	2,225			4,242			3,888
Amortization of prior service credit	(1,343		)	(1,343		)	(1,343		)
Net periodic benefit cost	$	55		$	2,229		$	3,154
TNMP Plan
Service cost	$	237		$	299		$	244
Interest cost	619			566			624
Expected return on plan assets	(534		)	(503		)	(516		)
Amortization of net (gain) loss	(122		)	—			(209		)
Amortization of prior service cost	32			57			57
Net periodic benefit cost	$	232		$	419		$	200

Schedule of Assumptions Used

The following significant weighted-average assumptions were used to determine the APBO and net periodic benefit cost. Should actual experience differ from actuarial assumptions, the APBO and net periodic benefit cost would be affected.

	Year Ended December 31,
PNM Plan	2014		2013		2012
Discount rate for determining December 31 APBO	4.45	%	5.21	%	4.26	%
Discount rate for determining net periodic benefit cost	5.21	%	4.26	%	5.70	%
Expected return on plan assets	8.50	%	8.50	%	8.50	%
Rate of compensation increase	N/A		N/A		N/A
TNMP Plan
Discount rate for determining December 31 APBO	4.45	%	5.21	%	4.26	%
Discount rate for determining net periodic benefit cost	5.21	%	4.26	%	5.70	%
Expected return on plan assets	6.50	%	6.50	%	6.50	%
Rate of compensation increase	N/A		N/A		N/A

Schedule of Expected Benefit Payments

The following other postretirement benefit payments, which reflect expected future service, are expected to be paid:

	PNM Plan		TNMP Plan
	(In thousands)
2015	$	6,560	$	801
2016	6,635		822
2017	6,718		838
2018	6,875		860
2019	6,950		882
2020 - 2024	34,585		4,717

Schedule of Health Care Cost Trend Rates

The following table shows the assumed health care cost trend rates for the PNM postretirement benefit plan:

	PNM Plan
	December 31,
	2014		2013
Health care cost trend rate assumed for next year	7.0	%	7.5	%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)	5.0	%	5.0	%
Year that the rate reaches the ultimate trend rate	2023		2019

Executive Retirement Program [Member]

Defined Benefit Plan Disclosure [Line Items]

Schedule of Amounts in Accumulated Other Comprehensive Income (Loss) to be Recognized over Next Fiscal Year

The following table presents pre-tax information about net actuarial loss in AOCI as of December 31, 2014.

	December 31, 2014
	PNM Plan			TNMP Plan
	(In thousands)
Amount in AOCI not yet recognized in net periodic benefit cost at beginning of year	$	1,833		$	—
Experience loss (gain)	2,040			(110		)
Regulatory asset (liability) adjustment	(1,183		)	110
Amortization recognized in net periodic benefit cost (income)	(88		)	—
Amount in AOCI not yet recognized in net periodic benefit cost at end of year	$	2,602		$	—
Amortization expected to be recognized in 2015	$	136		$	—

Schedule of Net Benefit Costs

The following table presents the components of net periodic benefit:

	Year Ended December 31,
	2014		2013		2012
	(In thousands)
PNM Plan
Service cost	$	—	$	—	$	—
Interest cost	822		720		876
Amortization of net (gain) loss	210		232		83
Amortization of prior service cost	—		—		—
Net periodic benefit cost	$	1,032	$	952	$	959
TNMP Plan
Service cost	$	—	$	—	$	—
Interest cost	39		36		45
Amortization of net (gain) loss	—		—		—
Amortization of prior service cost	—		—		—
Net periodic benefit cost	$	39	$	36	$	45

Schedule of Assumptions Used

The following significant weighted-average assumptions were used to determine the PBO and net periodic benefit cost. Should actual experience differ from actuarial assumptions, the PBO and net periodic benefit cost would be affected.

	Year Ended December 31,
PNM Plan	2014		2013		2012
Discount rate for determining December 31 PBO	4.48	%	5.27	%	4.30	%
Discount rate for determining net periodic benefit cost	5.27	%	4.30	%	5.67	%
Long-term rate of return on plan assets	N/A		N/A		N/A
Rate of compensation increase	N/A		N/A		N/A
TNMP Plan
Discount rate for determining December 31 PBO	4.39	%	5.06	%	4.19	%
Discount rate for determining net periodic benefit cost	5.06	%	4.19	%	5.69	%
Long-term rate of return on plan assets	N/A		N/A		N/A
Rate of compensation increase	N/A		N/A		N/A

Schedule of Expected Benefit Payments

The following executive retirement plan payments, which reflect expected future service, are expected:

	PNM Plan		TNMP Plan
	(In thousands)
2015	$	1,528	$	93
2016	1,510		92
2017	1,490		91
2018	1,468		89
2019	1,445		86
2020 – 2024	6,722		384

XML

Income Taxes Schedule of Effective Income Tax Rate Reconciliation (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Taxes [Line Items]
Federal income tax at statutory rates	$ 70,226	$ 61,274	$ 61,262
Amortization of accumulated investment tax credits	(2,164)	(2,192)	(2,237)
Flow-through of depreciation items	1,344	1,132	1,284
Earnings attributable to non-controlling interest in Valencia	(4,945)	(5,082)	(4,918)
State income tax, net of federal benefit	5,723	3,818	4,646
Impairment of state net operating loss carryforwards	3,129	0	0
Impairment of state production tax credits, net of federal benefit	894	3,880	718
Other	(4,469)	(3,317)	(5,845)
Total income taxes	69,738	59,513	54,910
Effective tax rate	34.76%	33.99%	31.37%
Public Service Company of New Mexico [Member]
Income Taxes [Line Items]
Federal income tax at statutory rates	53,930	53,018	54,710
Amortization of accumulated investment tax credits	(2,164)	(2,192)	(2,237)
Flow-through of depreciation items	1,325	1,115	1,268
Earnings attributable to non-controlling interest in Valencia	(4,945)	(5,082)	(4,918)
State income tax, net of federal benefit	5,522	6,202	6,500
Impairment of state net operating loss carryforwards	2,145	0	0
Other	(3,180)	(4,257)	(4,610)
Total income taxes	52,633	48,804	50,713
Effective tax rate	34.16%	32.22%	32.44%
Texas-New Mexico Power Company [Member]
Income Taxes [Line Items]
Federal income tax at statutory rates	21,115	16,349	14,735
State income tax, net of federal benefit	1,257	1,247	1,185
Other	151	25	(568)
Total income taxes	$ 22,523	$ 17,621	$ 15,352
Effective tax rate	37.33%	37.72%	36.47%

XML

Regulatory and Rate Matters (Details) (USD $)	12 Months Ended	1 Months Ended	3 Months Ended	12 Months Ended		0 Months Ended		12 Months Ended	0 Months Ended	1 Months Ended		6 Months Ended				12 Months Ended	6 Months Ended		4 Months Ended
	Dec. 31, 2014	Dec. 31, 2011	Dec. 31, 2014 MW	Dec. 31, 2013	Dec. 31, 2012	Oct. 05, 2012	Oct. 06, 2014	Dec. 31, 2011	Dec. 06, 2012	Jul. 31, 2011	Jun. 30, 2012	Sep. 07, 2014	Mar. 12, 2014	Sep. 16, 2013	Mar. 19, 2013	Dec. 31, 2015	Sep. 15, 2015	Mar. 15, 2015	Jun. 17, 2015	Jan. 31, 2012	Feb. 20, 2015 customer	Feb. 17, 2015
Public Service Company of New Mexico [Member] | 2014 Electric Rate Case [Member]
Rate Matters [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 107,400,000
Public Utilities, Requested Return on Equity, Percentage	10.50%
Public Utilities, Average customer bill increase percentage	7.69%
Public Utilities, Percentage of requested rate increase pertaining to infrastructure investments	92.00%
Public Service Company of New Mexico [Member] | Renewable Portfolio Standard [Member]
Rate Matters [Line Items]
Public Utilites, Additional Renewable Procurements Spending Required by NMPRC		900,000
Public Utilities, Number of Mega Watts of Solar Photovoltaic Capacity	20		20
Public Utilities, Estimated Cost of Mega Watts of Solar Photovoltaic Capacity			45,500,000
Public Utilities, Final Cost of Solar Photovoltaic Capacity				48,900,000
Public Utilities, Number of Mega Watts of Solar Photovoltaic Capacity, Current Output	4		4
Public Utilities, Number of Mega Watts of Solar Photovoltaic Capacity, Expected Output	10		10
Public Service Company of New Mexico [Member] | Renewable Portfolio Standard [Member] | Minimum [Member]
Rate Matters [Line Items]
Public Utilities, Reasonable Cost Threshold	3.00%		3.00%
Public Service Company of New Mexico [Member] | Renewable Portfolio Standard [Member] | Maximum [Member]
Rate Matters [Line Items]
Public Utilities, Reasonable Cost Threshold	3.00%		3.00%
Public Service Company of New Mexico [Member] | Renewable Portfolio Standard [Member] | Wind Energy [Member] | Minimum [Member]
Rate Matters [Line Items]
Public Utilities, Required Percentage of Diversification	30.00%		30.00%
Public Service Company of New Mexico [Member] | Renewable Portfolio Standard [Member] | Solar Energy [Member] | Minimum [Member]
Rate Matters [Line Items]
Public Utilities, Required Percentage of Diversification	20.00%		20.00%
Public Service Company of New Mexico [Member] | Renewable Portfolio Standard [Member] | Renewable Technologies [Member] | Minimum [Member]
Rate Matters [Line Items]
Public Utilities, Required Percentage of Diversification	5.00%		5.00%
Public Service Company of New Mexico [Member] | Renewable Portfolio Standard [Member] | Distributed Generation [Member] | Minimum [Member]
Rate Matters [Line Items]
Public Utilities, Required Percentage of Diversification	1.50%		1.50%
Public Utilities, Future Required Percentage of Diversification	3.00%		3.00%
Public Service Company of New Mexico [Member] | Renewable Portfolio Standard [Member] | Required Percentage by 2011 [Member]
Rate Matters [Line Items]
Public Utilities, Required Percentage of Renewable Energy in Portfolio to Electric Sales	10.00%		10.00%
Public Service Company of New Mexico [Member] | Renewable Portfolio Standard [Member] | Required Percentage by 2015 [Member]
Rate Matters [Line Items]
Public Utilities, Required Percentage of Renewable Energy in Portfolio to Electric Sales	15.00%		15.00%
Public Service Company of New Mexico [Member] | Renewable Portfolio Standard [Member] | Required Percentage by 2020 [Member]
Rate Matters [Line Items]
Public Utilities, Required Percentage of Renewable Energy in Portfolio to Electric Sales	20.00%		20.00%
Public Service Company of New Mexico [Member] | Renewable Portfolio Standard Supplemental Procurement [Member]
Rate Matters [Line Items]
Public Utilities, Number of Mega Watts of Solar Photovoltaic Capacity	2		2
Public Utilities, Estimated Cost of Mega Watts of Solar Photovoltaic Capacity			4,500,000
Public Service Company of New Mexico [Member] | Renewable Portfolio Standard Supplemental Procurement Reduction [Member]
Rate Matters [Line Items]
Public Utilities, Number of Mega Watts of Solar Photovoltaic Capacity	1.5		1.5
Public Service Company of New Mexico [Member] | Renewable Portfolio Standard Supplemental Procurement Reduction [Member] | Maximum [Member]
Rate Matters [Line Items]
Public Utilities, Number of Mega Watts of Solar Photovoltaic Capacity	2		2
Public Service Company of New Mexico [Member] | Renewable Portfolio Standard 2014 [Member]
Rate Matters [Line Items]
Public Utilities, Number of Mega Watts of Solar Photovoltaic Capacity	23		23
Public Utilities, Estimated Cost of Mega Watts of Solar Photovoltaic Capacity	46,700,000
Public Utilities, Wind Capacity Planned Purchase Agreement Term	20 years
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 Service Company of New Mexico [Member] | Renewable Portfolio Standard 2015 [Member]
Rate Matters [Line Items]
Public Utilities, Number of Mega Watts of Solar Photovoltaic Capacity	40		40
Public Utilities, Estimated Cost of Mega Watts of Solar Photovoltaic Capacity	79,300,000
Public Utilities, Approved cost per MWh for additional necessary procurements to comply with RPS	4.25
Public Utilities, Approved Revised cost per MWh for additional necessary procurements to comply with RPS	3.00
Public Utilities, Number of MegaWatt Hours of renewable resources	44,000
Public Utilities, Actual cost per MWh for additional necessary procurements to comply with RPS	1.75
Public Service Company of New Mexico [Member] | 2014 Wind generated Renewable Energy Credits [Member]
Rate Matters [Line Items]
Public Utilities, Number of Mega Watt Hours of Wind Generation	50,000
Public Service Company of New Mexico [Member] | 2015 Wind generated Renewable Energy Credits [Member]
Rate Matters [Line Items]
Public Utilities, Number of Mega Watt Hours of Wind Generation	120,000
Public Service Company of New Mexico [Member] | Renewable Energy Rider [Member]
Rate Matters [Line Items]
Public Utilities, Revenue from Renewable energy rider	34,300,000			23,700,000	6,400,000
Public Service Company of New Mexico [Member] | Renewable Energy Rider [Member] | Maximum [Member]
Rate Matters [Line Items]
Public Utilities, Rider Condition of Earned Return on Jurisdictional Equity in 2013	10.50%
Public Utilities, Annual Revenue To be Collected Under 2015 Rider Rate	44,700,000		44,700,000
Public Service Company of New Mexico [Member] | Energy Efficient and Load Management [Member] | Disincentives / Incentives Adder [Member]
Rate Matters [Line Items]
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
Public Utilities, Energy Efficiency Incentive adder collected				1,300,000
Public Service Company of New Mexico [Member] | FPPAC Continuation Application [Member]
Rate Matters [Line Items]
Public Utilities, Retention Percentage of Sales Margins	10.00%
Public Utilities, Under-collected balance write-off				10,500,000
Public Utilities, Under-recovery expected to be collected	63,500,000		63,500,000
Public Service Company of New Mexico [Member] | FPPAC Continuation Application [Member] | Maximum [Member]
Rate Matters [Line Items]
Public Utilities, Fuel Costs to be Collected				36,200,000	38,800,000
Public Service Company of New Mexico [Member] | 2014 Energy Efficiency and Load Management Program [Member] | Disincentives / Incentives Adder [Member]
Rate Matters [Line Items]
Public Utilities, Program Costs Related To Energy Efficiency							25,800,000
Public Utilities, Proposed Profit Incentive Adder Revenues Related To Energy Efficiency Program	2,100,000
Public Utilities, Anticipated future profit incentive 2015	1,700,000		1,700,000
Public Utilities, Anticipated future profit incentive 2016	1,800,000		1,800,000
Public Service Company of New Mexico [Member] | Nmprc Rulemaking on Disincentives to Energy Efficiency Programs [Member]
Rate Matters [Line Items]
Public Utilities, Rate Rider Net Over-Recovery				200,000
Public Utilities, Rate Rider Program Costs Over-Recovery				1,000,000
Public Utilities, Rate Rider Incentives Under-Recovery				800,000
Public Utilities, Rate Rider Estimated Incentives Under-Recovery				500,000
Public Service Company of New Mexico [Member] | 2011 Integrated Resource Plan [Member]
Rate Matters [Line Items]
Public Utilities, Planning Period Covered of IRP	20 years
Public Service Company of New Mexico [Member] | Transmission Rate Case [Member]
Rate Matters [Line Items]
Public Utilities, Approved Rate Increase (Decrease), Amount								11,100,000
Public Utilities, Approved Return on Equity, Percentage								12.25%
Public Utilities, Increase Annual Transmission Service Revenue				2,900,000
Public Service Company of New Mexico [Member] | Wholesale Electric Transmission Rate Case [Member] [Member]
Rate Matters [Line Items]
Public Utilities, Approved Rate Increase (Decrease), Amount				2,900,000	3,200,000
Public Utilities, Approved Return on Equity, Percentage				10.81%
Public Utilities, Lease ownership percentage in EIP	60.00%
Public Utilities, Approved additional rate increase, Amount	500,000			1,300,000
Public Service Company of New Mexico [Member] | Firm Requirements Wholesale Power Rate Case, Navopache [Member] [Member]
Rate Matters [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount								8,700,000
Public Utilities, Approved Rate Increase (Decrease), Amount									5,300,000
Public Utilities, Regulatory Rate Increase								39.80%
Public Service Company of New Mexico [Member] | Firm Requirements Wholesale Power Rate Case [Member]
Rate Matters [Line Items]
Public Utilities, Contract Extension									10 years
Public Service Company of New Mexico [Member] | Firm Requirements Wholesale Power Contract, Gallup [Member]
Rate Matters [Line Items]
Public Utilities, Revenue For Power Sold Under Specific Contract	6,100,000			11,700,000
Texas-New Mexico Power Company [Member] | Advanced Meter System Deployment and Surcharge Request [Member]
Rate Matters [Line Items]
Public Utilities, Approved Deployment Costs										113,400,000
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				200,000
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, Non-standard metering service cost total to be borne by opt-out customers	200,000		200,000
Public Utilities, Non-standard metering ongoing expenses total to be borne by opt-out customers	500,000		500,000
Public Utilities, Non-standard metering ongoing expenses monthly charge	36.78		36.78
Presumed number of customers that will elect non-standard meter service	1,081		1,081
Texas-New Mexico Power Company [Member] | Advanced Meter System Deployment and Surcharge Request [Member] | Minimum [Member]
Rate Matters [Line Items]
Public Utilities, Non-standard metering service cost, Proposed initial fee range				142.84
Public Utilities, Non-standard metering service cost initial fee range	63.97		63.97
Texas-New Mexico Power Company [Member] | Advanced Meter System Deployment and Surcharge Request [Member] | Maximum [Member]
Rate Matters [Line Items]
Public Utilities, Non-standard metering service cost, Proposed initial fee range				247.48
Public Utilities, Non-standard metering service cost initial fee range	168.61		168.61
Texas-New Mexico Power Company [Member] | Ercot Transmission Rates [Member]
Rate Matters [Line Items]
Public Utilities, Eliminated Recovery of Adder Revenue																				1,600,000
Public Utilities, Additional Transmission Costs Requested											3,200,000
Texas-New Mexico Power Company [Member] | Ercot Transmission Rates [Member] | PUCT staff agreed to interim rate relief that will permit TNMP to add uncontested costs to its existing TCRF [Member]
Rate Matters [Line Items]
Public Utilities, Approved Additional Transmission Costs				1,600,000
Texas-New Mexico Power Company [Member] | Energy Efficiency [Member]
Rate Matters [Line Items]
Public Utilities, Approved Program Implementation Costs	5,600,000			5,200,000	3,400,000
Public Utilities, Approved Program Implementation Costs, Bonus	1,500,000				300,000
Public Utilities, Unapproved 2015 Program Implementation Costs, Bonus	700,000		700,000	1,500,000
Public Utilities, Unapproved 2015 Program Implementation Costs	5,700,000		5,700,000
Texas-New Mexico Power Company [Member] | Transmission Cost of Service Rates [Member]
Rate Matters [Line Items]
Public Utilities, Approved Rate Increase (Decrease), Amount												18,200,000	18,100,000	21,900,000	26,400,000
Public Utilities, Increase Annual Transmission Service Revenue												2,900,000	2,800,000	2,900,000	2,500,000
Texas-New Mexico Power Company [Member] | Subsequent Event [Member] | Advanced Meter System Deployment and Surcharge Request [Member]
Rate Matters [Line Items]
Current number of customers that have elected non-standard meter service																					89
Texas-New Mexico Power Company [Member] | Subsequent Event [Member] | Energy Efficiency [Member]
Rate Matters [Line Items]
Public Utilities, Approved Program Implementation Costs																5,700,000
Texas-New Mexico Power Company [Member] | Subsequent Event [Member] | Transmission Cost of Service Rates [Member]
Rate Matters [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount																	27,100,000
Public Utilities, Approved Rate Increase (Decrease), Amount																		25,200,000
Public Utilities, Increase Annual Transmission Service Revenue																		4,200,000
Public Utilities, Requested Increase Annual Transmission Service Revenue																	$ 4,400,000
Four Corners [Member] | Public Service Company of New Mexico [Member] | Subsequent Event [Member]
Rate Matters [Line Items]
Jointly Owned Utility Plant Proportionate Ownership Share, Other Entities																						7.00%
Period of time to file a waiver of rights of first refusal																			120 days

XML

Lease Commitments Lease Commitments (Tables)

12 Months Ended

Dec. 31, 2014

Leases [Abstract]

Schedule of Rent Expense

Operating lease expense, including the PVNGS and EIP leases, was:

	PNMR		PNM		TNMP
	(In thousands)
2014	$	82,756	$	76,745	$	3,932
2013	$	82,882	$	78,306	$	2,663
2012	$	84,794	$	78,483	$	2,871

Schedule of Future Minimum Rental Payments for Operating Leases

Future minimum operating lease payments at December 31, 2014 shown below have been reduced by payments on the PVNGS lessor notes of $24.0 million in 2015 and $9.0 million in 2016 that will be returned in cash to PNM:

	PNMR		PNM		TNMP
	(In thousands)
2015	$	36,350	$	33,144	$	1,186
2016	28,892		27,986		636
2017	25,185		24,907		—
2018	25,194		24,907		—
2019	25,203		24,907		—
Later years	134,068		133,842		—
Total minimum lease payments	$	274,892	$	269,693	$	1,822

XML

Segment Information (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information, Profit (Loss) [Abstract]
Electric Operating Revenues	$ 346,845	$ 413,951	$ 346,160	$ 328,897	$ 322,929	$ 399,730	$ 347,599	$ 317,665	$ 1,435,853	$ 1,387,923	$ 1,342,403
Cost of energy									471,556	432,316	399,850
Margin									964,297	955,607	942,553
Other operating expenses									491,966	501,884	504,659
Depreciation and amortization									172,634	166,881	164,173
Operating income	62,849	116,799	71,296	48,753	40,532	117,739	77,867	50,704	299,697	286,842	273,721
Interest income									8,483	10,043	13,072
Gain on sale of First Choice									0	0	1,012
Other income (deductions)									12,094	(368)	8,075
Interest charges									(119,627)	(121,448)	(120,845)
Earnings before Income Taxes									200,647	175,069	175,035
Income Taxes									69,738	59,513	54,910
Net Earnings	22,111	59,486	33,181	16,131	11,397	58,814	31,383	13,962	130,909	115,556	120,125
Valencia non-controlling interest									(14,127)	(14,521)	(14,050)
Preferred Stock Dividend Requirements of Subsidiary									(528)	(528)	(528)
Segment earnings (loss) attributable to PNMR									116,254	100,507	105,547
Gross property additions									460,658	348,039	308,909
Total Assets	5,829,325				5,500,210				5,829,325	5,500,210	5,372,583
Goodwill	278,297				278,297				278,297	278,297	278,297
PNM [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Electric Operating Revenues									1,147,914	1,116,312	1,092,264
Cost of energy									403,626	374,710	353,649
Margin									744,288	741,602	738,615
Other operating expenses									422,051	428,591	435,442
Depreciation and amortization									109,524	103,826	97,291
Operating income									212,713	209,185	205,882
Interest income									8,557	10,182	13,243
Gain on sale of First Choice											0
Other income (deductions)									12,258	11,288	13,290
Interest charges									(79,442)	(79,175)	(76,101)
Earnings before Income Taxes									154,086	151,480	156,314
Income Taxes									52,633	48,804	50,713
Net Earnings									101,453	102,676	105,601
Valencia non-controlling interest									(14,127)	(14,521)	(14,050)
Preferred Stock Dividend Requirements of Subsidiary									(528)	(528)	(528)
Segment earnings (loss) attributable to PNMR									86,798	87,627	91,023
Gross property additions									316,800	239,906	196,800
Total Assets	4,473,652				4,227,616				4,473,652	4,227,616	4,163,907
Goodwill	51,632				51,632				51,632	51,632	51,632
TNMP [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Electric Operating Revenues									287,939	271,611	250,140
Cost of energy									67,930	57,606	46,201
Margin									220,009	214,005	203,939
Other operating expenses									84,365	91,601	87,079
Depreciation and amortization									50,056	50,219	49,340
Operating income									85,588	72,185	67,520
Interest income									0	0	1
Gain on sale of First Choice											0
Other income (deductions)									2,138	1,919	2,739
Interest charges									(27,396)	(27,393)	(28,161)
Earnings before Income Taxes									60,330	46,711	42,099
Income Taxes									22,523	17,621	15,352
Net Earnings									37,807	29,090	26,747
Valencia non-controlling interest									0	0	0
Preferred Stock Dividend Requirements of Subsidiary									0	0	0
Segment earnings (loss) attributable to PNMR									37,807	29,090	26,747
Gross property additions									127,191	89,117	92,973
Total Assets	1,240,241				1,162,431				1,240,241	1,162,431	1,086,229
Goodwill	226,665				226,665				226,665	226,665	226,665
Corporate and Other [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Electric Operating Revenues									0	0	(1)
Cost of energy									0	0	0
Margin									0	0	(1)
Other operating expenses									(14,450)	(18,308)	(17,862)
Depreciation and amortization									13,054	12,836	17,542
Operating income									1,396	5,472	319
Interest income									(74)	(139)	(172)
Gain on sale of First Choice											1,012
Other income (deductions)									(2,302)	(13,575)	(7,954)
Interest charges									(12,789)	(14,880)	(16,583)
Earnings before Income Taxes									(13,769)	(23,122)	(23,378)
Income Taxes									(5,418)	(6,912)	(11,155)
Net Earnings									(8,351)	(16,210)	(12,223)
Valencia non-controlling interest									0	0	0
Preferred Stock Dividend Requirements of Subsidiary									0	0	0
Segment earnings (loss) attributable to PNMR									(8,351)	(16,210)	(12,223)
Gross property additions									16,667	19,016	19,136
Total Assets	115,432				110,163				115,432	110,163	122,447
Goodwill	$ 0				$ 0				$ 0	$ 0	$ 0

XML

Fair Value of Derivative and Other Financial Instruments, Sale of Power (Details) (Palo Verde Nuclear Generating Station Unit 3 [Member], PNMR and PNM [Member])	Dec. 31, 2014 MW
Sale of Power [Line Items]
Public Utilities, Number of Megawatts Nuclear Generation	134
Percentage of Electric Power Plant Output Sold for 2014 and 2015	100.00%
Commodity Contract [Member]
Sale of Power [Line Items]
Derivative, Average Forward Price	37

XML

Lease Commitments Narratives (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2012	Dec. 31, 2013	May 01, 2014 MW	Jan. 15, 2015	Jan. 15, 2016 MW
Lease commitments
Operating Lease, Extended Term	2 years
Operating Leases, Renewal Options After Original Lease Term	6 years
Administrative and General Expense [Member]
Lease commitments
Abandonment expense		$ (7,400,000)
Corporate Headquarters [Member]
Lease commitments
Operating Leases, Rent Expense, Net	1,900,000
Public Service Company of New Mexico [Member]
Lease commitments
Operating Leases, Renewal Options After Original Lease Term	2 years
Public Utilities, Option to Purchase Leased Capacity At Fair Value	7,700,000
Operating Leases, Rent Expense, Net	76,745,000	78,483,000	78,306,000
Public Service Company of New Mexico [Member] | Navajo Nation [Member]
Lease commitments
Operating Leases, Number of leases set to expire	0
Operating Leases, Period to expiration of the lease	5 years
Annual lease payments	6,000,000
Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station [Member]
Lease commitments
Rental Payments, Fixed renewal option period during original terms of leases	50.00%
Operating Lease, Extended Term, Notice Period to Retain Leased Assets	3 years
Operating Lease, Extended Term, Notice Period to Purchase or Renewal Options	2 years
Lease Covenant, Restriction on Conveying, Transferring, Leasing, & Dividends	5.00%
Loss Contingency, Range of Possible Loss, Portion Not Accrued	122,200,000
Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station, Unit 1 Leases [Member]
Lease commitments
Annual lease payments	33,000,000
Annual Lease Payments During Renewal Period	16,500,000
Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station, Unit 2 Leases [Member]
Lease commitments
Annual lease payments	23,700,000
Annual Lease Payments During Renewal Period	1,600,000
Leased Capacity to be Purchased				32.76
Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station, Unit 2 Leases 32.76 MW [Member]
Lease commitments
Purchase Price of Leased Asset to be paid January 15, 2016				85,200,000
Early Purchase Price of Leased Asset effective June 1, 2014				79,900,000
Early Purchase Price of Leased Asset currently in effect	81,800,000
Public Service Company of New Mexico [Member] | Administrative and General Expense [Member]
Lease commitments
Abandonment expense		(6,200,000)
Public Service Company of New Mexico [Member] | TGP Granada, LLC and its affiliate Complaint [Member]
Lease commitments
Public Utilities, Lease ownership percentage in EIP	60.00%
Operating Lease, Notice Period to Purchase Leased Assets	24 months
Public Service Company of New Mexico [Member] | Maximum [Member] | Palo Verde Nuclear Generating Station, Unit 2 Leases 32.76 MW [Member]
Lease commitments
Additional consideration for early purchase of leased asset effective June 1, 2014				5,800,000
Additional consideration for early purchase of leased asset currently effective	4,500,000
Public Service Company of New Mexico [Member] | Minimum [Member] | Palo Verde Nuclear Generating Station, Unit 2 Leases 32.76 MW [Member]
Lease commitments
Additional consideration for early purchase of leased asset effective June 1, 2014				1,200,000
Public Service Company of New Mexico [Member] | Subsequent Event [Member] | Palo Verde Nuclear Generating Station [Member]
Lease commitments
Loss Contingency, Range of Possible Loss, Portion Not Accrued					217,300,000
Public Service Company of New Mexico [Member] | Subsequent Event [Member] | Palo Verde Nuclear Generating Station, Unit 2 Leases [Member]
Lease commitments
Estimated Purchase Price of Leased Asset						78,100,000
Leased Capacity to be Purchased						31.25
Tortoise Capital Resources Corporation [Member] | TGP Granada, LLC and its affiliate Complaint [Member]
Lease commitments
Public Utilities, Lease ownership percentage in EIP	40.00%
Texas-New Mexico Power Company [Member]
Lease commitments
Operating Leases, Rent Expense, Net	3,932,000	2,871,000	2,663,000
Texas-New Mexico Power Company [Member] | Administrative and General Expense [Member]
Lease commitments
Abandonment expense		$ (1,200,000)

XML

Accumulated Other Comprehensive Income (Loss) (Tables)

12 Months Ended

Dec. 31, 2014

Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]

Schedule of Accumulated Other Comprehensive Income (Loss)

AOCI reports a measure for accumulated changes in equity that result from transactions and other economic events other than transactions with shareholders. Information regarding AOCI is as follows:

	Accumulated Other Comprehensive Income (Loss)
	Unrealized Gain on Available-for-Sale Securities			Pension Liability Adjustment			Fair Value Adjustment for Cash Flow Hedges			Total
				(In thousands)
PNMR
Balance at December 31, 2011	$	15,634		$	(82,432	)	$	(58	)	$	(66,856	)
Amounts reclassified from AOCI (pre-tax)	(37,269		)	4,611			182			(32,476		)
Income tax impact of amounts reclassified	14,755			(1,825		)	(65		)	12,865
Other OCI changes (pre-tax)	38,548			(30,084		)	(428		)	8,036
Income tax impact of other OCI changes	(15,262		)	11,910			153			(3,199		)
Net change after income taxes	772			(15,388		)	(158		)	(14,774		)
Balance at December 31, 2012	16,406			(97,820		)	(216		)	(81,630		)
Amounts reclassified from AOCI (pre-tax)	(11,956		)	6,364			207			(5,385		)
Income tax impact of amounts reclassified	4,734			(2,524		)	(73		)	2,137
Other OCI changes (pre-tax)	27,419			17,136			(279		)	44,276
Income tax impact of other OCI changes	(10,855		)	(6,781		)	98			(17,538		)
Net change after income taxes	9,342			14,195			(47		)	23,490
Balance at December 31, 2013	25,748			(83,625		)	(263		)	(58,140		)
Amounts reclassified from AOCI (pre-tax)	(13,862		)	5,152			558			(8,152		)
Income tax impact of amounts reclassified	5,461			(2,032		)	(195		)	3,234
Other OCI changes (pre-tax)	17,473			(15,282		)	(153		)	2,038
Income tax impact of other OCI changes	(6,812		)	6,024			53			(735		)
Net change after income taxes	2,260			(6,138		)	263			(3,615		)
Balance at December 31, 2014	$	28,008		$	(89,763	)	$	—		$	(61,755	)

	Accumulated Other Comprehensive Income (Loss)
	Unrealized Gain on Available-for-Sale Securities			Pension Liability Adjustment			Fair Value Adjustment for Cash Flow Hedges		Total
				(In thousands)
PNM
Balance at December 31, 2011	$	15,634		$	(82,432	)	$	—	$	(66,798	)
Amounts reclassified from AOCI (pre-tax)	(37,269		)	4,611			—		(32,658		)
Income tax impact of amounts reclassified	14,755			(1,825		)	—		12,930
Other OCI changes (pre-tax)	38,548			(30,084		)	—		8,464
Income tax impact of other OCI changes	(15,262		)	11,910			—		(3,352		)
Net change after income taxes	772			(15,388		)	—		(14,616		)
Balance at December 31, 2012	16,406			(97,820		)	—		(81,414		)
Amounts reclassified from AOCI (pre-tax)	(11,956		)	6,364			—		(5,592		)
Income tax impact of amounts reclassified	4,734			(2,524		)	—		2,210
Other OCI changes (pre-tax)	27,419			17,136			—		44,555
Income tax impact of other OCI changes	(10,855		)	(6,781		)	—		(17,636		)
Net change after income taxes	9,342			14,195			—		23,537
Balance at December 31, 2013	25,748			(83,625		)	—		(57,877		)
Amounts reclassified from AOCI (pre-tax)	(13,862		)	5,152			—		(8,710		)
Income tax impact of amounts reclassified	5,461			(2,032		)	—		3,429
Other OCI changes (pre-tax)	17,473			(15,282		)	—		2,191
Income tax impact of other OCI changes	(6,812		)	6,024			—		(788		)
Net change after income taxes	2,260			(6,138		)	—		(3,878		)
Balance at December 31, 2014	$	28,008		$	(89,763	)	$	—	$	(61,755	)

	Accumulated Other Comprehensive Income (Loss)
	Unrealized Gain on Available-for-Sale Securities		Pension Liability Adjustment		Fair Value Adjustment for Cash Flow Hedges			Total
			(In thousands)
TNMP
Balance at December 31, 2011	$	—	$	—	$	(58	)	$	(58	)
Amounts reclassified from AOCI (pre-tax)	—		—		182			182
Income tax impact of amounts reclassified	—		—		(65		)	(65		)
Other OCI changes (pre-tax)	—		—		(428		)	(428		)
Income tax impact of other OCI changes	—		—		153			153
Net change after income taxes	—		—		(158		)	(158		)
Balance at December 31, 2012	—		—		(216		)	(216		)
Amounts reclassified from AOCI (pre-tax)	—		—		207			207
Income tax impact of amounts reclassified	—		—		(73		)	(73		)
Other OCI changes (pre-tax)	—		—		(279		)	(279		)
Income tax impact of other OCI changes	—		—		98			98
Net change after income taxes	—		—		(47		)	(47		)
Balance at December 31, 2013	—		—		(263		)	(263		)
Amounts reclassified from AOCI (pre-tax)	—		—		558			558
Income tax impact of amounts reclassified	—		—		(195		)	(195		)
Other OCI changes (pre-tax)	—		—		(153		)	(153		)
Income tax impact of other OCI changes	—		—		53			53
Net change after income taxes	—		—		263			263
Balance at December 31, 2014	$	—	$	—	$	—		$	—

XML

Summary of the Business and Significant Accounting Policies

12 Months Ended

Dec. 31, 2014

Accounting Policies [Abstract]

Summary of the Business and Significant Accounting Policies

Summary of the Business and Significant Accounting Policies

Nature of Business

PNMR is an investor-owned holding company of energy and energy-related businesses. PNMR’s primary subsidiaries are PNM and TNMP. PNM is a public utility with regulated operations primarily engaged in the generation, transmission, and distribution of electricity. TNMP is a wholly owned subsidiary of TNP, which is a holding company that is wholly owned by PNMR. TNMP provides regulated transmission and distribution services in Texas. PNMR’s common stock trades on the New York Stock Exchange under the symbol PNM.

Financial Statement Preparation and Presentation

The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could ultimately differ from those estimated.

The Notes to Consolidated Financial Statements include disclosures for PNMR, PNM, and TNMP. For discussion purposes, this report uses the term “Company” when discussing matters of common applicability to PNMR, PNM, and TNMP. Discussions regarding only PNMR, PNM, or TNMP are so indicated.

Certain amounts in the 2013 and 2012 Consolidated Financial Statements and Notes thereto have been reclassified to conform to the 2014 financial statement presentation.

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

Principles of Consolidation

The Consolidated Financial Statements of each of PNMR, PNM, and TNMP include their accounts and those of subsidiaries in which that entity owns a majority voting interest. PNM also consolidates the PVNGS Capital Trust and Valencia (Note 9). 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.

PNMR shared services’ administrative and general expenses, which represent costs that are primarily driven by corporate level activities, are charged to the business segments. These services are billed at cost. Other significant intercompany transactions between PNMR, PNM, and TNMP include interest and income tax sharing payments, as well as equity transactions. All intercompany transactions and balances have been eliminated. See Note 18.

Accounting for the Effects of Certain Types of Regulation

The Company maintains its accounting records in accordance with the uniform system of accounts prescribed by FERC and adopted by the NMPRC and PUCT.

Certain of the Company’s operations are regulated by the NMPRC, PUCT, and FERC and the provisions of GAAP for rate-regulated enterprises are applied to the regulated operations. Regulators may assign costs to accounting periods that differ from accounting methods applied by non-regulated utilities.  When it is probable that regulators will permit recovery of costs through future rates, costs that otherwise would be expensed are deferred as regulatory assets.  Likewise, regulatory liabilities are recognized when it is probable that regulators will require refunds through future rates or when revenue is collected for expenditures that have not yet been incurred.  Regulatory assets and liabilities are amortized into earnings over the authorized recovery period. Accordingly, the Company has deferred certain costs and recorded certain liabilities pursuant to the rate actions of the NMPRC, PUCT, and FERC. Information on regulatory assets and regulatory liabilities is contained in Note 4.

In some circumstances, regulators allow a requested increase in rates to be implemented, subject to refund, before the regulatory process has been completed and a decision rendered by the regulator. When this occurs, the Company assesses the possible outcomes of the rate proceeding. The Company records a provision for refund to the extent the amounts being collected, subject to refund, exceed the amount the Company determines is probable of ultimately being allowed by the regulator.

Competition Transition Charge

In connection with the adoption of Senate Bill 7 by the Texas Legislature in 1999 that deregulated electric utilities operating within ERCOT, TNMP was allowed to recover its stranded costs through the CTC and to also recover a carrying charge on the CTC. The amounts yet to be collect are recorded as regulatory assets by TNMP. TNMP’s calculation of allowable carrying charges on stranded costs recoverable from its transmission and distribution customers is based on a Texas Supreme Court ruling and the PUCT’s application of that ruling.

Cash and Cash Equivalents

Investments in highly liquid investments with original maturities of three months or less at the date of purchase are considered cash equivalents.

Utility Plant

Utility plant is stated at cost, which includes capitalized payroll-related costs such as taxes, pension, and other fringe benefits, administrative costs, and AFUDC where authorized by rate regulation.

Repairs, including major maintenance activities, and minor replacements of property are expensed when incurred, except as required by regulators for ratemaking purposes. Major replacements are charged to utility plant. Gains or losses resulting from retirements or other dispositions of regulated property in the normal course of business are credited or charged to accumulated depreciation.

Allowance for Funds Used During Construction

As provided by the FERC uniform systems of accounts, AFUDC is charged to regulated utility plant for construction projects. This allowance is a non-cash item designed to enable a utility to capitalize financing costs during periods of construction of property subject to rate regulation. It represents the cost of borrowed funds (allowance for borrowed funds used during construction) and a return on other funds (allowance for equity funds used during construction). The allowance for borrowed funds used during construction is recorded in interest charges and the allowance for equity funds used during construction is recorded in other income on the Consolidated Statements of Earnings.

For the years ended December 31, 2014, 2013, and 2012, PNM recorded $4.2 million, $3.3 million, and $3.5 million of allowance for borrowed funds used during construction and $5.6 million, $4.4 million, and $3.8 million of allowance for equity funds used during construction. TNMP recorded $0.5 million, $0.4 million, and $0.7 million of allowance for borrowed funds used during construction and zero, zero, and $0.6 million of allowance for equity funds used during construction.

Capitalized Interest

The Company capitalizes interest on its construction projects and major computer software projects not subject to the computation of AFUDC. Interest was capitalized at the overall weighted average borrowing rate of 6.6%, 6.9%, and 6.6% for 2014, 2013, and 2012. In 2014, 2013, and 2012, capitalized interest was $1.6 million, $1.5 million, and $1.2 million for PNMR consolidated; $1.1 million, $1.1 million, and $0.8 million for PNM; and $0.1 million, zero, and zero for TNMP.

Materials, Supplies, and Fuel Stock

Materials and supplies relate to transmission, distribution, and generating assets. Materials and supplies are charged to inventory when purchased and are expensed or capitalized as appropriate when issued. Materials and supplies are valued using an average costing method.

Coal is valued using a rolling weighted average costing method that is updated based on the current period cost per ton. Periodic aerial surveys are performed on the coal piles and adjustments are made.

Inventories consisted of the following at December 31:

	PNMR				PNM				TNMP
	2014		2013		2014		2013		2014		2013
	(In thousands)
Coal	$	17,525	$	24,872	$	17,525	$	24,872	$	—	$	—
Materials and supplies	46,103		42,351		43,334		39,648		2,769		2,703
	$	63,628	$	67,223	$	60,859	$	64,520	$	2,769	$	2,703

Investments

In 1985 and 1986, PNM entered into eleven operating leases for interests in certain PVNGS generation facilities (Note 7). The 10.3% and 10.15% lessor notes that were issued by the owners of the assets subject to these leases were subsequently purchased and held by the PVNGS Capital Trust, which is consolidated by PNM. Eight leases continue and are classified as operating leases. The PVNGS Capital Trust held certain of the lessor notes to their maturity in January 2015 and intends to hold the other lessor notes until their maturity in 2016. The PVNGS lessor notes are carried at amortized cost. Similarly, in 1985, PNM entered into two operating leases for the EIP transmission line for which the owners had issued lessor notes. In 2003, PNM acquired a 60% ownership interest in the EIP, collapsing the lease relating to it. In 2004, PNM purchased the outstanding lessor note relating to the remaining 40% interest. The remaining EIP lessor note bore interest at 10.25% and matured in 2012.

PNM holds investment securities in the NDT for the purpose of funding its share of the decommissioning costs of PVNGS and, beginning in August 2012, a trust for PNM’s share of post-term reclamation costs related to the coal mines serving SJGS (Note 16). All of these investments are classified as available-for-sale. PNM evaluates the securities for impairment on an on-going basis. Since third party investment managers have sole discretion over the purchase and sales of the securities, PNM records a realized loss as an impairment for any security that has a market value that is less than cost at the end of each quarter. For the years ended December 31, 2014, 2013, and 2012, PNM recorded impairment losses on the available-for-sale securities held in the NDT and coal mine reclamation trust of $4.8 million, $3.5 million, and $4.8 million. No gains or losses are deferred as regulatory assets or liabilities. Unrealized gains on these investments, net of related tax effects, are included in OCI and AOCI. The available-for-sale securities are primarily comprised of international, United States, state, and municipal government obligations and corporate debt and equity securities. All investments are held in PNM’s name and are in the custody of major financial institutions. The specific identification method is used to determine the cost of securities disposed of, with realized gains and losses reflected in other income and deductions.

Goodwill

Under GAAP, the Company does not amortize goodwill. Goodwill is evaluated for impairment annually, or more frequently if events and circumstances indicate that the goodwill might be impaired. See Note 21.

Asset Impairment

Tangible long-lived assets are evaluated in relation to the estimated future undiscounted cash flows to assess recoverability when events and circumstances indicate that the assets might be impaired.

Revenue Recognition

Electric operating revenues are recorded in the period of energy delivery, which includes estimated amounts for service rendered but unbilled at the end of each accounting period. The determination of the energy sales to individual customers is based on the reading of their meters, which occurs on a systematic basis throughout the month. At the end of each month, amounts of energy delivered to customers since the date of the last meter reading and the corresponding unbilled revenue are estimated. Unbilled electric revenue is estimated based on the daily generation volumes, estimated customer usage by class, weather factors, line losses, and applicable customer rates reflecting historical trends and experience.

PNM’s wholesale electricity sales are recorded as electric operating revenues and the wholesale electricity purchases are recorded as costs of energy sold. In accordance with GAAP, derivative contracts that are net settled or “booked-out” are recorded net in earnings. A book-out is the planned or unplanned netting of off-setting purchase and sale transactions. A book-out is a transmission mechanism to reduce congestion on the transmission system or administrative burden. For accounting purposes, a book-out is the recording of net revenues upon the settlement of a derivative contract.

Unrealized gains and losses on contracts that do not qualify for the normal purchases or normal sales exception or are not designated for hedge accounting are classified as economic hedges. Economic hedges are defined as derivative instruments, including long-term power and fuel supply agreements, used to hedge generation assets and purchased power costs. Changes in the fair value of economic hedges are reflected in results of operations, with changes related to economic hedges on sales included in operating revenues and changes related to economic hedges on purchases included in cost of energy sold.

Accounts Receivable and Allowance for Uncollectible Accounts

Accounts receivable consists primarily of trade receivables from customers. In the normal course of business, credit is extended to customers on a short-term basis. The Company calculates the allowance for uncollectible accounts based on historical experience and estimated default rates. The accounts receivable balances are reviewed monthly and adjustments to the allowance for uncollectible accounts and bad debt expense are made as necessary. Amounts that are deemed uncollectible are written off.

Depreciation and Amortization

PNM’s provision for depreciation and amortization of utility plant, other than nuclear fuel, is based upon composite straight-line rates approved by the NMPRC. Amortization of nuclear fuel is based on units-of-production. TNMP’s provision for depreciation and amortization of utility plant is based upon straight-line rates approved by the PUCT. Depreciation of non-utility property is computed based on the straight-line method. The provision for depreciation of certain equipment is allocated between operating expenses and construction projects based on the use of the equipment. Average straight-line rates used were as follows:

	Year ended December 31
	2014		2013		2012
PNM
Electric plant	2.26	%	2.27	%	2.25	%
Common, intangible, and general plant	4.64	%	4.87	%	5.35	%
TNMP	3.59	%	3.66	%	3.56	%

Amortization of Debt Acquisition Costs

Discount, premium, and expense related to the issuance of long-term debt are amortized over the lives of the respective issues. Gains and losses incurred upon the early retirement of long-term debt are recognized in other income or other deductions, except for amounts attributable to NMPRC, FERC, or PUCT regulation, which are recorded as regulatory assets or liabilities and amortized over the lives of the respective issues.

Derivatives

The Company records derivative instruments, including energy contracts, other than those designated as normal purchases or normal sales, in the balance sheet as either an asset or liability measured at their fair value. GAAP requires that changes in the derivatives’ fair value be recognized currently in earnings unless specific hedge accounting or normal purchase or normal sale criteria are met. Normal purchases and normal sales are not marked to market and are reflected in results of operations when the underlying transactions settle. For qualifying hedges, an entity must formally document, designate, and assess the effectiveness of transactions that receive hedge accounting. GAAP provides that the effective portion of the gain or loss on a derivative instrument designated and qualifying as a cash flow hedging instrument be reported as a component of AOCI and be reclassified into earnings in the period during which the hedged forecasted transaction affects earnings. The results of hedge ineffectiveness and the portion of the change in fair value of a derivative that an entity has chosen to exclude from hedge effectiveness are required to be presented in current earnings. See Note 8.

The Company treats all forward electric purchases and sales contracts subject to unplanned netting or book-out by the transmission provider as derivative instruments subject to mark-to-market accounting, unless the contract qualifies for the normal exception by meeting the definition of a capacity contract. Under this definition, the contract cannot permit net settlement, the seller must have the resources to serve the contract, and the buyer must be a load serving entity. GAAP provides guidance on whether realized gains and losses on derivative contracts not held for trading purposes should be reported on a net or gross basis and concludes such classification is a matter of judgment that depends on the relevant facts and circumstances. 

Decommissioning and Reclamation Costs

PNM owns and leases nuclear and fossil-fuel generating facilities. In accordance with GAAP, PNM is only required to recognize and measure decommissioning liabilities for tangible long-lived assets for which a legal obligation exists. Nuclear decommissioning costs and related accruals are based on periodic site-specific estimates of the costs for removing all radioactive and other structures at PVNGS and are dependent upon numerous assumptions, including estimates of future decommissioning costs at current price levels, inflation rates, and discount rates. PNM’s accruals for PVNGS Units 1, 2, and 3, including portions held under leases, have been made based on such estimates, the guidelines of the NRC, and the extended PVNGS license periods. PVNGS Units 1 and 2 are included in PNM’s retail rates while PVNGS Unit 3 is currently excluded. PNM collects a provision for ultimate decommissioning of PVNGS Units 1 and 2 and its fossil-fueled generation facilities in its rates and recognizes a corresponding expense and liability for these amounts. See Note 15 and Note 16.

In connection with both the SJGS coal agreement and the Four Corners fuel agreement, the owners are required to reimburse the mining companies for the cost of contemporaneous reclamation, as well as the costs for final reclamation of the coal mines. The reclamation costs are based on periodic site-specific studies that estimate the costs to be incurred in the future and are dependent upon numerous assumptions, including estimates of future reclamation costs at current price levels, inflation rates, and discount rates. PNM considers the contemporaneous reclamation costs part of the cost of its delivered coal costs. See Note 16 for a discussion of the final reclamation costs.

Environmental Costs

The normal operations of the Company involve activities and substances that expose the Company to potential liabilities under laws and regulations protecting the environment. Liabilities under these laws and regulations can be material and in some instances may be imposed without regard to fault, or may be imposed for past acts, even though the past acts may have been lawful at the time they occurred.

The Company records its environmental liabilities when site assessments or remedial actions are probable and a range of reasonably likely cleanup costs can be estimated. The Company reviews its sites and measures the liability by assessing a range of reasonably likely costs for each identified site using currently available information and the probable level of involvement and financial condition of other potentially responsible parties. These estimates are based on assumptions regarding the costs for site investigations, remediation, operations and maintenance, monitoring, and site closure. The ultimate cost to clean up the Company’s identified sites may vary from its recorded liability due to numerous uncertainties inherent in the estimation process. Amounts recorded for environmental expense in the years ended December 31, 2014, 2013, and 2012, as well as the amounts of environmental liabilities at December 31, 2014 and 2013 were insignificant.

Pension and Other Postretirement Benefits

See Note 12 for a discussion of pension and postretirement benefits expense, including a discussion of the actuarial assumptions.

Stock-Based Compensation

See Note 13 for a discussion of stock-based compensation expense.

Income Taxes

Income taxes are recognized using the asset and liability method of accounting for income taxes. Deferred tax assets and liabilities are recognized for the estimated future tax consequences attributable to differences between the financial statement carrying value of existing assets and liabilities and their respective tax basis. Current NMPRC, FERC, and PUCT approved rates include the tax effects of the majority of these differences. GAAP requires that rate-regulated enterprises record deferred income taxes for temporary differences accorded flow-through treatment at the direction of a regulatory commission. The resulting deferred tax assets and liabilities are recorded at the expected cash flow to be reflected in future rates. Because the NMPRC, FERC, and the PUCT have consistently permitted the recovery of tax effects previously flowed-through earnings, the Company has established regulatory liabilities and assets offsetting such deferred tax assets and liabilities. The Company recognizes only the impact of tax positions that, based on their merits, are more likely than not to be sustained upon an IRS audit. The Company defers investment tax credits related to rate regulated assets and amortizes them over the estimated useful lives of those assets. See Note 11.

The Company makes an estimate of its anticipated effective tax rate for the year as of the end of each quarterly period within its fiscal year. Year-to-date income tax expense is then calculated by applying the anticipated annual effective tax rate to year-to-date earnings before taxes, which includes the earnings attributable to the Valencia non-controlling interest. GAAP also provides that certain unusual or infrequently occurring items, as well as adjustments due to enactment of new tax laws, be excluded from the estimated annual effective tax rate calculation.

Excise Taxes

The Company pays certain fees or taxes which are either considered to be an excise tax or similar to an excise tax. Substantially all of these taxes are recorded on a net basis in the Consolidated Statements of Earnings.

New Accounting Pronouncements

Information concerning recently issued accounting pronouncements that have not been adopted by the Company is presented below.

Accounting Standards Update 2014-09 – Revenue from Contracts with Customers (Topic 606)

On May 28, 2014, the FASB issued ASU No. 2014-09. The core principle of the guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The new standard will replace most existing revenue recognition guidance in GAAP when it becomes effective. The new standard is effective for the Company beginning on January 1, 2017. Early adoption is not permitted. The standard permits the use of either the retrospective or cumulative effect transition method. The Company is analyzing the impacts this new standard will have on its consolidated financial statements and related disclosures. The Company has not yet selected a transition method nor has it determined the effect of the standard on its ongoing financial reporting.

Accounting Standards Update 2014-15 – Presentation of Financial Statements – Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern

On August 27, 2014, the FASB issued ASU No. 2014-15, which requires management to evaluate whether there is substantial doubt about a company’s ability to continue as a going concern in connection with the preparation of financial statements for each annual and interim reporting period. Disclosure requirements associated with management’s evaluation are also outlined in the new guidance. The new standard is effective for the Company for reporting periods ending after December 15, 2016, with early adoption permitted. The Company is in the process of analyzing the impacts of this new standard.

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Lease Commitments Schedule of Rent Expense (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
PNMR [Member]
Operating lease expense [Line Items]
Operating Leases, Rent Expense, Net	$ 82,756	$ 82,882	$ 84,794
Public Service Company of New Mexico [Member]
Operating lease expense [Line Items]
Operating Leases, Rent Expense, Net	76,745	78,306	78,483
Texas-New Mexico Power Company [Member]
Operating lease expense [Line Items]
Operating Leases, Rent Expense, Net	$ 3,932	$ 2,663	$ 2,871

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Stock-Based Compensation Plans (Tables)

12 Months Ended

Dec. 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 provides additional information concerning stock options, and restricted stock activity including performance-based and market-based shares:

	Year Ended December 31,
Restricted Stock	2014		2013		2012
Weighted-average grant date fair value	$	21.27	$	20.03	$	16.75
Total fair value of restricted shares that vested (in thousands)	$	4,933	$	4,395	$	5,099
Stock Options
Weighted-average grant date fair value of options granted	$	—	$	—	$	—
Total fair value of options that vested (in thousands)	$	—	$	625	$	1,054
Total intrinsic value of options exercised (in thousands)	$	2,473	$	2,721	$	6,356

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

	Year Ended December 31,
Restricted Shares and Performance-Based Shares	2014			2013			2012
Expected quarterly dividends per share	$	0.185		$	0.165		$	0.145
Risk-free interest rate	0.62		%	0.34		%	1.22		%
Market-Based Shares
Dividend yield	2.82		%	2.86		%	3.45		%
Expected volatility	25.11		%	25.11		%	43.98		%
Risk-free interest rate	0.64		%	0.36		%	1.04		%

The following table summarizes activity in restricted stock awards, including performance-based and market-based shares, and stock options:

	Restricted Stock				Stock Options
	Shares		Weighted-Average Grant Date Fair Value		Shares		Weighted Average Exercise Price
Outstanding at December 31, 2013	315,305		$	17.87	1,343,666		$	20.63
Granted	242,164		$	21.27	—		$	—
Exercised	(295,423	)	$	16.70	(345,426	)	$	20.04
Forfeited	(3,276	)	$	22.46	(17,151	)	$	26.43
Expired	—		—		(60,584	)	$	27.98
Outstanding at December 31, 2014	258,770		$	22.31	920,505		$	20.39

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Quarterly Operating Results (Unaudited)

12 Months Ended

Dec. 31, 2014

Quarterly Financial Data [Abstract]

Quarterly Operating Results (Unaudited)

Quarterly Operating Results (Unaudited)

Unaudited operating results by quarters for 2014 and 2013 are presented below. In the opinion of management of the Company, all adjustments (consisting of normal recurring accruals) necessary for a fair statement of the results of operations for such periods have been included.

	Quarter Ended
	March 31		June 30		September 30		December 31
	(In thousands, except per share amounts)
PNMR
2014
Operating revenues	$	328,897	$	346,160	$	413,951	$	346,845
Operating income	48,753		71,296		116,799		62,849
Net earnings	16,131		33,181		59,486		22,111
Net earnings attributable to PNMR	12,468		29,141		55,653		18,992
Net Earnings Attributable to PNMR per Common Share:
Basic	0.16		0.37		0.70		0.24
Diluted	0.16		0.36		0.69		0.24
2013
Operating revenues	$	317,665	$	347,599	$	399,730	$	322,929
Operating income	50,704		77,867		117,739		40,532
Net earnings	13,962		31,383		58,814		11,397
Net earnings attributable to PNMR	10,626		27,678		54,555		7,648
Net Earnings Attributable to PNMR per Common Share:
Basic	0.13		0.35		0.68		0.10
Diluted	0.13		0.34		0.68		0.10
PNM
2014
Operating revenues	$	262,736	$	275,704	$	334,993	$	274,481
Operating income	31,304		49,806		90,615		40,988
Net earnings	11,205		24,254		49,052		16,942
Net earnings attributable to PNM	7,674		20,346		45,351		13,955
2013
Operating revenues	$	257,894	$	279,690	$	326,026	$	252,702
Operating income	37,239		58,302		95,217		18,427
Net earnings	14,773		29,697		51,950		6,256
Net earnings attributable to PNM	11,569		26,124		47,823		2,639
TNMP
2014
Operating revenues	$	66,161	$	70,456	$	78,958	$	72,364
Operating income	17,262		21,265		25,873		21,188
Net earnings	6,803		9,534		12,355		9,115
2013
Operating revenues	$	59,771	$	67,909	$	73,704	$	70,227
Operating income	13,054		19,667		22,254		17,210
Net earnings	3,726		8,339		10,106		6,919

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Goodwill; Impairments

12 Months Ended

Dec. 31, 2014

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill; Impairments

Goodwill; Impairments

The excess purchase price over the fair value of the assets acquired and the liabilities assumed by PNMR for its 2005 acquisition of TNP was recorded as goodwill and was pushed down to the businesses acquired. In 2007, the TNMP assets that were included in its New Mexico operations, including goodwill, were transferred to PNM.

GAAP requires the Company to evaluate its goodwill for impairment annually at the reporting unit level or more frequently if circumstances indicate that the goodwill may be impaired. The Company evaluates goodwill impairment as of April 1st of each year. PNMR’s reporting units that have goodwill are PNM and TNMP. Application of the impairment test requires judgment, including the identification of reporting units, assignment of assets and liabilities to reporting units, and determination of the fair value of each reporting unit.

GAAP provides that in certain circumstances an entity may perform a qualitative analysis to conclude that the goodwill of a reporting unit is not impaired. Under a qualitative assessment an entity considers macroeconomic conditions, industry and market considerations, cost factors, overall financial performance, other relevant entity-specific events affecting a reporting unit, as well as whether a sustained decrease (both absolute and relative to its peers) in share price had occurred. An entity considers the extent to which each of the adverse events and circumstances identified could affect the comparison of a reporting unit’s fair value with its carrying amount. An entity places more weight on the events and circumstances that most affect a reporting unit’s fair value or the carrying amount of its net assets. An entity also considers positive and mitigating events and circumstances that may affect its determination of whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount. An entity evaluates, on the basis of the weight of evidence, the significance of all identified events and circumstances in determining whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount. If, after assessing the totality of events or circumstances, an entity determines that it is not more likely than not that the fair value of a reporting unit is less than its carrying amount, a quantitative analysis is not required.

In other circumstances, an entity may perform a quantitative analysis to reach the conclusion regarding impairment with respect to a reporting unit. The first step of the quantitative impairment test requires an entity to compare the fair value of the reporting unit with its carrying value, including goodwill. If as a result of this analysis, the entity concludes there is an indication of impairment in a reporting unit having goodwill, the entity is required to perform the second step of the impairment analysis, determining the amount of goodwill impairment to be recorded. The amount is calculated by comparing the implied fair value of the goodwill to its carrying amount. This exercise requires the entity to allocate the fair value determined in step one to the individual assets and liabilities of the reporting unit. Any remaining fair value would be the implied fair value of goodwill on the testing date. To the extent the recorded amount of goodwill of a reporting unit exceeds the implied fair value determined in step two, an impairment loss would be reflected in results of operations.

An entity may choose to perform a quantitative analysis without performing a qualitative analysis and may perform a qualitative analysis for certain reporting units, but a quantitative analysis for others. Prior to 2013, the Company performed qualitative analyses for all reporting units having goodwill. For the annual evaluations performed as of April 1, 2014 and 2013, PNMR utilized a qualitative analysis for the TNMP reporting unit and a quantitative analysis for the PNM reporting unit.

For the PNM reporting unit, a discounted cash flow methodology was primarily used in the quantitative analysis to estimate the fair value of the reporting unit. This analysis requires significant judgments, including estimation of future cash flows, which is dependent on internal forecasts, estimation of long-term growth rates for the business, and determination of appropriate weighted average cost of capital for each reporting unit. Changes in these estimates and assumptions could materially affect the determination of fair value and the conclusion of impairment.

The April 1, 2014 and 2013 quantitative evaluations indicated the fair value of the PNM reporting unit, which has goodwill of $51.6 million, exceeded its carrying value by approximately 30% and 27%. An increase of 0.5% in the expected return on equity capital utilized in discounting the forecasted cash flows, would have reduced the excess of PNM’s fair value over carrying value to approximately 23% and 20% at April 1, 2014 and 2013. The 2014 and 2013 qualitative analysis for the TNMP reporting unit, which has goodwill of $226.7 million, included the consideration of various reporting unit specific factors as well as industry and macroeconomic factors to determine whether these factors were reasonably likely to have a material impact on the fair value of the reporting unit. Factors considered included the results of the April 1, 2012 quantitative analysis, which indicated that fair value exceeded carrying value of the reporting unit by approximately 26%, current and long-term forecasted financial results, regulatory environment, credit rating, interest rate environment, absolute and relative price of PNMR’s common stock, and operating strategy. TNMP believes it is operating within a generally favorable regulatory environment, its historical and forecasted financial results are positive, and its credit is perceived positively. Based on the analysis of the relevant factors, PNMR concluded that it is more likely than not that the fair value of the TNMP reporting unit exceeds its carrying value. The annual evaluations performed as of April 1, 2014 and 2013 did not indicate impairments of the goodwill of any of PNMR’s reporting units. Since the April 1, 2014 annual evaluation, there have been no indications that the fair values of the reporting units with recorded goodwill have decreased below the carrying values.

Prior annual evaluations have not indicated impairments of any of PNMR’s reporting units, except in 2008. During 2008, the market capitalization of PNMR’s common stock was significantly below book value. In addition, First Choice, a PNMR reporting unit that was sold in 2011, was significantly impacted by depressed economic conditions and changes in the market in which it operated. As a result, goodwill impairments of $51.1 million for PNM, $34.5 million for TNMP, and an aggregate of $174.4 million for PNMR were recorded in 2008. Since 2008, the price of PNMR’s common stock has increased, improving the relationship between PNMR’s market capitalization and book value. In addition, improved regulatory treatment has been experienced by PNM in New Mexico and by TNMP in Texas. These factors resulted in more predictable earnings and increased fair values of the reporting units. Since 2008, the annual evaluations have not indicated that the fair values of the reporting units with recorded goodwill have decreased below their carrying values.

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Goodwill; Impairments (Details) (USD $)	12 Months Ended
	Dec. 31, 2008	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Apr. 01, 2014	Apr. 01, 2013	Apr. 01, 2012
Schedule of Goodwill and Other Intangible Assets [Line Items]
Goodwill		$ 278,297,000	$ 278,297,000	$ 278,297,000
Goodwill, Impairment Loss	174,400,000
Public Service Company of New Mexico [Member]
Schedule of Goodwill and Other Intangible Assets [Line Items]
Goodwill		51,600,000	51,600,000
Reporting Unit, Percentage of Fair Value in Excess of Carrying Amount					30.00%	27.00%
Goodwill, Reporting Unit, Sensitivity analysis, Percentage Increase in Expected Return on Equity					0.50%
Goodwill, Reporting Unit, Sensitivity analysis, Reduced Percentage of Fair Value in Excess of Carrying Value					23.00%	20.00%
Goodwill, Impairment Loss	51,100,000
Texas-New Mexico Power Company [Member]
Schedule of Goodwill and Other Intangible Assets [Line Items]
Goodwill		226,700,000	226,700,000
Reporting Unit, Percentage of Fair Value in Excess of Carrying Amount							26.00%
Goodwill, Impairment Loss	$ 34,500,000

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Stockholders' Equity (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Class of Stock [Line Items]
Preferred stock, cumulative shares authorized (in shares)	10,000,000
Texas-New Mexico Power Company [Member]
Class of Stock [Line Items]
Equity contribution from parent		$ 13,800,000
Amount available for dividend distribution without prior approval from regulators or financial counterparties	203,000,000
Preferred stock, cumulative shares authorized (in shares)	1,000,000
Public Service Company of New Mexico [Member]
Class of Stock [Line Items]
Amount available for dividend distribution without prior approval from regulators or financial counterparties	223,000,000
Preferred stock, dividend rate (as a percent)	4.58%
Preferred stock, redemption percent (as a percent)	102.00%
Preferred Stock, Shares Outstanding	115,293	115,293
Preferred stock, cumulative shares authorized (in shares)	10,000,000	10,000,000
PNMR and TNMP [Member]
Class of Stock [Line Items]
Preferred Stock, Shares Outstanding	0
Affiliated Entity [Member] | Texas-New Mexico Power Company [Member]
Class of Stock [Line Items]
Cash dividends paid to parent company by consolidated subsidiaries	16,300,000	3,700,000	26,000,000
Affiliated Entity [Member] | Public Service Company of New Mexico [Member]
Class of Stock [Line Items]
Cash dividends paid to parent company by consolidated subsidiaries	$ 30,300,000	$ 155,000,000	$ 34,400,000
Line of Credit [Member] | Texas-New Mexico Power Company [Member]
Class of Stock [Line Items]
Ratio of debt to capital, maximum (as a percent)	65.00%

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Construction Program and Jointly-Owned Electric Generating Plants Schedule of Jointly Owned Utility Plants (Tables)

12 Months Ended

Dec. 31, 2014

Construction Program and Jointly-Owned Electric Generating Plants [Abstract]

Schedule of Jointly Owned Utility Plants

At December 31, 2014, PNM’s interests and investments in jointly-owned generating facilities are:

Station (Fuel Type)	Plant in Service		Accumulated Depreciation			Construction Work in Progress			Composite Interest
	(In thousands)
SJGS (Coal)	$	1,009,378	$	(423,364	)	$	25,551		46.30	%
PVNGS (Nuclear) (1)	$	533,702	$	(152,273	)	$	42,334		10.20	%
Four Corners Units 4 and 5 (Coal)	$	162,111	$	(101,007	)	$	8,253		13.00	%
Luna (Gas)	$	66,169	$	(20,297	)	$	(136	)	33.33	%

⁽¹⁾  Includes interest in PVNGS Unit 3, interest in common facilities for all PVNGS units, and owned interests in PVNGS Units 1 and 2.

Summary of budgeted construction expenditures

An unaudited summary of the budgeted construction expenditures, including expenditures for jointly-owned projects, and nuclear fuel, is as follows:

	2015		2016		2017		2018		2019		Total
					(In millions)
PNM	$	423.9	$	402.3	$	334.8	$	180.6	$	260.3	$	1,601.9
TNMP	121.3		92.8		93.3		105.9		105.0		518.3
Corporate and Other	24.0		19.3		15.4		13.7		14.7		87.1
Total PNMR	$	569.2	$	514.4	$	443.5	$	300.2	$	380.0	$	2,207.3

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Schedule I - Condensed Financial Information of Parent Company

12 Months Ended

Dec. 31, 2014

Condensed Financial Information of Parent Company Only Disclosure [Abstract]

Schedule I - Condensed Financial Information of Parent Company

SCHEDULE I

PNM RESOURCES, INC.

CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY

STATEMENTS OF EARNINGS

	Year ended December 31,
	2014			2013			2012
	(In thousands)
Operating Revenues	$	—		$	—		$	—
Operating Expenses	650			941			3,287
Operating income (loss)	(650		)	(941		)	(3,287		)
Other Income and Deductions:
Equity in earnings of subsidiaries	124,543			116,634			117,900
Other income	622			769			670
Other deductions	(13,650		)	(22,825		)	(20,904		)
Net other income (deductions)	111,515			94,578			97,666
Earnings Before Income Taxes	110,865			93,637			94,379
Income Tax Expense (Benefit)	(5,389		)	(6,870		)	(11,168		)
Net Earnings	$	116,254		$	100,507		$	105,547

SCHEDULE I

PNM RESOURCES, INC.

CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY

STATEMENTS OF CASH FLOWS

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Cash Flows From Operating Activities:
Net earnings	$	116,254		$	100,507		$	105,547
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	680			4,192			5,000
Deferred income tax expense	(69,442		)	(51,820		)	(46,632		)
Equity in (earnings) of subsidiaries	(124,543		)	(116,634		)	(117,900		)
Loss on reacquired debt	—			3,253			—
Stock based compensation expense	5,931			5,320			3,585
Changes in certain assets and liabilities:
Other current assets	22,955			28,460			(43,638		)
Other assets	51,644			46,558			34,096
Accounts payable	(88		)	620			8
Accrued interest and taxes	(7,683		)	(9,266		)	(28,855		)
Other current liabilities	(1,668		)	(146		)	3,876
Other liabilities	28,704			(27,756		)	(29,601		)
Net cash flows from operating activities	22,744			(16,712		)	(114,514		)
Cash Flows From Investing Activities:
Utility plant additions	(474		)	(960		)	(7,524		)
Investments in subsidiaries	—			(13,800		)	—
Cash dividends from subsidiaries	46,599			158,772			61,406
Net cash flows from investing activities	46,125			144,012			53,882
Cash Flows From Financing Activities:
Short-term borrowings (repayments), net	600			(37,600		)	120,900
Repayment of long-term debt	—			(29,468		)	(2,387		)
Proceeds from stock option exercise	6,999			4,618			11,684
Purchases to satisfy awards of common stock	(17,319		)	(13,807		)	(25,168		)
Dividends paid	(58,940		)	(50,980		)	(44,609		)
Other, net	81			—			—
Net cash flows from financing activities	(68,579		)	(127,237		)	60,420
Change in Cash and Cash Equivalents	290			63			(212		)
Cash and Cash Equivalents at Beginning of Period	92			29			241
Cash and Cash Equivalents at End of Period	$	382		$	92		$	29
Supplemental Cash Flow Disclosures:
Interest paid	$	12,152		$	14,510		$	15,007
Income taxes paid (refunded), net	$	(2,014	)	$	22,378		$	1,501

SCHEDULE I

PNM RESOURCES, INC.

CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY

BALANCE SHEETS

	December 31,
	2014			2013
	(In thousands)
Assets
Cash and cash equivalents	$	382		$	92
Intercompany receivables	107,619			136,387
Income taxes receivable	29			14,989
Other, net	8,115			8,544
Total current assets	116,145			160,012
Property, plant and equipment, net of accumulated depreciation of $10,251 and $9,167	27,076			26,601
Investment in subsidiaries	1,757,650			1,683,321
Other long-term assets	70,939			53,892
Total long-term assets	1,855,665			1,763,814
	$	1,971,810		$	1,923,826
Liabilities and Stockholders’ Equity
Short-term debt	$	100,600		$	100,000
Short-term debt-affiliate	8,819			8,819
Current maturities of long-term debt	118,766			—
Accrued interest and taxes	2,816			2,797
Other current liabilities	16,320			16,876
Total current liabilities	247,321			128,492
Long-term debt	—			118,766
Other long-term liabilities	2,943			2,999
Total liabilities	250,264			250,257
Common stock (no par value; 120,000,000 shares authorized; issued and outstanding 79,653,624 shares)	1,173,845			1,178,369
Accumulated other comprehensive income (loss), net of tax	(61,755		)	(58,140		)
Retained earnings	609,456			553,340
Total common stockholders’ equity	1,721,546			1,673,569
	$	1,971,810		$	1,923,826

See Notes 6, 7, 14, and 16 for information regarding commitments, contingencies, and maturities of long-term debt.

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Schedule II - Valuation and Qualifying Accounts

12 Months Ended

Dec. 31, 2014

Valuation and Qualifying Accounts [Abstract]

Schedule II - Valuation and Qualifying Accounts

SCHEDULE II

PNM RESOURCES, INC. AND SUBSIDIARIES

VALUATION AND QUALIFYING ACCOUNTS

			Additions				Deductions
Description	Balance at beginning of year		Charged to costs and expenses		Charged to other accounts		Write-offs and other		Balance at end of year
			(In thousands)
Allowance for doubtful accounts, year ended December 31:
2012	$	1,778	$	3,367	$	—	$	3,394	$	1,751
2013	$	1,751	$	2,849	$	—	$	3,177	$	1,423
2014	$	1,423	$	3,267	$	—	$	3,224	$	1,466

SCHEDULE II

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARY

A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC.

VALUATION AND QUALIFYING ACCOUNTS

			Additions				Deductions
Description	Balance at beginning of year		Charged to costs and expenses		Charged to other accounts		Write-offs		Balance at end of year
			(In thousands)
Allowance for doubtful accounts, year ended December 31:
2012	$	1,778	$	3,384	$	—	$	3,411	$	1,751
2013	$	1,751	$	2,864	$	—	$	3,192	$	1,423
2014	$	1,423	$	3,275	$	—	$	3,232	$	1,466

SCHEDULE II

TEXAS-NEW MEXICO POWER COMPANY AND SUBSIDIARIES

A WHOLLY OWNED SUBSIDIARY OF PNM RESOURCES, INC.

VALUATION AND QUALIFYING ACCOUNTS

			Additions					Deductions
Description	Balance at beginning of year		Charged to costs and expenses			Charged to other accounts		Write-offs			Balance at end of year
			(In thousands)
Allowance for doubtful accounts, year ended December 31:
2012	$	—	$	(17	)	$	—	$	(17	)	$	—
2013	$	—	$	(15	)	$	—	$	(15	)	$	—
2014	$	—	$	(8	)	$	—	$	(8	)	$	—

XML

Consolidated Statements of Changes in Equity (USD $) In Thousands, unless otherwise specified	Total	Common Stock [Member]	AOCI [Member]	Retained Earnings [Member]	Total PNMR 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 PNMR 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 TNMP at Dec. 31, 2011													$ 463,253	$ 64	$ 416,394	$ (58)	$ 46,853
Balance at Dec. 31, 2011	1,656,408	1,193,191	(66,856)	447,650	1,573,985	82,423	1,294,512	1,061,776	(66,798)	217,111	1,212,089	82,423
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Proceeds from stock option exercise	11,684		0	0	11,684	0
Purchases to satisfy awards of common stock	25,168		0	0	25,168	0
Net earnings (loss)	105,547						91,551						26,747	0	0	0
Excess tax (shortfall) from stock-based payment arrangements	(473)	(473)	0	0	(473)	0
Stock based compensation expense	3,585		0	0	3,585	0
Valencia’s transactions with its owner	(15,630)	0	0	0	0		(15,630)	0	0	0	0
Net earnings	120,125	0	0	106,075	106,075	14,050	105,601	0	0	91,551	91,551	14,050	26,747
Preferred Stock Dividends Requirements	(528)	0	0		(528)	0	(528)	0	0		(528)	0	0
Total other comprehensive income (loss)	(14,774)	0	(14,774)	0	(14,774)	0	(14,616)	0	(14,616)	0	(14,616)	0	(158)	0	0	(158)	0
Equity contribution from parent													0
Dividends declared on common stock	(46,199)	0	0	(46,199)	(46,199)	0	(34,433)	0	0	(34,433)	(34,433)	0	(26,028)	0		0	0
Balance TNMP at Dec. 31, 2012													463,814	64	390,366	(216)	73,600
Balance at Dec. 31, 2012	1,689,030	1,182,819	(81,630)	506,998	1,608,187	80,843	1,334,906	1,061,776	(81,414)	273,701	1,254,063	80,843
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Proceeds from stock option exercise	4,618		0	0	4,618	0
Purchases to satisfy awards of common stock	13,807		0	0	13,807	0
Net earnings (loss)	100,507						88,155						29,090	0	0	0
Excess tax (shortfall) from stock-based payment arrangements	(581)	(581)	0	0	(581)	0
Stock based compensation expense	5,320		0	0	5,320	0
Valencia’s transactions with its owner	(18,335)	0	0	0	0		(18,335)	0	0	0	0
Net earnings	115,556	0	0	101,035	101,035	14,521	102,676	0	0	88,155	88,155	14,521	29,090
Preferred Stock Dividends Requirements	(528)	0	0		(528)	0	(528)	0	0		(528)	0	0
Total other comprehensive income (loss)	23,490	0	23,490	0	23,490	0	23,537	0	23,537	0	23,537	0	(47)	0	0	(47)	0
Equity contribution from parent													13,800	0	13,800	0	0
Dividends declared on common stock	(54,165)	0	0	(54,165)	(54,165)	0	(155,028)	0	0	(155,028)	(155,028)	0	(3,726)	0	0	0
Balance TNMP at Dec. 31, 2013	1,673,569						1,210,199						502,931	64	404,166	(263)	98,964
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
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Proceeds from stock option exercise	6,999		0	0	6,999	0
Purchases to satisfy awards of common stock	17,319		0	0	17,319	0
Net earnings (loss)	116,254						87,326						37,807	0	0	0
Excess tax (shortfall) from stock-based payment arrangements	(135)	(135)	0	0	(135)	0
Stock based compensation expense	5,931		0	0	5,931	0
Valencia’s transactions with its owner	(17,610)	0	0	0	0		(17,610)	0	0	0	0
Net earnings	130,909	0	0	116,782	116,782	14,127	101,453	0	0	87,326	87,326	14,127	37,807
Preferred Stock Dividends Requirements	(528)	0	0		(528)	0	(528)	0	0		(528)	0	0
Total other comprehensive income (loss)	(3,615)	0	(3,615)	0	(3,615)	0	(3,878)	0	(3,878)	0	(3,878)	0	263	0	0	263	0
Equity contribution from parent													0
Dividends declared on common stock	(60,138)	0	0	(60,138)	(60,138)	0	(30,263)	0	0	(30,263)	(30,263)	0	(16,336)	0	0	0
Balance TNMP at Dec. 31, 2014	1,721,546						1,262,856						524,665	64	404,166	0	120,435
Balance at Dec. 31, 2014	$ 1,795,092	$ 1,173,845	$ (61,755)	$ 609,456	$ 1,721,546	$ 73,546	$ 1,336,402	$ 1,061,776	$ (61,755)	$ 262,835	$ 1,262,856	$ 73,546

XML

Summary of the Business and Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2014

Accounting Policies [Abstract]

Principles of Consolidation

The Consolidated Financial Statements of each of PNMR, PNM, and TNMP include their accounts and those of subsidiaries in which that entity owns a majority voting interest. PNM also consolidates the PVNGS Capital Trust and Valencia (Note 9). 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.

PNMR shared services’ administrative and general expenses, which represent costs that are primarily driven by corporate level activities, are charged to the business segments. These services are billed at cost. Other significant intercompany transactions between PNMR, PNM, and TNMP include interest and income tax sharing payments, as well as equity transactions. All intercompany transactions and balances have been eliminated.

Accounting for the Effects of Certain Types of Regulation

The Company maintains its accounting records in accordance with the uniform system of accounts prescribed by FERC and adopted by the NMPRC and PUCT.

Certain of the Company’s operations are regulated by the NMPRC, PUCT, and FERC and the provisions of GAAP for rate-regulated enterprises are applied to the regulated operations. Regulators may assign costs to accounting periods that differ from accounting methods applied by non-regulated utilities.  When it is probable that regulators will permit recovery of costs through future rates, costs that otherwise would be expensed are deferred as regulatory assets.  Likewise, regulatory liabilities are recognized when it is probable that regulators will require refunds through future rates or when revenue is collected for expenditures that have not yet been incurred.  Regulatory assets and liabilities are amortized into earnings over the authorized recovery period. Accordingly, the Company has deferred certain costs and recorded certain liabilities pursuant to the rate actions of the NMPRC, PUCT, and FERC. Information on regulatory assets and regulatory liabilities is contained in Note 4.

In some circumstances, regulators allow a requested increase in rates to be implemented, subject to refund, before the regulatory process has been completed and a decision rendered by the regulator. When this occurs, the Company assesses the possible outcomes of the rate proceeding. The Company records a provision for refund to the extent the amounts being collected, subject to refund, exceed the amount the Company determines is probable of ultimately being allowed by the regulator.

Cash and Cash Equivalents

Investments in highly liquid investments with original maturities of three months or less at the date of purchase are considered cash equivalents.

Utility Plant

Utility plant is stated at cost, which includes capitalized payroll-related costs such as taxes, pension, and other fringe benefits, administrative costs, and AFUDC where authorized by rate regulation.

Repairs, including major maintenance activities, and minor replacements of property are expensed when incurred, except as required by regulators for ratemaking purposes. Major replacements are charged to utility plant. Gains or losses resulting from retirements or other dispositions of regulated property in the normal course of business are credited or charged to accumulated depreciation.

Allowance for Funds Used During Construction

As provided by the FERC uniform systems of accounts, AFUDC is charged to regulated utility plant for construction projects. This allowance is a non-cash item designed to enable a utility to capitalize financing costs during periods of construction of property subject to rate regulation. It represents the cost of borrowed funds (allowance for borrowed funds used during construction) and a return on other funds (allowance for equity funds used during construction). The allowance for borrowed funds used during construction is recorded in interest charges and the allowance for equity funds used during construction is recorded in other income on the Consolidated Statements of Earnings.

Capitalized Interest

The Company capitalizes interest on its construction projects and major computer software projects not subject to the computation of AFUDC.

Materials, Supplies, and Fuel Stock

Materials and supplies relate to transmission, distribution, and generating assets. Materials and supplies are charged to inventory when purchased and are expensed or capitalized as appropriate when issued. Materials and supplies are valued using an average costing method.

Coal is valued using a rolling weighted average costing method that is updated based on the current period cost per ton. Periodic aerial surveys are performed on the coal piles and adjustments are made.

Investments

PNM holds investment securities in the NDT for the purpose of funding its share of the decommissioning costs of PVNGS and, beginning in August 2012, a trust for PNM’s share of post-term reclamation costs related to the coal mines serving SJGS (Note 16). All of these investments are classified as available-for-sale. PNM evaluates the securities for impairment on an on-going basis. Since third party investment managers have sole discretion over the purchase and sales of the securities, PNM records a realized loss as an impairment for any security that has a market value that is less than cost at the end of each quarter. For the years ended December 31, 2014, 2013, and 2012, PNM recorded impairment losses on the available-for-sale securities held in the NDT and coal mine reclamation trust of $4.8 million, $3.5 million, and $4.8 million. No gains or losses are deferred as regulatory assets or liabilities. Unrealized gains on these investments, net of related tax effects, are included in OCI and AOCI.

Goodwill and Other Intangible Assets

Under GAAP, the Company does not amortize goodwill. Goodwill is evaluated for impairment annually, or more frequently if events and circumstances indicate that the goodwill might be impaired.

Asset Impairment

Tangible long-lived assets are evaluated in relation to the estimated future undiscounted cash flows to assess recoverability when events and circumstances indicate that the assets might be impaired.

Revenue Recognition

Electric operating revenues are recorded in the period of energy delivery, which includes estimated amounts for service rendered but unbilled at the end of each accounting period. The determination of the energy sales to individual customers is based on the reading of their meters, which occurs on a systematic basis throughout the month. At the end of each month, amounts of energy delivered to customers since the date of the last meter reading and the corresponding unbilled revenue are estimated. Unbilled electric revenue is estimated based on the daily generation volumes, estimated customer usage by class, weather factors, line losses, and applicable customer rates reflecting historical trends and experience.

PNM’s wholesale electricity sales are recorded as electric operating revenues and the wholesale electricity purchases are recorded as costs of energy sold. In accordance with GAAP, derivative contracts that are net settled or “booked-out” are recorded net in earnings. A book-out is the planned or unplanned netting of off-setting purchase and sale transactions. A book-out is a transmission mechanism to reduce congestion on the transmission system or administrative burden. For accounting purposes, a book-out is the recording of net revenues upon the settlement of a derivative contract.

Unrealized gains and losses on contracts that do not qualify for the normal purchases or normal sales exception or are not designated for hedge accounting are classified as economic hedges. Economic hedges are defined as derivative instruments, including long-term power and fuel supply agreements, used to hedge generation assets and purchased power costs. Changes in the fair value of economic hedges are reflected in results of operations, with changes related to economic hedges on sales included in operating revenues and changes related to economic hedges on purchases included in cost of energy sold.

Accounts Receivable and Allowance for Uncollectible Accounts

Accounts receivable consists primarily of trade receivables from customers. In the normal course of business, credit is extended to customers on a short-term basis. The Company calculates the allowance for uncollectible accounts based on historical experience and estimated default rates. The accounts receivable balances are reviewed monthly and adjustments to the allowance for uncollectible accounts and bad debt expense are made as necessary. Amounts that are deemed uncollectible are written off.

Depreciation and Amortization

PNM’s provision for depreciation and amortization of utility plant, other than nuclear fuel, is based upon composite straight-line rates approved by the NMPRC. Amortization of nuclear fuel is based on units-of-production. TNMP’s provision for depreciation and amortization of utility plant is based upon straight-line rates approved by the PUCT. Depreciation of non-utility property is computed based on the straight-line method. The provision for depreciation of certain equipment is allocated between operating expenses and construction projects based on the use of the equipment.

Amortization of Debt Acquisition Costs

Discount, premium, and expense related to the issuance of long-term debt are amortized over the lives of the respective issues. Gains and losses incurred upon the early retirement of long-term debt are recognized in other income or other deductions, except for amounts attributable to NMPRC, FERC, or PUCT regulation, which are recorded as regulatory assets or liabilities and amortized over the lives of the respective issues.

Derivatives

The Company records derivative instruments, including energy contracts, other than those designated as normal purchases or normal sales, in the balance sheet as either an asset or liability measured at their fair value. GAAP requires that changes in the derivatives’ fair value be recognized currently in earnings unless specific hedge accounting or normal purchase or normal sale criteria are met. Normal purchases and normal sales are not marked to market and are reflected in results of operations when the underlying transactions settle. For qualifying hedges, an entity must formally document, designate, and assess the effectiveness of transactions that receive hedge accounting. GAAP provides that the effective portion of the gain or loss on a derivative instrument designated and qualifying as a cash flow hedging instrument be reported as a component of AOCI and be reclassified into earnings in the period during which the hedged forecasted transaction affects earnings. The results of hedge ineffectiveness and the portion of the change in fair value of a derivative that an entity has chosen to exclude from hedge effectiveness are required to be presented in current earnings. See Note 8.

The Company treats all forward electric purchases and sales contracts subject to unplanned netting or book-out by the transmission provider as derivative instruments subject to mark-to-market accounting, unless the contract qualifies for the normal exception by meeting the definition of a capacity contract. Under this definition, the contract cannot permit net settlement, the seller must have the resources to serve the contract, and the buyer must be a load serving entity. GAAP provides guidance on whether realized gains and losses on derivative contracts not held for trading purposes should be reported on a net or gross basis and concludes such classification is a matter of judgment that depends on the relevant facts and circumstances. 

Under derivative accounting and related rules for energy contracts, the Company accounts for its various derivative instruments for the purchase and sale of energy based on the Company’s intent. During the years ended December 31, 2014 and 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.

Decommissioning Costs

PNM owns and leases nuclear and fossil-fuel generating facilities. In accordance with GAAP, PNM is only required to recognize and measure decommissioning liabilities for tangible long-lived assets for which a legal obligation exists. Nuclear decommissioning costs and related accruals are based on periodic site-specific estimates of the costs for removing all radioactive and other structures at PVNGS and are dependent upon numerous assumptions, including estimates of future decommissioning costs at current price levels, inflation rates, and discount rates. PNM’s accruals for PVNGS Units 1, 2, and 3, including portions held under leases, have been made based on such estimates, the guidelines of the NRC, and the extended PVNGS license periods. PVNGS Units 1 and 2 are included in PNM’s retail rates while PVNGS Unit 3 is currently excluded. PNM collects a provision for ultimate decommissioning of PVNGS Units 1 and 2 and its fossil-fueled generation facilities in its rates and recognizes a corresponding expense and liability for these amounts. See Note 15 and Note 16.

In connection with both the SJGS coal agreement and the Four Corners fuel agreement, the owners are required to reimburse the mining companies for the cost of contemporaneous reclamation, as well as the costs for final reclamation of the coal mines. The reclamation costs are based on periodic site-specific studies that estimate the costs to be incurred in the future and are dependent upon numerous assumptions, including estimates of future reclamation costs at current price levels, inflation rates, and discount rates. PNM considers the contemporaneous reclamation costs part of the cost of its delivered coal costs. See Note 16 for a discussion of the final reclamation costs.

Environmental Costs

The normal operations of the Company involve activities and substances that expose the Company to potential liabilities under laws and regulations protecting the environment. Liabilities under these laws and regulations can be material and in some instances may be imposed without regard to fault, or may be imposed for past acts, even though the past acts may have been lawful at the time they occurred.

The Company records its environmental liabilities when site assessments or remedial actions are probable and a range of reasonably likely cleanup costs can be estimated. The Company reviews its sites and measures the liability by assessing a range of reasonably likely costs for each identified site using currently available information and the probable level of involvement and financial condition of other potentially responsible parties. These estimates are based on assumptions regarding the costs for site investigations, remediation, operations and maintenance, monitoring, and site closure. The ultimate cost to clean up the Company’s identified sites may vary from its recorded liability due to numerous uncertainties inherent in the estimation process.

Income Taxes

Income taxes are recognized using the asset and liability method of accounting for income taxes. Deferred tax assets and liabilities are recognized for the estimated future tax consequences attributable to differences between the financial statement carrying value of existing assets and liabilities and their respective tax basis. Current NMPRC, FERC, and PUCT approved rates include the tax effects of the majority of these differences. GAAP requires that rate-regulated enterprises record deferred income taxes for temporary differences accorded flow-through treatment at the direction of a regulatory commission. The resulting deferred tax assets and liabilities are recorded at the expected cash flow to be reflected in future rates. Because the NMPRC, FERC, and the PUCT have consistently permitted the recovery of tax effects previously flowed-through earnings, the Company has established regulatory liabilities and assets offsetting such deferred tax assets and liabilities. The Company recognizes only the impact of tax positions that, based on their merits, are more likely than not to be sustained upon an IRS audit. The Company defers investment tax credits related to rate regulated assets and amortizes them over the estimated useful lives of those assets.

Excise Taxes

The Company pays certain fees or taxes which are either considered to be an excise tax or similar to an excise tax. Substantially all of these taxes are recorded on a net basis in the Consolidated Statements of Earnings.

Segment Information

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

Fair Value Derivatives

ures

The Company determines the fair values of its derivative and other financial instruments based on the hierarchy established in GAAP, which requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. GAAP describes three levels of inputs that may be used to measure fair value. Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities that the reporting entity has the ability to access at the measurement date. Level 2 inputs are inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly. Level 3 inputs are unobservable inputs for the asset or liability. Level 3 inputs used in determining fair values for the Company consist of internal valuation models. The Company records any transfers between fair value hierarchy levels as of the end of each calendar quarter. There were no transfers between levels during the years ended December 31, 2014 and 2013.

For available-for-sale securities, Level 2 fair values are provided by the trustee utilizing a pricing service. The pricing provider predominantly uses the market approach using bid side market value based upon a hierarchy of information for specific securities or securities with similar characteristics. For commodity derivatives, Level 2 fair values are determined based on market observable inputs, which are validated using multiple broker quotes, including forward price, volatility, and interest rate curves to establish expectations of future prices. Credit valuation adjustments are made for estimated credit losses based on the overall exposure to each counterparty. For the Company’s long-term debt, Level 2 fair values are provided by an external pricing service. The pricing service primarily utilizes quoted prices for similar debt in active markets when determining fair value. For investments categorized as Level 3, primarily the PVNGS lessor notes and certain items in other investments, fair values were determined by discounted cash flow models that take into consideration discount rates that are observable for similar types of assets and liabilities. Management of the Company independently verifies the information provided by pricing serv

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.

Pension and Other Postretirement Benefits

GAAP requires a plan sponsor to (a) recognize in its statement of financial position an asset for a plan’s overfunded status or a liability for a plan’s underfunded status; (b) measure a plan’s assets and its obligations that determine its funded status as of the end of the employer’s fiscal year; and (c) recognize changes in the funded status of a defined benefit postretirement plan in the year in which the changes occur.

GAAP requires unrecognized prior service costs and unrecognized gains or losses to be recorded in AOCI and subsequently amortized. The amortization of these incurred costs is included as pension and postretirement benefit periodic cost or income in subsequent years. To the extent the amortization of these items will ultimately be recovered in future rates, PNM and TNMP record the costs as a regulatory asset or regulatory liability.

The expected long-term rate of return on pension and postretirement plan assets is calculated on the market-related value of assets. GAAP requires that actual gains and losses on pension and postretirement plan assets be recognized in the market-related value of assets equally over a period of not more than five years, which reduces year-to-year volatility.

Commitments and Contingencies

There are various claims and lawsuits pending against the Company. The Company also is subject to federal, state, and local environmental laws and regulations and periodically participates in the investigation and remediation of various sites. In addition, the Company occasionally enters into financial commitments in connection with its business operations. Also, the Company is involved in various legal and regulatory (Note 17) proceedings in the normal course of its business. It is not possible at this time for the Company to determine fully the effect of all litigation and other legal and regulatory proceedings on its financial position, results of operations, or cash flows.

With respect to some of the items listed below, the Company has determined that a loss is not probable or that, to the extent probable, cannot be reasonably estimated. In some cases, the Company is not able to predict with any degree of certainty the range of possible loss that could be incurred. Nevertheless, the Company assesses legal and regulatory matters based on current information and makes judgments concerning their potential outcome, giving due consideration to the nature of the claim, the amount and nature of 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. Except as otherwise disclosed, the Company does not expect that any known lawsuits, environmental costs, and commitments will have a material effect on its financial condition, results of operations, or cash flows.

XML

Pension and Other Postretirement Benefits APBO, PBO, Fair Value of Plan Assets, and Funded Status of the Plans (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Non-current liability	$ 110,738	$ 80,046
Public Service Company of New Mexico [Member] | Pension Plan [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit Obligation at beginning of year	599,537	675,549
Service cost	0	0	0
Interest cost	30,163	28,142	32,232
Plan amendment	0	(6,346)
Actuarial (gain) loss	72,524	(56,533)
Benefits paid	(44,667)	(41,275)
Benefit Obligation at end of year	657,557	599,537	675,549
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	556,353	518,095
Actual return on plan assets	76,223	19,533
Employer contributions	0	60,000
Benefits paid	(44,667)	(41,275)
Fair value of plan assets at end of year	587,909	556,353	518,095
Funded status – asset (liability) for pension benefits	(69,648)	(43,184)
Public Service Company of New Mexico [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit Obligation at beginning of year	92,165	99,613
Service cost	181	260	217
Interest cost	4,630	4,113	5,293
Participant contributions	(2,582)	(2,537)
Actuarial (gain) loss	4,455	(4,566)
Benefits paid	(8,838)	(9,792)
Benefit Obligation at end of year	95,175	92,165	99,613
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	73,565	64,464
Actual return on plan assets	7,334	12,780
Employer contributions	3,532	3,576
Participant contributions	2,582	2,537
Benefits paid	(8,838)	(9,792)
Fair value of plan assets at end of year	78,175	73,565	64,464
Funded status – asset (liability) for pension benefits	(17,000)	(18,600)
Public Service Company of New Mexico [Member] | Executive Retirement Program [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit Obligation at beginning of year	16,363	17,467
Service cost	0	0	0
Interest cost	822	720	876
Actuarial (gain) loss	2,040	(330)
Benefits paid	(1,495)	(1,494)
Benefit Obligation at end of year	17,730	16,363	17,467
Less current liability	1,528	1,536
Non-current liability	16,202	14,827
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Benefits paid	(1,495)	(1,494)
Texas-New Mexico Power Company [Member] | Pension Plan [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit Obligation at beginning of year	66,159	76,640
Service cost	0	0	0
Interest cost	3,193	3,087	3,635
Plan amendment	0	0
Actuarial (gain) loss	8,466	(7,820)
Benefits paid	(5,513)	(5,748)
Benefit Obligation at end of year	72,305	66,159	76,640
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	66,118	66,540
Actual return on plan assets	8,572	4,326
Employer contributions	0	1,000
Benefits paid	(5,513)	(5,748)
Fair value of plan assets at end of year	69,177	66,118	66,540
Funded status – asset (liability) for pension benefits	(3,128)	(41)
Texas-New Mexico Power Company [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit Obligation at beginning of year	12,266	13,678
Service cost	237	299	244
Interest cost	619	566	624
Participant contributions	(366)	(373)
Actuarial (gain) loss	1,639	(1,080)
Benefits paid	(1,057)	(1,570)
Benefit Obligation at end of year	14,070	12,266	13,678
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	9,601	8,643
Actual return on plan assets	841	1,813
Employer contributions	343	342
Participant contributions	366	373
Benefits paid	(1,057)	(1,570)
Fair value of plan assets at end of year	10,094	9,601	8,643
Funded status – asset (liability) for pension benefits	(3,976)	(2,665)
Texas-New Mexico Power Company [Member] | Executive Retirement Program [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit Obligation at beginning of year	823	902
Service cost	0	0	0
Interest cost	39	36	45
Actuarial (gain) loss	110	(21)
Benefits paid	(94)	(94)
Benefit Obligation at end of year	878	823	902
Less current liability	94	94
Non-current liability	784	729
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Benefits paid	$ (94)	$ (94)

XML

Earnings and Dividends Per Share (Tables)

12 Months Ended

Dec. 31, 2014

Earnings Per Share [Abstract]

Schedule of Earnings Per Share, Basic and Diluted

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

	Year Ended December 31,
	2014		2013		2012
	(In thousands, except per share amounts)
Earnings Attributable to PNMR	$	116,254	$	100,507	$	105,547
Average Number of Common Shares:
Outstanding during year	79,654		79,654		79,654
Vested awards of restricted stock	134		191		145
Average Shares – Basic	79,788		79,845		79,799
Dilutive Effect of Common Stock Equivalents (1):
Stock options and restricted stock	491		586		618
Average Shares – Diluted	80,279		80,431		80,417
Net Earnings Per Share of Common Stock:
Basic	$	1.46	$	1.26	$	1.32
Diluted	$	1.45	$	1.25	$	1.31
Dividends Declared per Common Share	$	0.755	$	0.680	0.580

⁽¹⁾  Excludes out-of-the-money options for 254,050 shares of common stock at December 31, 2014. See Note 13.

XML

Segment Information (Narrative and Major Customers) (Details) (Electric operating revenues [Member])	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
First Choice [Member]
Concentration Risk [Line Items]
Operating revenues from continuing operations (as a percent)	15.00%	17.00%
Unaffiliated Customer of Texas-New Mexico Power Company One [Member]
Concentration Risk [Line Items]
Operating revenues from continuing operations (as a percent)	15.00%	16.00%	17.00%
Unaffiliated Customer of Texas-New Mexico Power Company Two [Member]
Concentration Risk [Line Items]
Operating revenues from continuing operations (as a percent)	11.00%	10.00%	10.00%
PNMR and PNM [Member] | Maximum [Member]
Concentration Risk [Line Items]
Number of Customers that make up 10 percent of total revenue	0
Operating revenues from continuing operations (as a percent)	10.00%
Texas-New Mexico Power Company [Member] | Maximum [Member]
Concentration Risk [Line Items]
Number of Customers that make up 10 percent of total revenue	2

XML

Variable Interest Entities (Details) (USD $)	3 Months Ended								12 Months Ended			6 Months Ended
	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Jul. 16, 2014	Oct. 08, 2013	May 30, 2008 MW	Jul. 17, 2014
Variable Interest Entity, Statement Of Operation [Abstract]
Earnings Attributable to non-controlling interest									$ 14,127,000	$ 14,521,000	$ 14,050,000
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Total current assets	432,817,000				401,539,000				432,817,000	401,539,000
Total Assets	5,829,325,000				5,500,210,000				5,829,325,000	5,500,210,000	5,372,583,000
Current liabilities	704,282,000				492,671,000				704,282,000	492,671,000
Owners' equity - non-controlling interest	73,546,000				77,029,000				73,546,000	77,029,000
Operating Leases, renewal options after original lease term									6 years
Earnings Attributable to PNMR	18,992,000	55,653,000	29,141,000	12,468,000	7,648,000	54,555,000	27,678,000	10,626,000	116,254,000	100,507,000	105,547,000
Public Service Company of New Mexico [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Operating Leases, Currently active with trusts	8								8
Operating Leases, trust lessors	8								8
Operating Leases, Different institutional investors of trust lessors	5								5
Operating Leases, renewal options after original lease term									2 years
Operating Leases, Extended lease term option									6 years
Operating leases, future minimum payments due	269,693,000								269,693,000
Operating Leases, Future Minimum Payments Due, Current	33,144,000								33,144,000
Earnings Attributable to PNMR	13,955,000	45,351,000	20,346,000	7,674,000	2,639,000	47,823,000	26,124,000	11,569,000
Valencia [Member] | Public Service Company of New Mexico [Member]
Variable Interest Entity [Line Items]
Number of mega watts purchased (in megawatts)														158
Power plant total construction costs														90,000,000
Long term contract for purchase of electric power fixed costs									19,100,000	18,900,000	18,800,000
Long term contract for purchase of electric power variable charges									1,200,000	1,200,000	900,000
Variable Interest Entity, Statement Of Operation [Abstract]
Electric Revenue									20,247,000	20,166,000	19,585,000
Operating expenses									(6,120,000)	(5,645,000)	(5,535,000)
Earnings Attributable to non-controlling interest									(14,127,000)	(14,521,000)	(14,050,000)
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Total current assets	2,513,000				2,658,000				2,513,000	2,658,000
Net property, plant and equipment	72,321,000				75,137,000				72,321,000	75,137,000
Total Assets	74,834,000				77,795,000				74,834,000	77,795,000
Current liabilities	1,288,000				766,000				1,288,000	766,000
Owners' equity - non-controlling interest	73,546,000				77,029,000				73,546,000	77,029,000
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, estimated purchase price													85,000,000
Long term contract option to purchase, approximate approval period									15 months
Long term contract option to purchase, ownership percentage									50.00%
Long Term Contract For Purchase of Power Term of Contract									20 years
Valencia [Member] | Maximum [Member] | Public Service Company of New Mexico [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Jointly owned utility plant, option to purchase proportionate ownership share	50.00%								50.00%
Delta [Member] | Public Service Company of New Mexico [Member]
Variable Interest Entity [Line Items]
Long term contract for purchase of electric power fixed costs												3,500,000
Long term contract for purchase of electric power variable charges												600,000
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Period of Long Term Contract For Purchase of Electric Power Fixed Costs									20 years
PVNGS [Member] | Public Service Company of New Mexico [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Operating leases, future minimum payments due	20,300,000								20,300,000
Operating leases, future minimum payments due, renewal term	145,200,000								145,200,000
Delta [Member] | Public Service Company of New Mexico [Member]
Variable Interest Entity [Line Items]
Long term contract for purchase of electric power fixed costs										6,400,000	6,200,000
Long term contract for purchase of electric power variable charges										1,800,000	800,000
Delta [Member] | Public Service Company of New Mexico [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Payments to acquire businesses, net												22,800,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt															14,600,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment															58,100,000
Business Combination, recognized identifiable assets acquired, accumulated amort															23,500,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets															3,600,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Assets															3,400,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities															300,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities															3,400,000
Palo Verde Nuclear Generating Station [Member] | PVNGS [Member] | Public Service Company of New Mexico [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Operating Leases, Future Minimum Payments Due, Current	$ 26,000,000				$ 26,000,000				$ 26,000,000	$ 26,000,000

XML

Consolidated Statements of Earnings (USD $) In Thousands, except Per Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Electric Operating Revenues	$ 1,435,853	$ 1,387,923	$ 1,342,403
Operating Expenses:
Cost of energy	471,556	432,316	399,850
Administrative and general	171,111	179,210	187,740
Energy production costs	185,638	175,819	185,417
Regulatory disallowances	1,062	12,235	0
Depreciation and amortization	172,634	166,881	164,173
Transmission and distribution costs	66,571	70,124	71,125
Taxes other than income taxes	67,584	64,496	60,377
Total operating expenses	1,136,156	1,101,081	1,068,682
Operating income	299,697	286,842	273,721
Other Income and Deductions:
Interest income	8,483	10,043	13,072
Gains on available-for-sale securities	10,527	10,612	12,965
Other income	12,048	10,572	12,746
Gain on sale of First Choice	0	0	1,012
Other (deductions)	(10,481)	(21,552)	(17,636)
Net other income and deductions	20,577	9,675	22,159
Interest Charges	119,627	121,448	120,845
Earnings before Income Taxes	200,647	175,069	175,035
Income Taxes	69,738	59,513	54,910
Net Earnings	130,909	115,556	120,125
(Earnings) Attributable to Valencia Non-controlling Interest	(14,127)	(14,521)	(14,050)
Net Earnings Attributable to Company	116,254	100,507	105,547
Preferred Stock Dividends Requirements	(528)	(528)	(528)
Net Earnings Available for PNM Common Stock	116,254	100,507	105,547
Net Earnings Attributable to PNMR per Common Share:
Basic (dollars per share)	$ 1.46	$ 1.26	$ 1.32
Diluted (dollars per share)	$ 1.45	$ 1.25	$ 1.31
Public Service Company of New Mexico [Member]
Electric Operating Revenues	1,147,914	1,116,312	1,092,264
Operating Expenses:
Cost of energy	403,626	374,710	353,649
Administrative and general	152,645	157,144	169,285
Energy production costs	185,638	175,819	185,403
Regulatory disallowances	1,062	12,235	0
Depreciation and amortization	109,524	103,826	97,291
Transmission and distribution costs	43,128	45,936	46,039
Taxes other than income taxes	39,578	37,457	34,715
Total operating expenses	935,201	907,127	886,382
Operating income	212,713	209,185	205,882
Other Income and Deductions:
Interest income	8,557	10,182	13,243
Gains on available-for-sale securities	10,527	10,612	12,965
Other income	8,949	7,650	8,126
Gain on sale of First Choice			0
Other (deductions)	(7,218)	(6,974)	(7,801)
Net other income and deductions	20,815	21,470	26,533
Interest Charges	79,442	79,175	76,101
Earnings before Income Taxes	154,086	151,480	156,314
Income Taxes	52,633	48,804	50,713
Net Earnings	101,453	102,676	105,601
(Earnings) Attributable to Valencia Non-controlling Interest	(14,127)	(14,521)	(14,050)
Net Earnings Attributable to Company	87,326	88,155	91,551
Preferred Stock Dividends Requirements	(528)	(528)	(528)
Net Earnings Available for PNM Common Stock	86,798	87,627	91,023
Texas-New Mexico Power Company [Member]
Electric Operating Revenues	287,939	271,611	250,140
Operating Expenses:
Cost of energy	67,930	57,606	46,201
Administrative and general	36,982	44,635	40,775
Depreciation and amortization	50,056	50,219	49,340
Transmission and distribution costs	23,443	24,188	25,086
Taxes other than income taxes	23,940	22,778	21,218
Total operating expenses	202,351	199,426	182,620
Operating income	85,588	72,185	67,520
Other Income and Deductions:
Interest income	0	0	1
Other income	2,865	2,377	4,698
Gain on sale of First Choice			0
Other (deductions)	(727)	(458)	(1,959)
Net other income and deductions	2,138	1,919	2,740
Interest Charges	27,396	27,393	28,161
Earnings before Income Taxes	60,330	46,711	42,099
Income Taxes	22,523	17,621	15,352
Net Earnings	37,807	29,090	26,747
(Earnings) Attributable to Valencia Non-controlling Interest	0	0	0
Net Earnings Attributable to Company	37,807	29,090	26,747
Preferred Stock Dividends Requirements	0	0	0
Net Earnings Available for PNM Common Stock	$ 37,807	$ 29,090	$ 26,747

XML

Asset Retirement Obligations (Tables)

12 Months Ended

Dec. 31, 2014

Asset Retirement Obligation Disclosure [Abstract]

Schedule of Asset Retirement Obligations

A reconciliation of the ARO liability is as follows:

	PNMR			PNM			TNMP
	(In thousands)
Liability at December 31, 2011	$	79,233		$	78,425		$	699
Liabilities incurred	—			—			—
Liabilities settled	(25		)	—			(25		)
Accretion expense	6,685			6,617			58
Liability at December 31, 2012	85,893			85,042			732
Liabilities incurred	—			—			—
Liabilities settled	(79		)	(67		)	(12		)
Accretion expense	7,245			7,174			62
Revisions to estimated cash flows(1)	3,076			3,076			—
Liability at December 31, 2013	96,135			95,225			782
Liabilities incurred	—			—			—
Liabilities settled	—			—			—
Accretion expense	7,984			7,906			66
Revisions to estimated cash flows	51			51			—
Liability at December 31, 2014	$	104,170		$	103,182		$	848

⁽¹⁾  Based on studies to estimate the amount and timing of future ARO expenditures. PNM has an ARO for PVNGS that includes the obligations for nuclear decommissioning of that facility. In 2013, a new decommissioning study for PVNGS was implemented reflecting updated cash flow estimates, including the extended operating licenses. The new study resulted in an increase of $0.5 million to the ARO. In addition, a new decommissioning study for SJGS was implemented in 2013, resulting in a $2.5 million increase to the ARO.

XML

Commitments and Contingencies (Details) (USD $)	12 Months Ended				0 Months Ended
	Dec. 31, 2014		Dec. 31, 2013	Dec. 31, 2012	Oct. 01, 2014	Dec. 20, 2013 MW	Dec. 21, 2011 mw	Jun. 26, 2014	Oct. 31, 2014	Oct. 31, 2012	Sep. 30, 2014	Nov. 25, 2014 opp	Jan. 31, 2010 opp	Apr. 12, 2012	Jun. 27, 2014	Mar. 11, 2014	May 23, 2013	Jan. 06, 2014 Allotment_Parcel	Sep. 01, 2012 Allotment_Parcel	Nov. 08, 2013	Jan. 07, 2015 MW	Jan. 15, 2015 MW	Jan. 22, 2015
Loss Contingencies [Line Items]
Minimum Megawatt Capacity from Coal and Oil-Fired Electric Generating Units under Jurisdiction of the Merucy and Air Toxics Standards							25
Other current assets	$ 58,471,000		$ 34,590,000
San Juan Generating Station [Member]
Loss Contingencies [Line Items]
Mercury Removal Rate, Percentage							99.00%
Four Corners [Member]
Loss Contingencies [Line Items]
Public Utilities, Jointly Owned Utility Plant, Sale of Ownership Percentage			48.00%
Public Service Company of New Mexico [Member]
Loss Contingencies [Line Items]
Regulatory Assets	401,025,000		403,611,000
Public Service Company of New Mexico [Member] | San Juan Generating Station Unit 4 [Member]
Loss Contingencies [Line Items]
Jointly Owned Utility Plan, Proposed Proportionate Ownership Share								64.50%
Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station [Member]
Loss Contingencies [Line Items]
Payments to Acquire Investments to be Held in Decommissioning Trust Fund	4,900,000		4,900,000	2,600,000
Decommissioning Fund Investments, Fair Value	244,600,000		222,500,000
Jointly Owned Utility Plant, Proportionate Ownership Share	10.20%	[1]
Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station [Member] | Nuclear Spent Fuel And Waste Disposal [Member]
Loss Contingencies [Line Items]
Loss Contingency, Estimate of Possible Loss	58,000,000
Annual Fee, Nuclear Waste Disposal	0		3,000,000
Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station [Member] | Department of energy, spent nuclear fuel removal July 2011 - June 2014 [Member]
Loss Contingencies [Line Items]
Lawsuit settlement, Third party settlement claim									42,500,000
PNMs share of third party settlement claim									4,300,000
Public Service Company of New Mexico [Member] | San Juan Generating Station [Member]
Loss Contingencies [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share										46.30%
Public Service Company of New Mexico [Member] | San Juan Generating Station Units 2 and 3 [Member]
Loss Contingencies [Line Items]
Net book value	282,000,000
Public Service Company of New Mexico [Member] | Four Corners Units 4 and 5 (Coal) [Member]
Loss Contingencies [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	13.00%
Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station Unit 3 [Member]
Loss Contingencies [Line Items]
Net book value											144,000,000
Public Service Company of New Mexico [Member] | San Juan Generating Station Units 1 and 4 [Member]
Loss Contingencies [Line Items]
Jointly Owned Utility Plan, Proposed Proportionate Ownership Share								58.70%
Public Service Company of New Mexico [Member] | Other Deferred Credits [Member] | Palo Verde Nuclear Generating Station [Member] | Nuclear Spent Fuel And Waste Disposal [Member]
Loss Contingencies [Line Items]
Mine Reclamation and Closing Liability, Noncurrent	12,300,000		11,900,000
Public Service Company of New Mexico [Member] | Minimum [Member] | San Juan Generating Station And Four Corners [Member]
Loss Contingencies [Line Items]
Public Utilities, Proposed Government Standard Emission Limit												65	60
Public Service Company of New Mexico [Member] | Maximum [Member] | San Juan Generating Station And Four Corners [Member]
Loss Contingencies [Line Items]
Public Utilities, Government Standard Emission Limit (pounds per MMBTU, parts per million)	75
Public Utilities, Proposed Government Standard Emission Limit												70	70
Public Service Company of New Mexico [Member] | Coal Supply [Member] | San Juan Generating Station [Member]
Loss Contingencies [Line Items]
Other current assets	37,300,000		12,300,000
Public Utilities, Estimated Increase in Coal Cost, Percentage	30.00%
Public Service Company of New Mexico [Member] | Surface [Member]
Loss Contingencies [Line Items]
Regulatory Assets	100,000,000
Public Service Company of New Mexico [Member] | Surface [Member] | Loss on Long-term Purchase Commitment [Member]
Loss Contingencies [Line Items]
Mine Reclamation and Closing Liability, Noncurrent	25,700,000		23,800,000
Final Reclamation, capped amount to be collected	100,000,000
Public Service Company of New Mexico [Member] | Surface [Member] | San Juan Generating Station [Member] | Loss on Long-term Purchase Commitment [Member]
Loss Contingencies [Line Items]
Loss Contingency, Estimate of Possible Loss	57,300,000
Public Service Company of New Mexico [Member] | Underground [Member] | Loss on Long-term Purchase Commitment [Member]
Loss Contingencies [Line Items]
Mine Reclamation and Closing Liability, Noncurrent	8,600,000		7,800,000
Public Service Company of New Mexico [Member] | Underground [Member] | San Juan Generating Station [Member] | Loss on Long-term Purchase Commitment [Member]
Loss Contingencies [Line Items]
Loss Contingency, Estimate of Possible Loss	93,300,000
Public Service Company of New Mexico [Member] | Nuclear Plant [Member] | Palo Verde Nuclear Generating Station [Member]
Loss Contingencies [Line Items]
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, Sublimit Amount under Nuclear Electric Insurance Limited	2,250,000,000
Public Utilities, Maximum Amount under Nuclear Electic Insurance Limited	4,800,000
Public Service Company of New Mexico [Member] | Nuclear Plant [Member] | Maximum [Member] | Palo Verde Nuclear Generating Station [Member]
Loss Contingencies [Line Items]
Public Utilities, Liability Insurance Coverage	13,600,000,000
Public Service Company of New Mexico [Member] | Commercial Providers [Member] | Nuclear Plant [Member] | Palo Verde Nuclear Generating Station [Member]
Loss Contingencies [Line Items]
Public Utilities, Liability Insurance Coverage	375,000,000
Public Service Company of New Mexico [Member] | Industry Wide Retrospective Assessment Program [Member] | Nuclear Plant [Member] | Palo Verde Nuclear Generating Station [Member]
Loss Contingencies [Line Items]
Public Utilities, Liability Insurance Coverage	13,200,000,000
Pnm Electric [Member] | San Juan Generating Station Units 2 and 3 [Member]
Loss Contingencies [Line Items]
Estimated cost of replacing gas fired peaking capacity due to retirement of SJGS units	268,400,000
PNMR and PNM [Member] | Palo Verde Nuclear Generating Station Unit 3 [Member]
Loss Contingencies [Line Items]
Public Utilities, Number of Megawatts Nuclear Generation	134
Fuel and purchased power adjustment clause [Member] | Public Service Company of New Mexico [Member] | Minimum [Member] | San Juan Generating Station [Member]
Loss Contingencies [Line Items]
Preliminary estimate increased deferral related to mine fire incident	17,400,000
Fuel and purchased power adjustment clause [Member] | Public Service Company of New Mexico [Member] | Maximum [Member] | San Juan Generating Station [Member]
Loss Contingencies [Line Items]
Preliminary estimate increased deferral related to mine fire incident	21,600,000
Clean Air Act related to Regional Haze [Member]
Loss Contingencies [Line Items]
Public Utilities, Number of States To Address Regional Haze	50
Public Utilities, Potential to emit tons per year of visibility impairing pollution, maximum	250
Clean Air Act, SNCR [Member] | San Juan Generating Station Unit 4 [Member]
Loss Contingencies [Line Items]
Public Utilities, Estimated rate base value at 1/1/2018					26,000,000
Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | San Juan Generating Station Unit 4 [Member]
Loss Contingencies [Line Items]
Public Utilities, Additional Ownership To Be Obtained, in Megawatts					132	78		132
Percentage of ownership held by exiting owners	38.80%
Public Utilities, Ownership Percentage	38.50%
Public Utilities, Costs to obtain additional ownership								0
Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | San Juan Generating Station [Member]
Loss Contingencies [Line Items]
Public Utilities, Overall Reduction Of Ownership, in Megawatts						340
Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | San Juan Generating Station Units 2 and 3 [Member]
Loss Contingencies [Line Items]
Public Utilities, Requested Time Period to Recover Retired Units NBV					20 years	20 years
Public Utilities, Number of Mega Watts of Gas-fired Generation						177
Public Utilities, Newly Identified Replacement Solar Generation, in Megawatts, December2013						40
Public Utilities, Recovery Percentage of Estimated undepreciated value at 12/31/17					50.00%
Public Utilities, Estimated undepreciated value at 12/31/17					231,000,000
Public Utilities, Write-off Percentage of Estimated undepreciated value at 12/31/17					50.00%
Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station Unit 3 [Member]
Loss Contingencies [Line Items]
Public Utilities, Proposed value per Kilowatt effective January 1, 2018					1,650
Public Utilities, Estimated rate base value at 1/1/2018					221,100,000
Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | San Juan Generating Station Unit 3 [Member]
Loss Contingencies [Line Items]
Public Utilities, Ownership To Be Exchanged, in Megawatts						78
Public Utilities, Proposed reduction in carrying value					26,000,000
Public Utilities,Estimated unrecoverable increase in operations and maintenance					20,000,000
Percentage of ownership held by exiting owners	50.00%
Public Utilities, Ownership Percentage	50.00%
Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | Minimum [Member] | San Juan Generating Station Unit 3 [Member]
Loss Contingencies [Line Items]
Public Utilities,Estimated pre-tax regulatory disallowance					60,000,000
Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | Maximum [Member] | San Juan Generating Station Unit 3 [Member]
Loss Contingencies [Line Items]
Public Utilities,Estimated pre-tax regulatory disallowance					70,000,000
Clean Air Act, SNCR [Member] | PNMR and PNM [Member] | Palo Verde Nuclear Generating Station Unit 3 [Member]
Loss Contingencies [Line Items]
Public Utilities, Number of Megawatts Nuclear Generation					134	134
Public Utilities, Proposed value per Kilowatt effective January 1, 2018						2,500
Public Utilities, Percentage capacity factor 7-year performance threshold					75.00%
Public Utilities, Period over which to measure capacity performance					7 years
Clean Air Act related to Post-Combustion Controls [Member] | Public Service Company of New Mexico [Member] | Four Corners [Member]
Loss Contingencies [Line Items]
Loss Contingency, Estimate of Possible Loss	80,000,000
Public Utilities, Number of Compliance alternatives	2
Public Utilities, Government Standard Emission Limit (pounds per MMBTU, parts per million)	0.015
Public Utilitites, Plant Requirment 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%
Clean Air Act related to Post-Combustion Controls [Member] | Public Service Company of New Mexico [Member] | Four Corners Units 4 and 5 (Coal) [Member]
Loss Contingencies [Line Items]
Public Utilities, Ownership Percentage	13.00%
Mercury Control [Member] | Public Service Company of New Mexico [Member] | San Juan Generating Station [Member]
Loss Contingencies [Line Items]
Current Annual Mercury Control Costs	700,000
Mercury Control [Member] | Public Service Company of New Mexico [Member] | Maximum [Member] | San Juan Generating Station [Member]
Loss Contingencies [Line Items]
Contingent Estimated Annual Mercury Control Cost	6,600,000
Sierra Club Allegations [Member] | San Juan Generating Station [Member]
Loss Contingencies [Line Items]
Estimated Total Litigation Settlement Cost														10,200,000
Sierra Club Allegations [Member] | Public Service Company of New Mexico [Member] | San Juan Generating Station [Member]
Loss Contingencies [Line Items]
Estimated Company Share Litigation Settlement Cost														4,500,000
Loss on Long-term Purchase Commitment [Member] | Public Service Company of New Mexico [Member]
Loss Contingencies [Line Items]
Public Utilities, Annual Funding	1,000,000		300,000	3,500,000
Public Utilities, Expected Funding Annual Requirements	600,000
Installation Costs Including Construction Management, Gross Receipts Taxes, AFUDC, and Other PNM Costs [Member] | Clean Air Act, SCR [Member] | Public Service Company of New Mexico [Member] | Minimum [Member] | San Juan Generating Station [Member]
Loss Contingencies [Line Items]
Estimated Total Capital Cost If Requirement Occurred										824,000,000
Installation Costs Including Construction Management, Gross Receipts Taxes, AFUDC, and Other PNM Costs [Member] | Clean Air Act, SCR [Member] | Public Service Company of New Mexico [Member] | Maximum [Member] | San Juan Generating Station [Member]
Loss Contingencies [Line Items]
Estimated Total Capital Cost If Requirement Occurred										910,000,000
Installation Costs Including Construction Management, Gross Receipts Taxes, AFUDC, and Other PNM Costs [Member] | Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | San Juan Generating Station Unit 4 [Member]
Loss Contingencies [Line Items]
Requested Expenditure, Installation Capital Costs																1,900,000
Requested Additional Expenditure, Installation Capital Costs															6,400,000
Installation Costs Including Construction Management, Gross Receipts Taxes, AFUDC, and Other PNM Costs [Member] | Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | Minimum [Member] | San Juan Generating Station [Member]
Loss Contingencies [Line Items]
Estimated Installation Capital Costs										85,000,000
Estimated Portion of Total Capital Costs if Requirement Occured										105,000,000
Installation Costs Including Construction Management, Gross Receipts Taxes, AFUDC, and Other PNM Costs [Member] | Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | Maximum [Member] | San Juan Generating Station [Member]
Loss Contingencies [Line Items]
Estimated Installation Capital Costs										90,000,000
Estimated Portion of Total Capital Costs if Requirement Occured										110,000,000
Installation Costs Including Construction Management, Gross Receipts Taxes, AFUDC, and Other PNM Costs [Member] | Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | Maximum [Member] | San Juan Generating Station Units 1 and 4 [Member]
Loss Contingencies [Line Items]
Estimated Installation Capital Costs					90,600,000	82,000,000
San Juan Underground Mine Fire [Member] | Fuel and purchased power adjustment clause [Member] | Public Service Company of New Mexico [Member] | San Juan Generating Station [Member]
Loss Contingencies [Line Items]
Public Utilities, Insurance Recovery	18,700,000
NMTRD Coal Severance Tax [Member] | Four Corners [Member]
Loss Contingencies [Line Items]
Public Utilities, Assessed Coal Severance Surtax Penalty and Interest																	30,000,000
NMTRD Coal Severance Tax [Member] | Public Service Company of New Mexico [Member] | Four Corners [Member]
Loss Contingencies [Line Items]
Public Utilities, PNM Share Assessed Coal Severance Surtax Penalty and Interest to pass through FFPAC																	9.40%
Navajo Nation Allottee Matters [Member] | Public Service Company of New Mexico [Member]
Loss Contingencies [Line Items]
Number of landowners claiming to be Navajo allottees																			43
Number of allotment parcels' appraisal requested for review																		58
San Juan Generating Station [Member] | National Ambient Air Quality Standards [Member] | Public Service Company of New Mexico [Member]
Loss Contingencies [Line Items]
Public Utilities, Revised SO2 Emissions Agreed Upon																				0.10
San Juan Generating Station [Member] | Continuous Highwall Mining [Member]
Loss Contingencies [Line Items]
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%
San Juan Generating Station [Member] | SJCC Arbitration [Member]
Loss Contingencies [Line Items]
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
San Juan Generating Station [Member] | SJCC Arbitration [Member] | Public Service Company of New Mexico [Member]
Loss Contingencies [Line Items]
Public Utilities, PNM Share of arbitration ruling	46.30%
Public Utilities, FFPAC Percentage of mining costs overbilled or unbilled ruled by arbitration	33.00%
Settled Litigation [Member] | Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station [Member] | Department of energy, spent nuclear fuel removal January 2007 - June 2011 [Member]
Loss Contingencies [Line Items]
Lawsuit settlement, third party receipt	57,400,000
Settled Litigation [Member] | Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station [Member] | Nuclear Spent Fuel And Waste Disposal [Member]
Loss Contingencies [Line Items]
PNMs share of lawsuit settlement, third party receipt	5,900,000
Subsequent Event [Member] | Clean Air Act, SNCR [Member] | San Juan Generating Station Unit 4 [Member]
Loss Contingencies [Line Items]
Public Utilities, Unsubscribed Ownership in Megawatts																					65
Subsequent Event [Member] | Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | San Juan Generating Station Unit 4 [Member]
Loss Contingencies [Line Items]
Public Utilities, Ownership in Megawatts PNM has agreed not to obtain																						65
Subsequent Event [Member] | Clean Air Act, SNCR [Member] | PNMR [Member] | San Juan Generating Station Unit 4 [Member]
Loss Contingencies [Line Items]
Public Utilities, Potential Acquisition of Ownership in Megawatts																					65
Subsequent Event [Member] | Installation Costs Including Construction Management, Gross Receipts Taxes, AFUDC, and Other PNM Costs [Member] | Clean Air Act, SNCR [Member] | Public Service Company of New Mexico [Member] | San Juan Generating Station Unit 4 [Member]
Loss Contingencies [Line Items]
Requested Expenditure, Installation Capital Costs																							$ 76,600,000

[1] Includes interest in PVNGS Unit 3, interest in common facilities for all PVNGS units, and owned interests in PVNGS Units 1 and 2.

XML

Consolidated Balance Sheets (USD $)	Dec. 31, 2014	Dec. 31, 2013
Current Assets:
Cash and cash equivalents	$ 28,274,000	$ 2,533,000
Accounts receivable, net of allowance for uncollectible accounts of $1,466 and $1,423 for PNMR and PNM	87,038,000	90,251,000
Unbilled revenues	63,719,000	58,806,000
Other receivables	39,857,000	53,909,000
Materials, supplies, and fuel stock	63,628,000	67,223,000
Regulatory assets	47,855,000	24,416,000
Commodity derivative instruments	11,232,000	4,064,000
Income taxes receivable	6,360,000	7,066,000
Current portion of accumulated deferred income taxes	26,383,000	58,681,000
Other current assets	58,471,000	34,590,000
Total current assets	432,817,000	401,539,000
Other Property and Investments:
Investment in PVNGS lessor notes	9,538,000	32,200,000
Available-for-sale securities	250,145,000	226,855,000
Other investments	1,762,000	1,835,000
Non-utility property	3,406,000	4,353,000
Total other property and investments	264,851,000	265,243,000
Utility Plant:
Plant in service and plant held for future use	5,941,581,000	5,563,061,000
Less accumulated depreciation and amortization	1,939,760,000	1,838,832,000
Net plant in service and plant held for future use	4,001,821,000	3,724,229,000
Construction work in progress	190,389,000	132,080,000
Nuclear fuel, net of accumulated amortization of $44,507 and $47,347 for PNMR and PNM	77,796,000	77,602,000
Net utility plant	4,270,006,000	3,933,911,000
Deferred Charges and Other Assets:
Regulatory assets	491,007,000	523,955,000
Goodwill	278,297,000	278,297,000
Commodity derivative instruments	0	3,002,000
Other deferred charges	92,347,000	94,263,000
Total deferred charges and other assets	861,651,000	899,517,000
Total Assets	5,829,325,000	5,500,210,000
Current Liabilities:
Short-term debt	105,600,000	149,200,000
Current installments of long-term debt	333,066,000	75,000,000
Accounts payable	110,029,000	109,666,000
Customer deposits	12,555,000	13,456,000
Accrued interest and taxes	53,863,000	49,600,000
Regulatory liabilities	1,703,000	1,081,000
Commodity derivative instruments	1,209,000	2,699,000
Dividends declared	16,063,000	14,864,000
Other current liabilities	70,194,000	77,105,000
Total current liabilities	704,282,000	492,671,000
Long-term Debt	1,642,024,000	1,670,420,000
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	891,111,000	827,263,000
Regulatory liabilities	466,143,000	460,649,000
Asset retirement obligations	104,170,000	96,135,000
Accrued pension liability and postretirement benefit cost	110,738,000	80,046,000
Commodity derivative instruments	477,000	1,094,000
Other deferred credits	103,759,000	109,805,000
Total deferred credits and other liabilities	1,676,398,000	1,574,992,000
Total liabilities	4,022,704,000	3,738,083,000
Commitments and Contingencies (See Note 16)
Cumulative Preferred Stock of Subsidiary without mandatory redemption requirements ($100 stated value; 10,000,000 shares authorized; issued and outstanding 115,293 shares)	11,529,000	11,529,000
Company common stockholders’ equity:
Common stock outstanding	1,173,845,000	1,178,369,000
Accumulated other comprehensive income (loss), net of income taxes	(61,755,000)	(58,140,000)
Retained earnings	609,456,000	553,340,000
Total PNMR common stockholders’ equity	1,721,546,000	1,673,569,000
Non-controlling interest in Valencia	73,546,000	77,029,000
Total equity	1,795,092,000	1,750,598,000
Total liabilities and stockholders' equity	5,829,325,000	5,500,210,000
Texas-New Mexico Power Company [Member]
Current Assets:
Cash and cash equivalents	1,000	1,000
Accounts receivable, net of allowance for uncollectible accounts of $1,466 and $1,423 for PNMR and PNM	19,416,000	20,125,000
Unbilled revenues	9,579,000	9,814,000
Other receivables	2,063,000	1,246,000
Materials, supplies, and fuel stock	2,769,000	2,703,000
Regulatory assets	3,875,000	5,022,000
Current portion of accumulated deferred income taxes	6,398,000	6,501,000
Other current assets	938,000	980,000
Total current assets	45,039,000	46,392,000
Other Property and Investments:
Other investments	242,000	245,000
Non-utility property	2,240,000	2,240,000
Total other property and investments	2,482,000	2,485,000
Utility Plant:
Plant in service and plant held for future use	1,182,112,000	1,074,193,000
Less accumulated depreciation and amortization	375,407,000	352,105,000
Net plant in service and plant held for future use	806,705,000	722,088,000
Construction work in progress	16,538,000	16,790,000
Net utility plant	823,243,000	738,878,000
Deferred Charges and Other Assets:
Regulatory assets	133,962,000	139,738,000
Goodwill	226,665,000	226,665,000
Other deferred charges	8,850,000	8,273,000
Total deferred charges and other assets	369,477,000	374,676,000
Total Assets	1,240,241,000	1,162,431,000
Current Liabilities:
Short-term debt	5,000,000	0
Short-term debt - affiliate	22,700,000	29,400,000
Accounts payable	14,203,000	12,543,000
Affiliate payables	2,469,000	3,181,000
Accrued interest and taxes	28,574,000	23,778,000
Other current liabilities	2,271,000	8,999,000
Total current liabilities	75,217,000	77,901,000
Long-term Debt	365,667,000	336,036,000
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	217,945,000	190,197,000
Regulatory liabilities	40,662,000	46,038,000
Asset retirement obligations	848,000	782,000
Accrued pension liability and postretirement benefit cost	7,888,000	3,435,000
Other deferred credits	7,349,000	5,111,000
Total deferred credits and other liabilities	274,692,000	245,563,000
Total liabilities	715,576,000	659,500,000
Commitments and Contingencies (See Note 16)
Company common stockholders’ equity:
Common stock outstanding	64,000	64,000
Paid-in-capital	404,166,000	404,166,000
Accumulated other comprehensive income (loss), net of income taxes	0	(263,000)
Retained earnings	120,435,000	98,964,000
Total PNMR common stockholders’ equity	524,665,000	502,931,000
Total liabilities and stockholders' equity	1,240,241,000	1,162,431,000
Public Service Company of New Mexico [Member]
Current Assets:
Cash and cash equivalents	25,480,000	21,000
Accounts receivable, net of allowance for uncollectible accounts of $1,466 and $1,423 for PNMR and PNM	67,622,000	70,126,000
Unbilled revenues	54,140,000	48,992,000
Other receivables	37,622,000	52,964,000
Affiliate receivables	8,853,000	10,054,000
Materials, supplies, and fuel stock	60,859,000	64,520,000
Regulatory assets	43,980,000	19,394,000
Commodity derivative instruments	11,232,000	4,064,000
Income taxes receivable	6,105,000	4,030,000
Current portion of accumulated deferred income taxes	12,418,000	43,827,000
Other current assets	53,095,000	30,510,000
Total current assets	381,406,000	348,502,000
Other Property and Investments:
Investment in PVNGS lessor notes	9,538,000	32,200,000
Available-for-sale securities	250,145,000	226,855,000
Other investments	397,000	445,000
Non-utility property	96,000	976,000
Total other property and investments	260,176,000	260,476,000
Utility Plant:
Plant in service and plant held for future use	4,581,066,000	4,314,016,000
Less accumulated depreciation and amortization	1,486,406,000	1,402,531,000
Net plant in service and plant held for future use	3,094,660,000	2,911,485,000
Construction work in progress	169,673,000	107,344,000
Nuclear fuel, net of accumulated amortization of $44,507 and $47,347 for PNMR and PNM	77,796,000	77,602,000
Net utility plant	3,342,129,000	3,096,431,000
Deferred Charges and Other Assets:
Regulatory assets	357,045,000	384,217,000
Goodwill	51,632,000	51,632,000
Commodity derivative instruments	0	3,002,000
Other deferred charges	81,264,000	83,356,000
Total deferred charges and other assets	489,941,000	522,207,000
Total Assets	4,473,652,000	4,227,616,000
Current Liabilities:
Short-term debt	0	49,200,000
Short-term debt - affiliate	0	32,500,000
Current installments of long-term debt	214,300,000	75,000,000
Accounts payable	86,055,000	84,643,000
Customer deposits	12,555,000	13,456,000
Affiliate payables	18,232,000	20,498,000
Accrued interest and taxes	29,298,000	27,665,000
Regulatory liabilities	1,703,000	1,081,000
Commodity derivative instruments	1,209,000	2,699,000
Dividends declared	132,000	132,000
Other current liabilities	52,053,000	50,392,000
Total current liabilities	415,537,000	357,266,000
Long-term Debt	1,276,357,000	1,215,618,000
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	715,814,000	677,094,000
Regulatory liabilities	425,481,000	414,611,000
Asset retirement obligations	103,182,000	95,225,000
Accrued pension liability and postretirement benefit cost	102,850,000	76,611,000
Commodity derivative instruments	477,000	1,094,000
Other deferred credits	86,023,000	91,340,000
Total deferred credits and other liabilities	1,433,827,000	1,355,975,000
Total liabilities	3,125,721,000	2,928,859,000
Commitments and Contingencies (See Note 16)
Cumulative Preferred Stock of Subsidiary without mandatory redemption requirements ($100 stated value; 10,000,000 shares authorized; issued and outstanding 115,293 shares)	11,529,000	11,529,000
Company common stockholders’ equity:
Common stock outstanding	1,061,776,000	1,061,776,000
Accumulated other comprehensive income (loss), net of income taxes	(61,755,000)	(57,877,000)
Retained earnings	262,835,000	206,300,000
Total PNMR common stockholders’ equity	1,262,856,000	1,210,199,000
Non-controlling interest in Valencia	73,546,000	77,029,000
Total equity	1,336,402,000	1,287,228,000
Total liabilities and stockholders' equity	$ 4,473,652,000	$ 4,227,616,000

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Summary of Budgeted Construction Expenditures (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2014
Summary of Budgeted Construction Expenditures [Line Items]
2015	$ 569.2
2016	514.4
2017	443.5
2018	300.2
2019	380.0
Total	2,207.3
Public Service Company of New Mexico [Member]
Summary of Budgeted Construction Expenditures [Line Items]
2015	423.9
2016	402.3
2017	334.8
2018	180.6
2019	260.3
Total	1,601.9
Texas-New Mexico Power Company [Member]
Summary of Budgeted Construction Expenditures [Line Items]
2015	121.3
2016	92.8
2017	93.3
2018	105.9
2019	105.0
Total	518.3
Other Subsidiaries [Member]
Summary of Budgeted Construction Expenditures [Line Items]
2015	24.0
2016	19.3
2017	15.4
2018	13.7
2019	14.7
Total	87.1
San Juan Generating Station [Member] | Public Service Company of New Mexico [Member]
Summary of Budgeted Construction Expenditures [Line Items]
Environmental Upgrades Requirement Estimates	70.7
Budgeted Construction Expenditures Related to Replacement Capacity	268.4
Four Corners Units 4 and 5 (Coal) [Member] | Public Service Company of New Mexico [Member]
Summary of Budgeted Construction Expenditures [Line Items]
Environmental Upgrades Requirement Estimates	$ 80.0

XML

Financing Schedule of Long-term Debt (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Apr. 03, 2013	Mar. 06, 2013
Debt Instrument [Line Items]
Long-term Debt	$ 1,975,090	$ 1,745,420
Less current maturities	333,066	75,000
Long-term Debt, Excluding Current Maturities	1,642,024	1,670,420
Unsecured Debt [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		9.25%
Unsecured Debt [Member] | Senior unsecured notes, 9.25% due 2015 [Member]
Debt Instrument [Line Items]
Unsecured Long-term Debt, Noncurrent	118,766	118,766
Public Service Company of New Mexico [Member]
Debt Instrument [Line Items]
Long-term Debt	1,490,657	1,290,618
Less current maturities	214,300	75,000
Long-term Debt, Excluding Current Maturities	1,276,357	1,215,618
Public Service Company of New Mexico [Member] | Senior Unsecured Notes, Pollution Control Revenue Bonds [Member] | 4.875% due 2033 [Member]
Debt Instrument [Line Items]
Unsecured Long-term Debt, Noncurrent	146,000	146,000
Debt Instrument, Interest Rate, Stated Percentage	4.875%	4.875%
Public Service Company of New Mexico [Member] | Senior Unsecured Notes, Pollution Control Revenue Bonds [Member] | 6.25% due 2038 [Member]
Debt Instrument [Line Items]
Unsecured Long-term Debt, Noncurrent	36,000	36,000
Debt Instrument, Interest Rate, Stated Percentage	6.25%	6.25%
Public Service Company of New Mexico [Member] | Senior Unsecured Notes, Pollution Control Revenue Bonds [Member] | 4.75% due 2040, mandatory tender at June 1, 2017 [Member]
Debt Instrument [Line Items]
Unsecured Long-term Debt, Noncurrent	37,000	37,000
Debt Instrument, Interest Rate, Stated Percentage	4.75%	4.75%
Public Service Company of New Mexico [Member] | Senior Unsecured Notes, Pollution Control Revenue Bonds [Member] | 5.20% due 2040, mandatory tender at June 1, 2020 [Member]
Debt Instrument [Line Items]
Unsecured Long-term Debt, Noncurrent	40,045	40,045
Debt Instrument, Interest Rate, Stated Percentage	5.20%	5.20%
Public Service Company of New Mexico [Member] | Senior Unsecured Notes, Pollution Control Revenue Bonds [Member] | 5.90% due 2040 [Member]
Debt Instrument [Line Items]
Unsecured Long-term Debt, Noncurrent	255,000	255,000
Debt Instrument, Interest Rate, Stated Percentage	5.90%	5.90%
Public Service Company of New Mexico [Member] | Senior Unsecured Notes, Pollution Control Revenue Bonds [Member] | 6.25% due 2040 [Member]
Debt Instrument [Line Items]
Unsecured Long-term Debt, Noncurrent	11,500	11,500
Debt Instrument, Interest Rate, Stated Percentage	6.25%	6.25%
Public Service Company of New Mexico [Member] | Senior Unsecured Notes, Pollution Control Revenue Bonds [Member] | 2.54% due 2042, mandatory tender at June 1, 2017 [Member]
Debt Instrument [Line Items]
Unsecured Long-term Debt, Noncurrent	20,000	20,000
Debt Instrument, Interest Rate, Stated Percentage	2.54%	2.54%
Public Service Company of New Mexico [Member] | Senior Unsecured Notes, Pollution Control Revenue Bonds [Member] | 4.00% due 2043, mandatory tender at June 1, 2015 [Member]
Debt Instrument [Line Items]
Unsecured Long-term Debt, Noncurrent	39,300	39,300
Debt Instrument, Interest Rate, Stated Percentage	4.00%	4.00%
Public Service Company of New Mexico [Member] | Senior Unsecured Notes, Pollution Control Revenue Bonds [Member] | 5.20% due 2043, mandatory tender at June 1, 2020 [Member]
Debt Instrument [Line Items]
Unsecured Long-term Debt, Noncurrent	21,000	21,000
Debt Instrument, Interest Rate, Stated Percentage	5.20%	5.20%
Public Service Company of New Mexico [Member] | Unsecured Debt [Member] | 7.95% due 2018 [Member]
Debt Instrument [Line Items]
Unsecured Long-term Debt, Noncurrent	350,000	350,000
Debt Instrument, Interest Rate, Stated Percentage	7.95%	7.95%
Public Service Company of New Mexico [Member] | Unsecured Debt [Member] | 7.50% due 2018 [Member]
Debt Instrument [Line Items]
Unsecured Long-term Debt, Noncurrent	100,025	100,025
Debt Instrument, Interest Rate, Stated Percentage	7.50%	7.50%
Public Service Company of New Mexico [Member] | Unsecured Debt [Member] | 5.35% due 2021 [Member]
Debt Instrument [Line Items]
Unsecured Long-term Debt, Noncurrent	160,000	160,000
Debt Instrument, Interest Rate, Stated Percentage	5.35%	5.35%
Public Service Company of New Mexico [Member] | Unsecured Debt [Member] | PNM 2014 Term Loan Agreement [Member]
Debt Instrument [Line Items]
Long-term Debt	0	75,000
Public Service Company of New Mexico [Member] | Unsecured Debt [Member] | PNM Term Loan Agreement due 2015 [Member]
Debt Instrument [Line Items]
Long-term Debt	175,000	0
Public Service Company of New Mexico [Member] | Unsecured Debt [Member] | PNM Multi-Draw Term Loan Agreement due 2016 [Member]
Debt Instrument [Line Items]
Long-term Debt	100,000	0
Public Service Company of New Mexico [Member] | Other [Member]
Debt Instrument [Line Items]
Unamortized premiums (discounts)	(213)	(252)
Texas-New Mexico Power Company [Member]
Debt Instrument [Line Items]
Long-term Debt	365,667	336,036
Less current maturities	0	0
Long-term Debt, Excluding Current Maturities	365,667	336,036
Texas-New Mexico Power Company [Member] | First Mortgage Bonds [Member] | 2011 Term Loan Agreement, due 2014 [Member]
Debt Instrument [Line Items]
Long-term Debt	0	50,000
Texas-New Mexico Power Company [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds Due 2014, Series 2009A, at 9 point 50 percent [Member]
Debt Instrument [Line Items]
Unsecured Long-term Debt, Noncurrent	172,302	172,302
Debt Instrument, Interest Rate, Stated Percentage	9.50%	9.50%	9.50%	9.50%
Texas-New Mexico Power Company [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds 6 Point 95 Percent, due 2043, Series 2013A [Member]
Debt Instrument [Line Items]
Unsecured Long-term Debt, Noncurrent	93,198	93,198
Debt Instrument, Interest Rate, Stated Percentage	6.95%	6.95%	6.95%	6.95%
Texas-New Mexico Power Company [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds Due 2024, Series 2014A, at 4 point 03 percent [Member] [Member]
Debt Instrument [Line Items]
Unsecured Long-term Debt, Noncurrent	80,000	0
Debt Instrument, Interest Rate, Stated Percentage	4.03%
Texas-New Mexico Power Company [Member] | Other [Member]
Debt Instrument [Line Items]
Unamortized premiums (discounts)	(20,167)	(20,536)
PNMR [Member]
Debt Instrument [Line Items]
Less current maturities	118,766	0
Long-term Debt, Excluding Current Maturities	$ 0	$ 118,766
PNMR [Member] | Unsecured Debt [Member] | Senior unsecured notes, 9.25% due 2015 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	9.25%	9.25%

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Accumulated Other Comprehensive Income (Loss) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning Balance	$ (58,140)	$ (81,630)	$ (66,856)
Amounts reclassified from AOCI (pre-tax)	(8,152)	(5,385)	(32,476)
Income tax impact of amounts reclassified	3,234	2,137	12,865
Other OCI changes (pre-tax)	2,038	44,276	8,036
Income tax impact of other OCI changes	(735)	(17,538)	(3,199)
Total Other Comprehensive Income (Loss)	(3,615)	23,490	(14,774)
Ending Balance	(61,755)	(58,140)	(81,630)
Percentage of Pension Liability Adjustment Capitalized into Construction Work In Process	24.40%	18.70%
Percentage of Pension Liability Adjustment Capitalized into Other Accounts	2.00%	3.00%
Public Service Company of New Mexico [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning Balance	(57,877)	(81,414)	(66,798)
Amounts reclassified from AOCI (pre-tax)	(8,710)	(5,592)	(32,658)
Income tax impact of amounts reclassified	3,429	2,210	12,930
Other OCI changes (pre-tax)	2,191	44,555	8,464
Income tax impact of other OCI changes	(788)	(17,636)	(3,352)
Total Other Comprehensive Income (Loss)	(3,878)	23,537	(14,616)
Ending Balance	(61,755)	(57,877)	(81,414)
Texas-New Mexico Power Company [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning Balance	(263)	(216)	(58)
Amounts reclassified from AOCI (pre-tax)	558	207	182
Income tax impact of amounts reclassified	(195)	(73)	(65)
Other OCI changes (pre-tax)	(153)	(279)	(428)
Income tax impact of other OCI changes	53	98	153
Total Other Comprehensive Income (Loss)	263	(47)	(158)
Ending Balance	0	(263)	(216)
Accumulated Net Unrealized Investment Gain (Loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning Balance	25,748	16,406	15,634
Amounts reclassified from AOCI (pre-tax)	(13,862)	(11,956)	(37,269)
Income tax impact of amounts reclassified	5,461	4,734	14,755
Other OCI changes (pre-tax)	17,473	27,419	38,548
Income tax impact of other OCI changes	(6,812)	(10,855)	(15,262)
Total Other Comprehensive Income (Loss)	2,260	9,342	772
Ending Balance	28,008	25,748	16,406
Accumulated Net Unrealized Investment Gain (Loss) [Member] | Public Service Company of New Mexico [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning Balance	25,748	16,406	15,634
Amounts reclassified from AOCI (pre-tax)	(13,862)	(11,956)	(37,269)
Income tax impact of amounts reclassified	5,461	4,734	14,755
Other OCI changes (pre-tax)	17,473	27,419	38,548
Income tax impact of other OCI changes	(6,812)	(10,855)	(15,262)
Total Other Comprehensive Income (Loss)	2,260	9,342	772
Ending Balance	28,008	25,748	16,406
Accumulated Net Unrealized Investment Gain (Loss) [Member] | Texas-New Mexico Power Company [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning Balance	0	0	0
Amounts reclassified from AOCI (pre-tax)	0	0	0
Income tax impact of amounts reclassified	0	0	0
Other OCI changes (pre-tax)	0	0	0
Income tax impact of other OCI changes	0	0	0
Total Other Comprehensive Income (Loss)	0	0	0
Ending Balance	0	0	0
Accumulated Defined Benefit Plans Adjustment [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning Balance	(83,625)	(97,820)	(82,432)
Amounts reclassified from AOCI (pre-tax)	5,152	6,364	4,611
Income tax impact of amounts reclassified	(2,032)	(2,524)	(1,825)
Other OCI changes (pre-tax)	(15,282)	17,136	(30,084)
Income tax impact of other OCI changes	6,024	(6,781)	11,910
Total Other Comprehensive Income (Loss)	(6,138)	14,195	(15,388)
Ending Balance	(89,763)	(83,625)	(97,820)
Accumulated Defined Benefit Plans Adjustment [Member] | Public Service Company of New Mexico [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning Balance	(83,625)	(97,820)	(82,432)
Amounts reclassified from AOCI (pre-tax)	5,152	6,364	4,611
Income tax impact of amounts reclassified	(2,032)	(2,524)	(1,825)
Other OCI changes (pre-tax)	(15,282)	17,136	(30,084)
Income tax impact of other OCI changes	6,024	(6,781)	11,910
Total Other Comprehensive Income (Loss)	(6,138)	14,195	(15,388)
Ending Balance	(89,763)	(83,625)	(97,820)
Accumulated Defined Benefit Plans Adjustment [Member] | Texas-New Mexico Power Company [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning Balance	0	0	0
Amounts reclassified from AOCI (pre-tax)	0	0	0
Income tax impact of amounts reclassified	0	0	0
Other OCI changes (pre-tax)	0	0	0
Income tax impact of other OCI changes	0	0	0
Total Other Comprehensive Income (Loss)	0	0	0
Ending Balance	0	0	0
Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning Balance	(263)	(216)	(58)
Amounts reclassified from AOCI (pre-tax)	558	207	182
Income tax impact of amounts reclassified	(195)	(73)	(65)
Other OCI changes (pre-tax)	(153)	(279)	(428)
Income tax impact of other OCI changes	53	98	153
Total Other Comprehensive Income (Loss)	263	(47)	(158)
Ending Balance	0	(263)	(216)
Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member] | Public Service Company of New Mexico [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning Balance	0	0	0
Amounts reclassified from AOCI (pre-tax)	0	0	0
Income tax impact of amounts reclassified	0	0	0
Other OCI changes (pre-tax)	0	0	0
Income tax impact of other OCI changes	0	0	0
Total Other Comprehensive Income (Loss)	0	0	0
Ending Balance	0	0	0
Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member] | Texas-New Mexico Power Company [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning Balance	(263)	(216)	(58)
Amounts reclassified from AOCI (pre-tax)	558	207	182
Income tax impact of amounts reclassified	(195)	(73)	(65)
Other OCI changes (pre-tax)	(153)	(279)	(428)
Income tax impact of other OCI changes	53	98	153
Total Other Comprehensive Income (Loss)	263	(47)	(158)
Ending Balance	$ 0	$ (263)	$ (216)

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Regulatory Assets and Liabilities (Tables)

12 Months Ended

Dec. 31, 2014

Public Service Company of New Mexico [Member]

Regulatory Assets [Line Items]

Regulatory Assets and Liabilities [Table Text Block]

Regulatory assets and liabilities reflected in the Consolidated Balance Sheets are presented below.

PNM

	December 31,
	2014			2013
Assets:	(In thousands)
Current:
FPPAC	$	43,980		$	19,394
Non-Current:
Coal mine reclamation costs	34,224			40,144
Deferred income taxes	63,645			61,850
Loss on reacquired debt	25,439			27,490
Pension and OPEB	222,545			206,691
FPPAC	—			25,386
Renewable energy costs	5,263			13,311
Other	5,929			9,345
	357,045			384,217
Total regulatory assets	$	401,025		$	403,611
Liabilities:
Current:
Other	$	(1,703	)	$	(1,081	)
Non-Current:
Cost of removal	(277,148		)	(266,075		)
Deferred income taxes	(75,941		)	(80,495		)
AROs	(35,834		)	(37,567		)
Renewable energy tax benefits	(24,854		)	(26,011		)
Other	(11,704		)	(4,463		)
	(425,481		)	(414,611		)
Total regulatory liabilities	$	(427,184	)	$	(415,692	)

Texas-New Mexico Power Company [Member]

Regulatory Assets [Line Items]

Regulatory Assets and Liabilities [Table Text Block]

TNMP

	December 31,
	2014			2013
Assets:	(In thousands)
Current:
Transmission cost recovery factor	$	2,482		$	4,250
Other	1,393			772
	3,875			5,022
Non-Current:
CTC, including carrying charges	55,292			63,606
Deferred income taxes	10,556			10,868
Pension	23,803			19,938
Loss on reacquired debt	36,703			38,616
AMS retirement costs	6,453			5,083
Other	1,155			1,627
	133,962			139,738
Total regulatory assets	$	137,837		$	144,760
Liabilities:
Non-Current:
Cost of removal	$	(29,391	)	$	(30,863	)
Deferred income taxes	(3,923		)	(4,563		)
AMS surcharge	(5,227		)	(7,251		)
OPEB	(2,121		)	(3,361		)
Total regulatory liabilities	$	(40,662	)	$	(46,038	)

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Fair Value of Derivative and Other Financial Instruments, Statement of Earnings Information (Details) (Commodity Contract [Member], Economic hedges [Member], USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss)	$ 5,084	$ 2,836	$ 5,708
Electric operating revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss)	4,491	1,727	6,168
Cost of energy [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss)	$ 593	$ 1,109	$ (460)

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Construction Program and Jointly-Owned Electric Generating Plants

12 Months Ended

Dec. 31, 2014

Construction Program and Jointly-Owned Electric Generating Plants [Abstract]

Construction Program and Jointly-Owned Electric Generating Plants

Construction Program and Jointly-Owned Electric Generating Plants

PNM is a participant in several jointly-owned power plant projects. The primary operating or participation agreements for the joint projects expire in July 2016 for Four Corners, July 2022 for SJGS, December 2046 for Luna, and November 2047 for PVNGS.

PNM’s expenditures for additions to utility plant were $316.8 million in 2014, including expenditures on jointly-owned projects. TNMP does not participate in the ownership or operation of any generating plants, but incurred expenditures for additions to utility plant of $127.2 million during 2014. On a consolidated basis, PNMR’s expenditures for additions to utility plant were $460.7 million in 2014.

Joint Projects

Under the agreements for the jointly-owned projects, PNM has an undivided interest in each asset and liability of the project and records its pro-rata share of each item in the corresponding asset and liability account on PNM’s Consolidated Balance Sheets. Likewise, PNM records its pro-rata share of each item of operating and maintenance expenses for its jointly-owned plants within the corresponding operating expense account in its Consolidated Statements of Earnings. PNM is responsible for financing its share of the capital and operating costs of the joint projects.

At December 31, 2014, PNM’s interests and investments in jointly-owned generating facilities are:

Station (Fuel Type)	Plant in Service		Accumulated Depreciation			Construction Work in Progress			Composite Interest
	(In thousands)
SJGS (Coal)	$	1,009,378	$	(423,364	)	$	25,551		46.30	%
PVNGS (Nuclear) (1)	$	533,702	$	(152,273	)	$	42,334		10.20	%
Four Corners Units 4 and 5 (Coal)	$	162,111	$	(101,007	)	$	8,253		13.00	%
Luna (Gas)	$	66,169	$	(20,297	)	$	(136	)	33.33	%

⁽¹⁾  Includes interest in PVNGS Unit 3, interest in common facilities for all PVNGS units, and owned interests in PVNGS Units 1 and 2.

San Juan Generating Station

PNM operates and jointly owns SJGS. SJGS Units 1 and 2 are owned on a 50% shared basis with Tucson. SJGS Unit 3 is owned 50% by PNM, 41.8% by SCPPA, and 8.2% by Tri-State. SJGS Unit 4 is owned 38.457% by PNM, 28.8% by M-S-R Public Power Agency, 10.04% by the City of Anaheim, California, 8.475% by the City of Farmington, New Mexico, 7.2% by the County of Los Alamos, New Mexico, and 7.028% by UAMPS. See Note 16 for additional information about SJGS, including the potential restructuring of SJGS ownership.

Palo Verde Nuclear Generating Station

PNM is a participant in the three units of PVNGS, also known as the Arizona Nuclear Power Project, with APS (the operating agent), SRP, EPE, SCE, SCPPA, and The Department of Water and Power of the City of Los Angeles. PNM has a 10.2% undivided interest in PVNGS, with portions of its interests in Units 1 and 2 held under leases. See Note 7 for additional information concerning the PVNGS leases, including PNM’s notices that it will exercise its option to purchase the assets underlying certain of the leases at the expiration of the leases on January 15, 2016.

Operation of each of the three PVNGS units requires an operating license from the NRC. The NRC issued full power operating licenses for Unit 1 in June 1985, Unit 2 in April 1986, and Unit 3 in November 1987. The full power operating licenses were originally for a period of 40 years and authorize APS, as operating agent for PVNGS, to operate the three PVNGS units. On April 21, 2011, the NRC approved extensions in the operating licenses for the plants for 20 years through June 2045 for Unit 1, April 2046 for Unit 2, and November 2047 for Unit 3. In April 2010, APS entered into a Municipal Effluent Purchase and Sale Agreement that provides effluent water rights necessary for cooling purposes at PVNGS through 2050.

Four Corners Power Plant

PNM is a participant in two units of Four Corners with APS (the operating agent), EPE, SRP, and Tucson. PNM has a 13.0% undivided interest in Units 4 and 5 of Four Corners. The Four Corners plant site is leased from the Navajo Nation and is also subject to an easement from the federal government. APS, on behalf of the Four Corners participants, negotiated amendments to an existing facility lease with the Navajo Nation, which extends the Four Corners leasehold interest from 2016 to 2041. 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 addition, installation of SCR control technology at Four Corners requires a PSD permit, which APS received in December 2014.  PNM cannot predict whether the 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 PNM and the other Four Corners owners. See Note 16 for additional information about Four Corners.

Luna Energy Facility

Luna is a combined-cycle power plant near Deming, New Mexico. Luna is owned equally by PNM, Tucson, and Samchully Power & Utilities 1, LLC. The operation and maintenance of the facility has been contracted to North American Energy Services.

Construction Program

The Company anticipates making substantial capital expenditures for the construction and acquisition of utility plant and other property and equipment. An unaudited summary of the budgeted construction expenditures, including expenditures for jointly-owned projects, and nuclear fuel, is as follows:

	2015		2016		2017		2018		2019		Total
					(In millions)
PNM	$	423.9	$	402.3	$	334.8	$	180.6	$	260.3	$	1,601.9
TNMP	121.3		92.8		93.3		105.9		105.0		518.3
Corporate and Other	24.0		19.3		15.4		13.7		14.7		87.1
Total PNMR	$	569.2	$	514.4	$	443.5	$	300.2	$	380.0	$	2,207.3

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 $70.7 million related to environmental upgrades at SJGS to address regional haze and $268.4 million related to the identified sources of replacement capacity under the revised plan for compliance described in Note 16. The above 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, environmental upgrades at Four Corners estimated to be $80.0 million, the purchase of the leased portion of the EIP, and the purchase of the assets underlying three of the PVNGS Unit 2 leases at the expiration of those leases.

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Financing (Tables)

12 Months Ended

Dec. 31, 2014

Debt Disclosure [Abstract]

Schedule of Short-term Debt

Short-term debt outstanding consists of:

	December 31,
Short-term Debt	2014		2013
	(In thousands)
PNM:
Revolving Credit Facility	$	—	$	49,200
PNM New Mexico Credit Facility	—		—
TNMP Revolving Credit Facility	5,000		—
PNMR
Revolving Credit Facility	600		—
PNMR Term Loan Agreement	100,000		100,000
	$	105,600	$	149,200

Schedule of Long-term Debt Instruments

Information concerning long-term debt outstanding is as follows:

	December 31,
Long-term Debt	2014			2013
	(In thousands)
PNM Debt
Senior Unsecured Notes, Pollution Control Revenue Bonds:
4.875% due 2033	$	146,000		$	146,000
6.25% due 2038	36,000			36,000
4.75% due 2040, mandatory tender at June 1, 2017	37,000			37,000
5.20% due 2040, mandatory tender at June 1, 2020	40,045			40,045
5.90% due 2040	255,000			255,000
6.25% due 2040	11,500			11,500
2.54% due 2042, mandatory tender at June 1, 2017	20,000			20,000
4.00% due 2043, mandatory tender at June 1, 2015	39,300			39,300
5.20% due 2043, mandatory tender at June 1, 2020	21,000			21,000
Senior Unsecured Notes:
7.95% due 2018	350,000			350,000
7.50% due 2018	100,025			100,025
5.35% due 2021	160,000			160,000
PNM Term Loan Agreement due 2014	—			75,000
PNM Term Loan Agreement due 2015	175,000			—
PNM Multi-draw Term Loan due 2016	100,000			—
Unamortized premiums (discounts)	(213		)	(252		)
	1,490,657			1,290,618
Less current maturities	214,300			75,000
	1,276,357			1,215,618
TNMP Debt
First Mortgage Bonds:
2011 Term Loan Agreement, due 2014	—			50,000
9.50% due 2019, Series 2009A	172,302			172,302
6.95% due 2043, Series 2013A	93,198			93,198
4.03% due 2024, Series 2014A	80,000			—
Unamortized premiums (discounts)	20,167			20,536
	365,667			336,036
Less current maturities	—			—
	365,667			336,036
PNMR Debt
Senior unsecured notes, 9.25% due 2015	118,766			118,766
Less current maturities	118,766			—
	—			118,766
Total Consolidated PNMR Debt	1,975,090			1,745,420
Less current maturities	333,066			75,000
	$	1,642,024		$	1,670,420

Schedule of Maturities of Long-term Debt

Reflecting mandatory tender dates, long-term debt matures as follows:

	PNMR		PNM		TNMP		PNMR Consolidated
	(In thousands)
2015	$	118,766	$	214,300	$	—	$	333,066
2016	—		100,000		—		100,000
2017	—		57,000		—		57,000
2018	—		450,025		—		450,025
2019	—		—		172,302		172,302
Thereafter	—		669,545		173,198		842,743
Total	$	118,766	$	1,490,870	$	345,500	$	1,955,136

Borrowing Arrangements Between PNMR and its Subsidiaries

PNMR has one-year intercompany loan agreements with its subsidiaries. Individual subsidiary loan agreements vary in amount up to $100.0 million and have either reciprocal or non-reciprocal terms. Interest charged to the subsidiaries is equivalent to interest paid by PNMR on its short-term borrowings. As of December 31, 2014 and 2013, PNM had outstanding borrowings of zero and $32.5 million and TNMP had outstanding borrowings of $22.7 million and $29.4 million from PNMR. At February 20, 2015, PNM and TNMP had borrowings of zero and $17.3 million from PNMR.

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Related Party Transactions (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Service billings [Member] | PNMR to PNM [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	$ 86,871	$ 92,597	$ 99,986
Service billings [Member] | PNMR to TNMP [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	28,349	28,937	29,110
Service billings [Member] | PNM to TNMP [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	524	562	595
Service billings [Member] | TNMP to PNMR [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	31	7	15
Income tax sharing payments [Member] | PNMR to PNM [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	0	77,433	63,114
Income tax sharing payments [Member] | PNMR to TNMP [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	0	0	1,951
Income tax sharing payments [Member] | TNMP to PNMR [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	0	3,643	0
Interest charges [Member] | TNMP to PNMR [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	309	481	137
Interest charges [Member] | PNM to PNMR [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	$ 65	$ 4	$ 1

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Commitments and Contingencies

12 Months Ended

Dec. 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 also is subject to federal, state, and local environmental laws and regulations and periodically participates in the investigation and remediation of various sites. In addition, the Company occasionally enters into financial commitments in connection with its business operations. Also, the Company is involved in various legal and regulatory (Note 17) proceedings in the normal course of its business. It is not possible at this time for the Company to determine fully the effect of all litigation and other legal and regulatory proceedings on its financial position, results of operations, or cash flows.

With respect to some of the items listed below, the Company has determined that a loss is not probable or that, to the extent probable, cannot be reasonably estimated. In some cases, the Company is not able to predict with any degree of certainty the range of possible loss that could be incurred. Nevertheless, the Company assesses legal and regulatory matters based on current information and makes judgments concerning their potential outcome, giving due consideration to the nature of the claim, the amount and nature of 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. Except as otherwise disclosed, the Company does not expect that any known lawsuits, environmental costs, and commitments will have a material effect on its financial condition, results of operations, or cash flows.

Commitments and Contingencies Related to the Environment

PVNGS Decommissioning Funding

PNM has a program for funding its share of decommissioning costs for PVNGS, including portions held under leases. The nuclear decommissioning funding program is invested in equities and fixed income instruments in qualified and non-qualified trusts. PNM funded $4.9 million, $4.9 million, and $2.6 million for the years ended December 31, 2014, 2013, and 2012 into the qualified and non-qualified trust funds. The estimated market value of the trusts at December 31, 2014 and 2013 was $244.6 million and $222.5 million.

Nuclear Spent Fuel and Waste Disposal

Nuclear power plant operators are required to enter into spent fuel disposal contracts with the DOE that require the DOE to accept and dispose of all spent nuclear fuel and other high-level radioactive wastes generated by domestic power reactors. Although the Nuclear Waste Policy Act required the DOE to develop a permanent repository for the storage and disposal of spent nuclear fuel by 1998, the DOE announced that it would not be able to open the repository by 1998 and sought to excuse its performance of these requirements. In November 1997, the 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 alleged 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. APS and DOE entered into a settlement agreement, and on October 7, 2014, APS received a settlement payment of $57.4 million for costs paid through June 30, 2011, for DOE’s failure to accept spent nuclear fuel generated at PVNGS. PNM’s share of the settlement is $5.9 million, substantially all of which is credited back to PNM’s customers. The settlement agreement also establishes a process for the payment of subsequent claims through December 30, 2016. Under the settlement agreement, APS must submit claims annually for payment of allowable costs. On October 31, 2014, APS submitted a $42.5 million claim for costs paid between July 1, 2011, and June 30, 2014. PNM’s share of the settlement would amount to $4.3 million, will be recorded when a final determination of the claim is made, which is anticipated to be in March 2015, and would primarily be credited back to PNM’s customers. The settlement agreement terminates upon payment of costs paid through December 31, 2016, unless extended by mutual written agreement.

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 December 31, 2014 and 2013, PNM had a liability for interim storage costs of $12.3 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 and temporary storage rule (“Waste Confidence Decision”).

The D.C. Circuit found that the Waste Confidence Decision update constituted a major federal action, which, consistent with NEPA, requires either an environmental impact statement or a finding of no significant impact from the NRC’s actions.  The D.C. Circuit found that the NRC’s evaluation of the environmental risks from spent nuclear fuel was deficient, and therefore remanded the Waste Confidence Decision update for further action consistent with NEPA.

On September 6, 2012, the NRC commissioners issued a directive to the NRC staff to proceed with development of a generic EIS to support an updated Waste Confidence Decision.  The NRC commissioners also directed the staff to establish a schedule to publish a final rule and environmental impact study within 24 months of September 6, 2012. 

In September 2013, the NRC issued its draft generic EIS to support an updated Waste Confidence Decision. On August 26, 2014, the NRC approved a final rule on the environmental effects of continued storage of spent nuclear fuel. The continued storage rule adopted the findings of the generic EIS regarding the environmental impacts of storing spent fuel at any reactor site after the reactor’s licensed period of operations. As a result, those generic impacts do not need to be re-analyzed in the environmental reviews for individual licenses. Although PVNGS had not been involved in any licensing actions affected by the D.C. Circuit’s June 8, 2012, decision, the NRC lifted its suspension on final licensing actions on all nuclear power plant licenses and renewals that went into effect when the D.C. Circuit issued its June 2012 decision. The August 2014 final rule has been subject to continuing legal challenges before the NRC and the United States Court of Appeals.

PVNGS has sufficient capacity at its on-site ISFSI to store all of the nuclear fuel that will be irradiated during the initial operating license period, which ends in December 2027.  Additionally, PVNGS has sufficient capacity at its on-site ISFSI to store a portion of the fuel that will be irradiated during the period of extended operation, which ends in November 2047.  If uncertainties regarding the United States government’s obligation to accept and store spent fuel are not favorably resolved, APS will evaluate alternative storage solutions that may obviate the need to expand the ISFSI to accommodate all of the fuel that will be irradiated during the period of extended operation.

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. 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 DOE’s intention to suspend collecting annual fees for nuclear waste disposal from nuclear power plant operators. On January 3, 2014, the DOE notified Congress of its intention to suspend collection of the one-mill fee, subject to Congress’ disapproval. On May 16, 2014, the DOE adjusted the fee to zero. 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 fee applicable to PVNGS Units 1 and 2 is being recovered by PNM in its retail rates. PNM anticipates challenges to this action and is unable to predict its ultimate outcome.

The Clean Air Act

Regional Haze

In 1999, EPA developed a regional haze program and regional haze rules under the CAA. The rule directs each of the 50 states to address regional haze. Pursuant to the CAA, states have the primary role to regulate visibility requirements by promulgating SIPs. States are required to establish goals for improving visibility in national parks and wilderness areas (also known as Class I areas) and to develop long-term strategies for reducing emissions of air pollutants that cause visibility impairment in their own states and for preventing degradation in other states. States must establish a series of interim goals to ensure continued progress. The first planning period specifies setting reasonable progress goals for improving visibility in Class I areas by the year 2018. In July 2005, EPA promulgated its final regional haze rule guidelines for states to conduct BART determinations for certain covered facilities, including utility boilers, built between 1962 and 1977 that have the potential to emit more than 250 tons per year of visibility impairing pollution. If it is demonstrated that the emissions from these sources cause or contribute to visibility impairment in any Class I area, then BART must be installed by 2018.

SJGS

BART 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 required installation of selective catalytic reduction technology (“SCR”) on all four units by September 21, 2016. In November 2012, EPA approved all components of the SIP, except for the NOx BART determination for SJGS, which continued to be subject to the FIP.

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. These parties also formally asked EPA to stay the effective date of the rule. Several environmental groups intervened in support of EPA. The parties file periodic status reports with the Tenth Circuit, but proceedings are being held in abeyance as agreed to by the parties.

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 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.

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. NMED developed a RSIP and submitted it to the EIB for approval in May 2013. The EIB approved the RSIP in September 2013 and it was submitted to EPA for approval in October 2013. Final rules approving the RSIP and withdrawing the FIP were published in the Federal Register on October 9, 2014 and became effective on November 10, 2014.

Conversion of SJGS Units 1 and 4 to balanced draft technology (“BDT”) is included with the installation of SNCRs in the RSIP. The requirement to install BDT was made binding and enforceable in the NSR permit that accompanied the RSIP submitted to the EPA. EPA’s rule approving the RSIP specifically references the NSR permit by including a condition that requires “modification of the fan systems on Units 1 and 4 to achieve ‘balanced’ draft configuration ….”

Implementation Activities – Due to the compliance deadline set forth in the FIP, PNM took steps to commence installation of SCRs at SJGS. In October 2012, PNM entered into a contract with an engineering, procurement, and construction contractor to install SCRs on behalf of the SJGS owners. At the time PNM entered into the contract, PNM estimated the total cost to install SCRs on all four units of SJGS to be between approximately $824 million and $910 million. The costs for the project to install SCRs would encompass installation of BDT equipment to comply with the NAAQS requirements described below. The construction contract was terminated in December 2014 following approval of the RSIP by EPA.

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 BDT 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 above estimates include gross receipts taxes, AFUDC, and other PNM costs. Based upon its current SJGS ownership interest, PNM’s share of the costs described above would be about 46.3%.

Following the February 2013 development of the alternative BART compliance plan, PNM began taking steps to prepare for the potential installation of SNCR and BDT equipment on Units 1 and 4 due to the long lead times on certain equipment purchases. In May 2013, PNM entered into an equipment and related services contract with a technology provider. In July 2014, PNM entered into a contract for management of the construction and in September 2014 entered into a construction and procurement contract.

NMPRC Filing –On December 20, 2013, PNM made a filing with the NMPRC requesting certain approvals necessary to effectuate the RSIP. In this filing, PNM requested:

• Permission to retire SJGS Units 2 and 3 at December 31, 2017 and to recover over 20 years their net book value at that date along with a regulated return on those costs

• A CCN to include PNM’s ownership of PVNGS Unit 3, amounting to 134 MW, as a resource to serve New Mexico retail customers at a proposed value of $2,500 per KW, effective January 1, 2018

• An order allowing cost recovery for PNM’s share of the installation of SNCR and BDT equipment to comply with NAAQS requirements on SJGS Units 1 and 4, not to exceed a total cost of $82 million

• 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 have been a reduction of 340 MW in PNM’s ownership of SJGS

The December 20, 2013 NMPRC filing identified 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. PNM received approval to construct the 40 MW of solar PV facilities in its 2015 Renewable Energy Plan. See Note 17. Specific approvals to acquire the gas facility and the treatment of associated costs will be made in future filings. PNM estimates the cost of these identified resources would be approximately $268.4 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 would 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 SNCR and BDT equipment.

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 RSIP. 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. In July 2014, PNM filed a notice with the NMPRC regarding the status of the negotiations among the SJGS participants, including that the SJGS participants reached non-binding agreements in principle on the ownership restructuring of SJGS and that PNM was proposing to acquire 132 MW of SJGS Unit 4 effective December 31, 2017, rather than exchanging 78 MW of capacity in SJGS Unit 3 for 78 MW in SJGS Unit 4 as contemplated in the December 20, 2013 NMPRC filing. Those agreements are memorialized in the resolution and term sheet described below.

On October 1, 2014, PNM, the staff of the NMPRC, the NMAG, New Mexico Independent Power Producers, Western Resource Advocates, and Renewable Energy Industries Association of New Mexico filed a stipulation with the NMPRC. NMIEC subsequently joined the agreement. New Mexico Independent Power Producers, Western Resource Advocates, and Renewable Energy Industries Association of New Mexico have since withdrawn support of the stipulation. Statements of opposition were filed by other intervenors.

Under the terms of the stipulation, PNM:

• Would be authorized to abandon SJGS Units 2 and 3 effective December 31, 2017

• Would be granted a CCN for an additional 132 MW of SJGS Unit 4 capacity as of January 1, 2018 with a rate base value of $26 million plus any reasonable and prudent investments made in Unit 4 prior to that date; PNM would reduce its carrying value of SJGS Unit 3 by this $26 million

• Would recover 50% of the estimated $231 million undepreciated value in SJGS Units 2 and 3 at December 31, 2017; recovery would be over a twenty year period and would include a return on the unrecovered amount at PNM’s WACC; at December 31, 2014, PNM’s net book value of its current ownership share of SJGS Units 2 and 3 was approximately $282 million

• Would be granted a CCN for 134 MW of PVNGS Unit 3 at a January 1, 2018 value of $221.1 million ($1,650 per KW); PNM’s ownership share of PVNGS would also be subject to a capacity factor performance threshold of 75% for a seven year period beginning January 1, 2018; subject to certain exceptions, if the capacity factor is not achieved in any year, PNM would refund the cost of replacement power through its FPPAC; at December 31, 2014, PNM’s net book value of PVNGS Unit 3 was approximately $144 million

• Would file for recovery of its reasonable and prudent costs of installation of the SNCR and BDT equipment requirements at SJGS Units 1 and 4 up to $90.6 million

• Would not be allowed to recover a total of approximately $20 million of increased operations and maintenance costs associated with the agreement reached with the remaining SJGS participants, additional fuel handling expenses, and certain other costs incurred in efforts to comply with the CAA

A public hearing in the NMPRC case was held in January 2015. In connection with the hearing, PNM filed testimony indicating that:

• PNM would not acquire the 65 MW of capacity in SJGS Unit 4 that was no longer anticipated to be acquired by the City of Farmington, as discussed under SJGS Ownership Restructuring Matters below

• PNM would not enter into a coal supply agreement for SJGS that extends beyond 2022 without NMPRC approval

• PNM would have an ownership restructuring agreement for SJGS in place by May 1, 2015

PNM expects a decision from the NMPRC in the second quarter of 2015. PNM is unable to predict if the NMPRC will approve the stipulation. If the stipulation is approved as filed, PNM anticipates it would incur a regulatory disallowance that would include the write-off of 50% of the undepreciated investment in SJGS Units 2 and 3, an offset to the regulatory disallowance to reflect including the investment in PVNGS Unit 3 in the ratemaking process at the stipulated value, and other impacts of the stipulation. Although PNM would record the regulatory disallowance upon approval by the NMPRC, the amount of the disallowance would be dependent on the provisions of the NMPRC’s final order, as well as PNM’s projections of the December 31, 2017 net book values of SJGS Units 2 and 3 and PVNGS Unit 3. The amount initially recorded would be subject to adjustment to reflect changes in the projected December 31, 2017 net book values of the plants. Based on the provisions of the stipulation as filed and PNM’s current projection of December 31, 2017 book values, PNM estimates the net pre-tax regulatory disallowance would be between $60 million and $70 million.

SJGS Ownership Restructuring Matters – 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 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.

The SJGS participants have engaged in mediated negotiations concerning the implementation of the RSIP to address BART at SJGS. These negotiations initially included potential shifts in ownership among participants and between Units 3 and 4 that could have resulted in PNM acquiring additional ownership in Unit 4 prior to the shutdown of SJGS Units 2 and 3. 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.

On June 26, 2014, a non-binding resolution (the “Resolution”) was unanimously approved by the SJGS Coordination Committee. The Resolution identifies the participants who would be exiting active participation in SJGS effective December 31, 2017, and participants, including PNM, who would retain an interest in the ongoing operation of one or more units of SJGS. The Resolution provides the essential terms of restructured ownership of SJGS between the exiting participants and the remaining participants and addresses other related matters. The Resolution includes provisions indicating that the exiting participants would remain obligated for their proportionate shares of environmental, mine reclamation, and certain other legacy liabilities that are attributable to activities that occurred prior to their exit, as well as outlining how their shares would be determined. Also, on June 26, 2014, a non-binding term sheet was approved by all of the remaining participants that provides the essential terms of restructured ownership of SJGS among the remaining participants. As part of the non-binding terms, PNM confirmed that it would acquire an additional 132 MW in SJGS Unit 4 effective December 31, 2017. There would be no initial cost for PNM to acquire the additional 132 MW although PNM’s share of capital improvements, including the costs of installing SNCR and BDT equipment, and operating expenses would increase to reflect the increased ownership. The acquisition of 132 MW of SJGS Unit 4 would result in PNM’s ownership share of SJGS Unit 4 being 64.5% and of SJGS Units 1 and 4 aggregating 58.7%. The Resolution and the non-binding term sheet recognize that prior to executing a binding restructuring agreement, the remaining participants will need to have greater certainty in regard to the economic cost and availability of fuel for SJGS for the period after December 31, 2017. As discussed under Coal Supply below, the remaining participants are in the process of negotiating agreements concerning future fuel supply for SJGS, the resolution of which is necessary for continued operation of SJGS after December 31, 2017. On September 2, 2014, the SJGS Coordination Committee adopted a non-binding supplement to the Resolution, which provides for allocation of future costs of decommissioning among current SJGS owners using a time-based sliding scale and outlines indemnification obligations.

In September 2014, the SJGS participants executed a binding Fuel and Capital Funding Agreement to implement certain provisions of the Resolution, including payment by the remaining participants of capital costs for the Unit 4 SNCR project starting July 1, 2014, and acquisition by PNM of the exiting participants’ coal inventory as of January 1, 2015. PNM filed the Fuel and Capital Funding Agreement with FERC on September 18, 2014, with a request for a retroactive effective date to July 1, 2014. FERC approved the request on November 13, 2014. The Fuel and Capital Funding Agreement provides that the SJGS participants will return to the prior arrangement if a binding restructuring agreement is not reached.

On January 7, 2015, the City of Farmington, New Mexico, which has an ownership interest in Unit 4, notified the other participants that it will not acquire additional MWs in Unit 4, leaving 65 MWs in that unit unsubscribed. As discussed under NMPRC Filing above, PNM has indicated that it will not acquire any of the unsubscribed MWs. However, a scenario is being evaluated in which PNMR Development would acquire the 65 MWs. The City of Farmington’s action was taken under the Fuel and Capital Funding Agreement and has the impact of negating certain provisions of that agreement, including the payment arrangement related to SNCRs and PNM’s acquisition of the exiting participants’ coal inventory described above, and reinstating the voting and capital improvement cost allocations under the current SJPPA. Accordingly, on February 3, 2015, PNM informed the participants in the Fuel and Capital Funding Agreement that the agreement would terminate by its terms no later than February 6, 2015. The City of Farmington and the other continuing participants in SJGS have indicated that they remain committed to on-going ownership in SJGS and mediated discussions regarding remaining issues have continued, including matters that were addressed in the Fuel and Capital Funding Agreement.

The participants continue to negotiate other definitive agreements that would formalize the matters contained in the Resolution, as amended. A number of regulatory approvals are required to implement the proposed ownership restructuring of SJGS. Any final binding agreements relating to the ownership restructuring are subject to the approval of each participant’s board or other decision-making body and are subject to required regulatory approvals. PNM is unable to predict the impact of the above developments on negotiations, whether definitive agreements will be reached among the owners, or whether required approvals will be obtained, but expects negotiations to proceed consistent with the time frames described in NMPRC Filing above.

Other Developments and Current Status – The SJPPA requires PNM, as operating agent, to obtain approval of capital improvement project expenditures from participants who have an ownership interest in the relevant unit or property common to more than one unit. 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 described below, 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. In addition, other capital projects related to Unit 4 were not approved by the participants. PNM subsequently requested that the owners of Unit 4 approve the expenditure of costs critical to being able to comply with the time frame in the RSIP with respect to the Unit 4 project of $1.9 million on March 10, 2014, $6.4 million on June 27, 2014, and total project expenses of $76.6 million (including the two prior requests) on January 22, 2015. The Unit 4 owners did not approve these requests.

PNM, in its capacity as operating agent of SJGS, is authorized and obligated under the SJPPA 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. Therefore, on March 10, 2014 and July 14, 2014, PNM, as operating agent for SJGS, issued “Prudent Utility Practice” notices under the SJPPA indicating PNM was undertaking certain critical activities to keep the Unit 4 SNCR project on schedule.

As discussed above, EPA approved the RSIP and withdrew the FIP on October 9, 2014 and those approvals became effective on November 10, 2014. PNM believes significant progress is being made towards implementation of the RSIP. However, the final implementation of the RSIP is still dependent upon PNM obtaining NMPRC approval to retire San Juan Units 2 and 3. Obtaining NMPRC approval will likely require that final binding agreements be reached among the SJGS owners on a revised ownership structure to facilitate the retirement of these two units. In turn, reaching agreement on ownership restructuring, will likely require that agreement be reached regarding the supply of coal for SJGS for periods after December 31, 2017. PNM can provide no assurance that these requirements will be accomplished. If the RSIP requirements ultimately are not implemented due to adverse or alternative regulatory, legislative, legal, or restructuring developments or other factors, PNM would need to pursue other alternatives to address compliance with the CAA.PNM will seek recovery from its ratepayers for costs that may be incurred as a result of the CAA requirements. PNM is unable to predict the ultimate outcome of these matters.

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.

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 shut down by APS on December 30, 2013. For particulate matter emissions, EPA is requiring Units 4 and 5 to meet an emission limit of 0.015 lb/MMBTU and the plant to meet a 20% opacity limit, both of which are achievable through operation of the existing baghouses. Although unrelated to BART, the final BART rule also imposes a 20% opacity limitation on certain fugitive dust emissions from Four Corners’ coal and material handling operations.

SCE, a participant in Four Corners, indicated that certain California legislation may prohibit it from making emission control expenditures at Four Corners. APS and SCE entered into an asset purchase agreement, providing for the purchase by APS of SCE’s 48% interest in each of Units 4 and 5 of Four Corners. A principal condition to closing was the execution of a new coal supply contract for Four Corners on terms reasonably acceptable to APS. See Coal Supply below.

On December 30, 2013, APS announced the closing of its purchase of SCE’s 48% interest in each of Units 4 and 5 of Four Corners. Concurrently with the closing of the SCE transaction, the ownership of the coal supplier and operator of the mine that serves Four Corners was transferred to a company formed by the Navajo Nation to own the mine and develop other energy projects. Also occurring concurrently, the Four Corners co-owners executed a long term agreement for the supply of coal to Four Corners from July 2016, when the current coal supply agreement expires, through 2031.

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.  On June 19, 2014, PNM submitted comments on the draft EIS as owner and operator of two electric transmission lines that are part of the connected action for the EIS.  A final EIS is expected to be issued in March 2015. In addition, installation of SCR control technology at Four Corners requires a PSD permit, which APS received in December 2014. PNM cannot predict whether the 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 $80.0 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. On July 23, 2014, the Tenth Circuit issued a unanimous decision affirming EPA’s action and denying WEG’s petition for review. On September 15, 2014, the Tenth Circuit issued its mandate marking an official end to the case.

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. On October 21, 2014, the Tenth Circuit denied the petitions for review and affirmed EPA’s actions. On December 15, 2014, the Tenth Circuit issued its mandate marking an official end to the case.

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. On May 13, 2014, EPA released the draft data requirements rule for the 1-hour SO₂ NAAQS, which directs state and tribal air agencies to characterize current air quality in areas with large SO₂ sources to identify maximum 1-hour SO₂ concentrations. The proposed rule also describes the process and timetable by which air regulatory agencies would characterize air quality around large SO₂ sources through ambient monitoring or modeling. This characterization will result in these areas being designated as attainment, nonattainment, or unclassified for compliance with the 1-hour SO₂ NAAQS. 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 November 8, 2013, PNM received an amendment to its NSR air permit for SJGS, which would be required for the installation of either SCRs or SNCRs described above. The revised permit, requires the reduction of SO₂ emissions to 0.10 pound per MMBTU on SJGS Units 1 and 4 and continues to require the installation of BDT equipment modifications for the purpose of reducing fugitive emissions, including NOx, SO₂, and particulate matter. These reductions will help SJGS meet the NAAQS. It is anticipated that the equipment modifications 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. 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 60-70 parts per billion (“ppb”). On December 17, 2014, EPA published a proposed rule that would revise the NAAQS for ground level ozone. The rule would reduce the current primary 8-hour ozone NAAQS from 75 ppb to between 70 and 65 ppb. EPA is proposing a secondary standard to provide protection against cumulative exposures that can damage plants and trees. To achieve this level of protection, EPA is proposing to set an 8-hour secondary standard at a level within the range of 65 to 70 ppb. According to EPA, 2011-2013 ozone ambient air monitoring data indicates that Bernalillo, Dona Ana, Eddy, and San Juan counties in New Mexico exceed a 70 ppb ozone concentration. In addition, Lea, Luna Santa Fe, and Valencia counties exceed the 65 ppb ozone concentration. Counties that exceed the ozone NAAQS would be designated as nonattainment for ozone. 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 controls to meet a new ozone NAAQS. PNM cannot predict the outcome of this matter, the impact of other potential environmental mitigations, or if additional controls would be required at any of its affected facilities as a result of ozone non-attainment designation. EPA is under a court order to finalize the ozone standard by October 1, 2015.

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 2011, PNM entered into an agreement with NMED and the plaintiffs to resolve a dispute over the applicable NOx emission limits under the Consent Decree. Under the agreement, so long as the NOx emissions limits imposed under the EPA FIP and the New Mexico SIP meet a specified emissions limit, and PNM does not challenge these limits, the parties’ dispute is deemed settled.

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 sought 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. Under the stipulated order, PNM was required to repeat the mercury study required under the Consent Decree using sorbent traps instead of the continuous emissions 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 completed stack testing and submitted the study report to NMED and the plaintiffs in December 2014. Based on PNM’s cost/benefit analysis, PNM recommended that the carbon injection not be increased from its current level. NMED and the plaintiffs are evaluating the study and PNM’s recommendation. 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 parties have recently agreed on terms of a settlement. The terms of the settlement do not have a material impact on PNM.  PNM recorded the impact of its share of the proposed settlement in 2014. A final consent decree has not yet been executed.

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 NEPA 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 a finding that the federal defendants violated NEPA by approving the mine plans, voiding, reversing, and remanding the various mining modification approvals, enjoining the federal defendants from re-issuing the mining plan approvals for the mines until compliance with NEPA has been demonstrated, 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. Legal briefing is complete and the matter is ready for a ruling from the court. If WEG ultimately obtains the relief it has requested, such a ruling could require significant expenditures to reconfigure operations at the San Juan mine, impact the production of coal, and impact the economic viability of the San Juan mine and SJGS. 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. In May 2005, APS and the Navajo Nation signed an agreement resolving the dispute regarding the Navajo Nation’s authority to adopt operating permit regulations under the Navajo Nation Air Pollution Prevention and Control Act. As a result of this agreement, APS sought, and the courts granted, dismissal of the pending litigation in the Navajo Nation Supreme Court and the Navajo Nation District Court, to the extent the claims relate to the CAA. The agreement does not address or resolve any dispute relating to other aspects of the Navajo Acts. PNM cannot currently predict the outcome of these matters or the range of their potential impacts.

Cooling Water Intake Structures

EPA issued its final cooling water intake structures rule on May 19, 2013, which establishes 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 final rule was published on August 15, 2014 and became effective October 14, 2014.

The final rule allows multiple compliance options and considerations for site specific conditions and the permit writer is granted a significant amount of discretion in determining permit requirements, schedules, and conditions. To minimize impingement mortality, the rule provides operators of facilities, such as SJGS and Four Corners, seven options for meeting “best technology available” standards for reducing impingement. To minimize entrainment mortality, the permitting authority must establish the “best technology available” for entrainment on a site-specific basis, taking into consideration an array of factors, including social costs and benefits. Affected sources must submit source water baseline characterization data to the permitting authority to assist in the determination. Compliance deadlines under the rule are tied to permit renewal and will be subject to a schedule of compliance established by the permitting authority. The renewal date for the SJGS NPDES permit is March 31, 2016; however, additional time to submit the application may be allowed by the NPDES permit writer. APS is currently in discussions with EPA Region 9, the National Pollutant Discharge Elimination System permit writer for Four Corners, to determine the scope of the impingement and entrainment requirements, which will, in turn, determine APS’s costs to comply with the rule. APS has indicated that it does not expect such costs to be material. 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. 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 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 conducted similar site-wide sampling activities in April 2014 and obtained results similar to the 2013 data. As part of this effort, PNM also collected a sample of hydrocarbon product for “fingerprint” analysis from a monitoring well located on the northeastern corner of the property.  This analysis indicated that the hydrocarbon product was a mixture of newer and older fuels, and the location of the monitoring well suggests that the hydrocarbon product is likely from offsite sources. PNM does not believe the former generating station is the source of the increased levels of free-phase hydrocarbons, but no conclusive determinations have been made. It is possible that PNM’s prior activities to remediate hydrocarbon contamination, as conducted under an NMED-approved plan, may have resulted in increased nitrate levels.  Additional testing and analysis will need to be performed before conclusions can be reached regarding the cause of the increased nitrate levels or the method and cost of remediation.  PNM is unable to predict the outcome of these matters.

Coal Combustion Byproducts Waste Disposal

Regulation

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 included two options for waste designation of coal ash. One option was 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 was 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 is developing a proposed rule governing the placement of CCBs at coal mining and reclamation operations. 

On January 29, 2014, in a consolidated case in the D.C. Circuit involving several environmental groups, including Sierra Club, and industry group members, the court issued 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.

On December 19, 2014, EPA issued its coal ash rule, including a non-hazardous waste determination for coal ash. Coal ash will be regulated as a solid waste under Subtitle D of RCRA. The rule does not cover mine placement of coal ash and OSM is expected to publish a rule covering mine placement in 2015. It is expected that OSM will be influenced by EPA’s rule. Because the rule is promulgated under Subtitle D, it does not require regulated facilities to obtain permits, does not require the states to adopt and implement the new rules, and is not within EPA’s enforcement jurisdiction. Instead, the rule’s compliance mechanism is for a state or citizen group to bring a RCRA citizen suit in federal district court against any facility that is alleged to be in non- compliance with the new requirements.

PNM is reviewing the rule to fully understand its implications. The rule’s preamble indicates EPA is still evaluating whether to reverse its original regulatory determination and regulate coal ash under RCRA Subtitle C, which means it is possible at some point in the future for EPA to review the new CCR rules. PNM would seek recovery from its ratepayers of all costs that are ultimately incurred. PNM cannot predict the outcome of OSM’s proposed rulemaking regarding CCB regulation, including mine placement of CCBs, or whether OSM’s actions will have a material impact on PNM’s operations, financial position, or cash flows. 

Sierra Club Consent Decree

In April 2010, the Sierra Club filed suit against PNMR, PNM, SJCC, and BHP in the United States District Court for the District of New Mexico. In the complaint, as amended, Sierra Club alleged that activities at SJGS and SJCC’s San Juan mine were causing imminent and substantial harm to the environment, including ground and surface water in the region, and that placement of CCBs at the San Juan mine constituted “open dumping” in violation of RCRA.  The suit also included claims against SJCC and BHP under the Surface Mine Control and Reclamation Act. The complaint requested judgment for injunctive relief, payment of civil penalties, and an award of plaintiffs’ attorney’s fees and costs.

On March 28, 2012, the parties filed an executed consent decree with the court, which was approved by the court on April 12, 2012, settling the litigation. Under the terms of the consent decree, the SJGS owners and SJCC will construct and operate a slurry wall and recovery trench, fund other environmental projects, and pay Sierra Club’s attorneys’ and experts’ fees. The total estimated cost of the settlement is $10.2 million, of which about $4.5 million is PNM’s share. Substantially all of the income statement impact related to this settlement was recorded in 2011. The consent decree also includes a release of claims and a covenant not to sue by Sierra Club. PNM is complying with the requirements of the consent decree.

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 must comply with the MATS rule by April 16, 2015, unless the facility has been granted a 1-year extension under CAA section 112(i)(3). PNM has not requested an extension and will begin complying with the MATS rule by the date specified in the 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 requested and received a 1-year extension until April 16, 2016 for Four Corners to comply with the MATS rule. However, 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 December 31, 2014 and 2013, prepayments for coal, which are included in other current assets, amounted to $37.3 million and $12.3 million. 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.

PNM and the other owners of SJGS are evaluating alternatives for the supply of coal after the expiration of the current coal sales agreement. As discussed under SJGS Ownership Restructuring Matters above, the Resolution and the non-binding term sheet approved by the SJGS Coordination Committee on June 26, 2014 recognize that prior to executing a binding restructuring agreement relating to the ownership of SJGS, the remaining participants will need to have greater certainty in regard to the cost and availability of fuel for SJGS for the period after December 31, 2017. The remaining participants are in the process of negotiating agreements concerning future fuel supply for SJGS. On October 1, 2014, the San Juan Fuels Committee approved a resolution authorizing an amendment to the coal sales agreement. The parties to the coal sales agreement and the amendment are SJCC, PNM, and Tucson. The amendment provided for the negotiation of a potential purchase transaction for the mine assets by one or more of the utilities, an affiliate, or another entity agreed to by the parties to be consummated on or before December 31, 2016. The amendment, which was effective as of October 2, 2014, also released the parties from the obligation to negotiate an extension of the coal sales agreement, but does not impact the utilities’ option to purchase the mining assets at the end of the current contract term if the purchase transaction is not completed. On February 12, 2015, the SJGS Coordination Committee approved a resolution authorizing the modification of the amendment to extend the date for negotiation of a transaction until May 1, 2015 and to allow for a direct sale of the SJCC mining operations by BHP to a third-party mining company. PNM anticipates that in connection with a consummated purchase transaction, the third-party mining company would enter into an agreement to supply coal to SJGS. The parties to the amendment also entered into an agreement in October 2014 providing the SJGS participants with access to data necessary to evaluate the mine assets and liabilities. This agreement has terminated and was not renewed in order to allow the parties to focus on the direct sales process. Currently, PNM cannot predict the outcome of these negotiations or if a transaction will be consummated.

APS purchased 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, beginning in July 2016 and expiring in 2031, was entered into with that entity. The BHP subsidiary is to be retained as the mine manager and operator until December 2016. Coal costs are anticipated to increase approximately 30% at the inception of the new contract. The contract provides for pricing adjustments over its term based on economic indices. 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 current 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 2014 estimates, remaining payments for mine reclamation, in future dollars, are estimated to be $57.3 million for the surface mines at both SJGS and Four Corners and $93.3 million for the underground mine at SJGS as of December 31, 2014. At December 31, 2014 and 2013, liabilities, in current dollars, of $25.7 million and $23.8 million for surface mine reclamation and $8.6 million and $7.8 million for underground mine reclamation were recorded in other deferred credits. On June 1, 2012, the SJGS owners entered into a trust funds agreement to provide funding to compensate SJCC for post-term reclamation obligations under the coal sales agreement. The trust funds agreement requires each owner to enter into an individual trust agreement with a financial institution as trustee, create an irrevocable trust, and periodically deposit funding into the trust for the owner’s share of the mine reclamation obligation. Deposits, which are based on funding curves, must be made on an annual basis. PNM funded $1.0 million in 2014, $0.3 million in 2013, and $3.5 million in 2012. Future funding requirements are currently expected to approximate $0.6 million annually.

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 (Note 4) 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, which was performed in 2013, 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. The reclamation amounts discussed above reflect PNM’s estimates of its share of the revised costs. How costs would be divided among the owners of SJGS has not been finalized. Regulatory determinations made by the NMPRC may also affect the impact on PNM. 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 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. Coal inventories have been restored to pre-incident levels and SJCC provided notice to PNM on September 23, 2014 that the mine has been restored to normal 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 $18.7 million. PNM has credited its FPPAC balancing account for the insurance proceeds allocable to PNM’s New Mexico jurisdictional customers. See Note 17.

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 were submitted to a panel for binding arbitration. The issues were: 1) whether the SJGS participants owed SJCC unbilled mining costs of $5.2 million or whether SJCC owed 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 were not billable under the mining contract.  PNM’s share of amounts subject to the arbitration was approximately 46.3%. A hearing before the arbitration panel on the remaining issues was held in May 2014. The arbitration panel found in favor of SJCC on both issues. Of PNM’s share of the costs, approximately 33% of the first issue was passed through PNM’s FPPAC and the rest impacted earnings in 2014. The amounts related to the second issue were recorded when billed in prior periods and had no impact in 2014.

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 9.4%, 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. 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 cannot predict the timing or outcome of this litigation. However, PNM does not expect the outcome to have a material impact on its financial position, results of operations, or cash flows.

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 a maximum 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 premium assessments of $4.8 million for each retrospective premium 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.

Natural Gas Supply

PNM procures gas supplies for its power plants from third-party sources and contracts with third party transportation providers.

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, Rio Bravo, 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 has entered 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. The court denied the utilities’ motion for judgment. The court further granted the County’s motion to dismiss the state law claims. The utilities filed an amended complaint reflecting the two federal claims remaining before the federal court. The utilities also filed a complaint in Bernalillo County, New Mexico District Court reflecting the state law counts dismissed by the federal court. In subsequent briefing in federal court, the County filed a motion for judgment of one of the utilities’ claims, which was granted by the court, leaving a claim regarding telecommunications service as the remaining federal claim. This matter is ongoing in state court. The utilities and Bernalillo County reached a standstill agreement whereby the County would not take any enforcement action against the utilities pursuant to the ordinance during the pendency of the litigation, but not including any period for appeal of a judgment, or upon 30 days written notice by either the County or the utilities of their intention to terminate the agreement.  If the challenges to the ordinance are 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, 43 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. Subsequent to the dismissal, PNM received a letter from counsel on behalf of what appears to be a subset of the 43 landowner allottees involved in the appeal, notifying PNM that the specified allottees were revoking their consents for renewal of right of way on six specific allotments.  On January 22, 2015, PNM received a letter from the BIA Regional Director identifying ten allotments with rights-of-way renewals that were previously contested.  The letter indicated that the renewals were not processed because the necessary consent was not met.  It is the BIA Regional Director’s position that PNM must re-obtain consent from these landowners.  PNM is in the process of investigating the validity of this notice of revocation and its potential impact in light of the BIA’s position and the recent dismissal with prejudice of the appeal, and is therefore unable at this time to predict the likely outcome of this matter.

XML

Fair Value of Derivative and Other Financial Instruments, Available for Sale Securities (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Schedule of Available-for-sale Securities [Line Items]
Realized impairment (loss) gain	$ 700,000	$ (600,000)	$ (5,200,000)
PNMR and PNM [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Fair value	250,145,000	226,855,000
Available-for-sale securities, Unrealized gains	46,348,000	42,602,000
Proceeds from sales	117,989,000	271,140,000	167,330,000
Gross realized gains	15,162,000	14,308,000	15,907,000
Gross realized (losses)	(3,964,000)	(4,298,000)	(8,170,000)
Other than Temporary Impairment Losses, Investments, Portion in Other Comprehensive Loss, before Tax, Portion Attributable to Parent	0
Cash and equivalents [Member] | PNMR and PNM [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Fair value	8,276,000	3,356,000
Available-for-sale securities, Unrealized gains	0	0
Domestic value [Member] | PNMR and PNM [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Fair value	45,340,000	39,460,000
Available-for-sale securities, Unrealized gains	17,418,000	14,523,000
Domestic growth [Member] | PNMR and PNM [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Fair value	74,053,000	76,292,000
Available-for-sale securities, Unrealized gains	21,354,000	25,656,000
International and other [Member] | PNMR and PNM [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Fair value	16,599,000	16,633,000
Available-for-sale securities, Unrealized gains	156,000	1,040,000
U.S. Government [Member] | PNMR and PNM [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Fair value	22,563,000	21,941,000
Available-for-sale securities, Unrealized gains	903,000	158,000
Municipals [Member] | PNMR and PNM [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Fair value	68,973,000	58,568,000
Available-for-sale securities, Unrealized gains	5,851,000	1,018,000
Corporate and other [Member] | PNMR and PNM [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Fair value	14,341,000	10,605,000
Available-for-sale securities, Unrealized gains	666,000	207,000
Measured on a recurring basis [Member] | PNMR and PNM [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Fair value	250,145,000	226,855,000
Measured on a recurring basis [Member] | Nuclear Decommissioning Trust [Member] | PNMR and PNM [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Fair value	244,600,000	222,500,000
Measured on a recurring basis [Member] | Mine Reclamation Trust [Member] | PNMR and PNM [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Fair value	5,500,000	4,400,000
Measured on a recurring basis [Member] | Cash and equivalents [Member] | PNMR and PNM [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Fair value	8,276,000	3,356,000
Measured on a recurring basis [Member] | Domestic value [Member] | PNMR and PNM [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Fair value	45,340,000	39,460,000
Measured on a recurring basis [Member] | Domestic growth [Member] | PNMR and PNM [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Fair value	74,053,000	76,292,000
Measured on a recurring basis [Member] | International and other [Member] | PNMR and PNM [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Fair value	16,599,000	16,633,000
Measured on a recurring basis [Member] | U.S. Government [Member] | PNMR and PNM [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Fair value	22,563,000	21,941,000
Measured on a recurring basis [Member] | Municipals [Member] | PNMR and PNM [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Fair value	68,973,000	58,568,000
Measured on a recurring basis [Member] | Corporate and other [Member] | PNMR and PNM [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, Fair value	$ 14,341,000	$ 10,605,000

XML

Consolidated Balance Sheets (Parenthetical) (USD $) In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Allowance for uncollectible accounts	$ 1,466	$ 1,423
Accumulated depreciation, nuclear fuel	44,507	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 outstanding	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
Cumulative preferred stock of subsidiary, shares authorized	10,000,000
Public Service Company of New Mexico [Member]
Allowance for uncollectible accounts	1,466	1,423
Accumulated depreciation, nuclear fuel	$ 44,507	$ 47,347
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
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 outstanding	115,293	115,293
Texas-New Mexico Power Company [Member]
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
Common stock, par value	$ 10	$ 10
Cumulative preferred stock of subsidiary, shares authorized	1,000,000

XML

Consolidated Statements of Comprehensive Income (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Net earnings (loss)	$ 116,254	$ 100,507	$ 105,547
Net Earnings	130,909	115,556	120,125
Unrealized Gain on Available-for-Sale Securities:
Unrealized holding gains (losses) arising during the period, net of income tax (expense) benefit	10,661	16,564	23,286
Reclassification adjustment for (gains) included in net earnings (loss), net of income tax expense	(8,401)	(7,222)	(22,514)
Pension Liability Adjustment:
Experience gain (loss), net of income tax (expense) benefit	(9,258)	10,355	(18,174)
Reclassification adjustment for amortization of experience (gain) loss recognized as net periodic benefit cost, net of income tax (expense) benefit	3,120	3,840	2,786
Fair Value Adjustment for Designated Cash Flow Hedges:
Change in fair market value, net of income tax (expense) benefit	(100)	(181)	(275)
Reclassification adjustment for (gains) losses included in net earnings (loss), net of income tax expense	363	134	117
Total Other Comprehensive Income (Loss)	(3,615)	23,490	(14,774)
Comprehensive Income	127,294	139,046	105,351
Comprehensive (Income) Attributable to Valencia Non-controlling Interest	(14,127)	(14,521)	(14,050)
Preferred Stock Dividend Requirements of Subsidiary	528	528	528
Comprehensive Income Attributable to PNMR	112,639	123,997	90,773
Public Service Company of New Mexico [Member]
Net earnings (loss)	87,326	88,155	91,551
Net Earnings	101,453	102,676	105,601
Unrealized Gain on Available-for-Sale Securities:
Unrealized holding gains (losses) arising during the period, net of income tax (expense) benefit	10,661	16,564	23,286
Reclassification adjustment for (gains) included in net earnings (loss), net of income tax expense	(8,401)	(7,222)	(22,514)
Pension Liability Adjustment:
Experience gain (loss), net of income tax (expense) benefit	(9,258)	10,355	(18,174)
Reclassification adjustment for amortization of experience (gain) loss recognized as net periodic benefit cost, net of income tax (expense) benefit	3,120	3,840	2,786
Fair Value Adjustment for Designated Cash Flow Hedges:
Total Other Comprehensive Income (Loss)	(3,878)	23,537	(14,616)
Comprehensive Income	97,575	126,213	90,985
Comprehensive (Income) Attributable to Valencia Non-controlling Interest	(14,127)	(14,521)	(14,050)
Preferred Stock Dividend Requirements of Subsidiary	528	528	528
Comprehensive Income Attributable to PNMR	83,448	111,692	76,935
Texas-New Mexico Power Company [Member]
Net earnings (loss)	37,807	29,090	26,747
Net Earnings	37,807	29,090	26,747
Fair Value Adjustment for Designated Cash Flow Hedges:
Change in fair market value, net of income tax (expense) benefit	(100)	(181)	(275)
Reclassification adjustment for (gains) losses included in net earnings (loss), net of income tax expense	363	134	117
Total Other Comprehensive Income (Loss)	263	(47)	(158)
Preferred Stock Dividend Requirements of Subsidiary	0	0	0
Comprehensive Income Attributable to PNMR	$ 38,070	$ 29,043	$ 26,589

XML

Variable Interest Entities

12 Months Ended

Dec. 31, 2014

Variable Interest Entities [Abstract]

Variable Interest Entities

Variable Interest Entities

GAAP determines how an enterprise evaluates and accounts for its involvement with variable interest entities, focusing primarily on whether the enterprise has the power to direct the activities that most significantly impact the economic performance of a variable interest entity. GAAP also requires continual reassessment of the primary beneficiary of a variable interest entity.

Valencia

PNM has a PPA to purchase all of the electric capacity and energy from Valencia, a 158 MW natural gas-fired power plant near Belen, New Mexico, through May 2028. A third-party built, owns, and operates the facility while PNM is the sole purchaser of the electricity generated. The total construction cost for the facility was $90.0 million. PNM estimates that the plant will typically operate during peak periods of energy demand in summer. PNM is obligated to pay fixed operations and maintenance and capacity charges in addition to variable operation and maintenance charges under this PPA. For the years ended December 31, 2014, 2013, and 2012, PNM paid $19.1 million, $18.9 million, and $18.8 million for fixed charges and $1.2 million, $1.2 million, and $0.9 million for variable charges. PNM does not have any other financial obligations related to Valencia. The assets of Valencia can only be used to satisfy obligations of Valencia and creditors of Valencia do not have any recourse against PNM’s assets.

PNM sources fuel for the plant, controls when the facility operates through its dispatch, and receives the entire output of the plant, which factors directly and significantly impact the economic performance of Valencia. Therefore, PNM has concluded that the third party entity that owns Valencia is a 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. Accordingly, the assets, liabilities, operating expenses, and cash flows of Valencia are included in the consolidated financial statements of PNM although PNM has no legal ownership interest or voting control of the variable interest entity. The assets and liabilities of Valencia set forth below are immaterial to PNM and, therefore, not shown separately on the Consolidated Balance Sheets. The owner’s equity and net income of Valencia are considered attributable to non-controlling interest.

Summarized financial information for Valencia is as follows:

Results of Operations
	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Operating revenues	$	20,247		$	20,166		$	19,585
Operating expenses	(6,120		)	(5,645		)	(5,535		)
Earnings attributable to non-controlling interest	$	14,127		$	14,521		$	14,050

Financial Position
	December 31,
	2014		2013
	(In thousands)
Current assets	$	2,513	$	2,658
Net property, plant and equipment	72,321		75,137
Total assets	74,834		77,795
Current liabilities	1,288		766
Owners’ equity – non-controlling interest	$	73,546	$	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 was initiated since the parties failed to reach agreement on fair market value within 60 days. Under the PPA, results of the appraisal process established the purchase price after which PNM was to determine in its sole discretion whether or not to exercise its option to purchase the 50% interest. The PPA also provides that the purchase price may be adjusted to reflect the period between the determination of the purchase price and the closing. The appraisal process determined the purchase price as of October 8, 2013 to be $85.0 million, prior to any adjustment to reflect the period through the closing date. Approval of the NMPRC and FERC would be required, which process could take up to 15 months. On May 30, 2014, after evaluating its alternatives with respect to Valencia, PNM notified the owner of Valencia that PNM intended to purchase 50% of the plant, subject to certain conditions. PNM’s conditions include: agreeing on the purchase price, adjusted to reflect the period between October 8, 2013 and the closing; approval of the NMPRC, including specified ratemaking treatment, and FERC; approval of the Board and PNM’s board of directors; receipt of other necessary approvals and consents; and other customary closing conditions. PNM received a letter dated June 30, 2014 from the owner of Valencia suggesting that the conditions set forth in PNM’s notification raise issues under the PPA. PNM is discussing these issues with the owner of Valencia. PNM cannot predict whether or not it will reach agreement with the owner of Valencia, if required regulatory and other approvals will be received, or if the purchase will be completed.

PVNGS Leases

PNM is leasing portions of its interests in Units 1 and 2 of PVNGS. There are currently eight separate lease agreements with eight different trusts whose beneficial owners are five different institutional investors. PNM is not the legal or tax owner of the leased assets. The beneficial owners of the trusts possess all of the voting control and pecuniary interests in the trusts. The leases provide PNM with an option to purchase the leased assets at appraised value at the end of the leases, but 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 2 years beyond the termination of the original lease terms. The option periods on certain leases may be further extended for up to an additional 6 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 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 $20.3 million over the remaining original terms of the leases and $145.2 million during the renewal terms of the leases that PNM has elected to renew. Other than as discussed in Note 7, 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 no assets or liabilities recorded on its Consolidated Balance Sheets related to the trusts other than accrued lease payments of $26.0 million at December 31, 2014 and 2013, which are included in other current liabilities on the Consolidated Balance Sheets.

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. The significant factors considered in reaching this conclusion are: the periods covered by fixed price renewal options are significantly shorter than the anticipated remaining useful lives of the assets, particularly since the operating licenses for the plants have been extended for twenty years through 2045 for Unit 1 and 2046 for Unit 2; PNM’s only financial obligation to the trusts is to make the fixed lease payments and the payments do not vary based on the output of the plants or their performance; during the lease terms, the economic performance of the trusts is substantially fixed due to the fixed lease payments; PNM is only one of several participants in PVNGS and is not the operating agent for the plants, so does not significantly influence the day-to-day operations of the plants; furthermore, the operations of the plants, including plans for their decommissioning, are highly regulated by the NRC, leaving little room for the participants to operate the plants in a manner that impacts the economic performance of the trusts; the economic performance of the trusts at the end of the lease terms is dependent upon the fair value and remaining lives of the plants at that time, which are determined by factors such as power prices, outlook for nuclear power, and the impacts of potential carbon legislation or regulation, all which are outside of PNM’s control; and while PNM has some benefit from its renewal options, the vast majority of the value at the end of the leases will accrue to the beneficial owners of the trusts, particularly given increases in the value of existing nuclear generating facilities, which have no GHG, resulting from potential carbon legislation or regulation.

Rio Bravo, formerly known as Delta

PNM had a 20-year PPA expiring in 2020 covering the entire output of Delta, which was a variable interest under GAAP. PNM also controlled the dispatch of the generating plant, which impacted the variable payments made under the PPA and impacted the economic performance of the entity that owned Delta. This arrangement was entered into prior to December 31, 2003 and PNM was unsuccessful in obtaining the information necessary to determine if it was the primary beneficiary of the entity that owned Delta, or to consolidate that entity if it were determined that PNM was the primary beneficiary. Accordingly, PNM was unable to make those determinations and, as provided in GAAP, accounted for this PPA as an operating lease.

In December 2012, PNM entered into an agreement with the owners of Delta under which PNM would purchase the entity that owned Delta. FERC approved the purchase on February 26, 2013 and the NMPRC approved the purchase on June 26, 2013. Closing was subject to the seller remedying specified operational, NERC compliance, and environmental issues, as well as other customary closing conditions. PNM closed on the purchase on July 17, 2014 and recorded the purchase as of that date. At closing, PNM made a cash payment of $22.8 million, which reflected an adjustment for working capital compared to a targeted working capital and included amounts placed in escrow. Delta had project financing debt, amounting to $14.6 million at closing, which PNM retired. PNM changed the name of the facility to Rio Bravo.

PNM recorded the acquisition as a business combination and reflected the requirements of the FERC Uniform System of Accounts since the purchased assets are subject to traditional rate regulation by the NMPRC and FERC. Accordingly, as of the acquisition date, PNM recorded plant in service of $58.1 million and accumulated depreciation of $23.5 million, reflecting the original cost of the facilities and the estimated economic life to PNM. PNM also recorded current assets of $3.6 million, deferred charges of $3.4 million, current liabilities of $0.3 million, and non-current regulatory liabilities of $3.4 million.

PNM made fixed and variable payments to Delta under the PPA. For the period from January 1, 2014 through July 17, 2014, PNM incurred fixed capacity charges of $3.5 million and variable energy charges of $0.6 million under the PPA. For the years ended December 31, 2013 and 2012, PNM incurred fixed capacity charges of $6.4 million, and $6.2 million and variable energy charges of $1.8 million, and $0.8 million under the PPA. PNM recovered the variable energy charges through its FPPAC.

PNM began consolidating Rio Bravo at the date of the acquisition. Prior to the acquisition, consolidation of Delta would have been immaterial to the Consolidated Balance Sheets of PNMR and PNM. Since all of Delta’s revenues and expenses were attributable to its PPA arrangement with PNM, the primary impact of consolidating Delta to the Consolidated Statements of Earnings of PNMR and PNM would have been to reclassify Delta’s net earnings from operating expenses and reflect such amount as earnings attributable to a non-controlling interest, without any impact to net earnings attributable to PNMR and PNM.

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Schedule I - Condensed Financial Information of Parent Company (Statement of Cash flow) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Cash Flows From Operating Activities:
Net earnings (loss)	$ 116,254	$ 100,507	$ 105,547
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	209,867	208,173	206,499
Deferred income tax expense	72,481	60,430	56,243
Loss on reacquired debt	0	3,253	0
Stock based compensation expense	5,931	5,320	3,585
Changes in certain assets and liabilities:
Other current assets	(30,436)	8,577	(2,598)
Other assets	290	(12,801)	(30,778)
Accounts payable	(2,311)	4,484	14,020
Accrued interest and taxes	2,040	91,537	255
Other current liabilities	(2,453)	(19,648)	(19,905)
Other liabilities	45,516	(61,262)	(70,743)
Net cash flows from operating activities	414,876	386,587	281,349
Cash Flows From Investing Activities:
Utility plant additions	(460,658)	(348,039)	(308,909)
Net cash flows from investing activities	(485,329)	(331,446)	(285,895)
Cash Flows From Financing Activities:
Short-term borrowings (repayments), net	(43,600)	(9,500)	(24,000)
Repayment of long-term debt	(125,000)	(29,468)	(22,387)
Proceeds from stock option exercise	6,999	4,618	11,684
Dividends paid	(59,468)	(51,508)	(45,137)
Other, net	(2,808)	(5,545)	(922)
Net cash flows from financing activities	96,194	(61,593)	(1,560)
Change in Cash and Cash Equivalents	25,741	(6,452)	(6,106)
Cash and Cash Equivalents at Beginning of Year	2,533	8,985	15,091
Cash and Cash Equivalents at End of Year	28,274	2,533	8,985
Supplemental Cash Flow Disclosures:
Interest paid	108,741	110,768	113,265
Income taxes paid (refunded), net	(2,597)	(95,327)	5,302
PNM Resources [Member]
Cash Flows From Operating Activities:
Net earnings (loss)	116,254	100,507	105,547
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	680	4,192	5,000
Deferred income tax expense	(69,442)	(51,820)	(46,632)
Equity in (earnings) loss of subsidiaries	(124,543)	(116,634)	(117,900)
Loss on reacquired debt	0	3,253	0
Stock based compensation expense	5,931	5,320	3,585
Changes in certain assets and liabilities:
Other current assets	22,955	28,460	(43,638)
Other assets	51,644	46,558	34,096
Accounts payable	(88)	620	8
Accrued interest and taxes	(7,683)	(9,266)	(28,855)
Other current liabilities	(1,668)	(146)	3,876
Other liabilities	28,704	(27,756)	(29,601)
Net cash flows from operating activities	22,744	(16,712)	(114,514)
Cash Flows From Investing Activities:
Utility plant additions	(474)	(960)	(7,524)
Investments in subsidiaries	0	(13,800)	0
Cash dividends from subsidiaries	46,599	158,772	61,406
Net cash flows from investing activities	46,125	144,012	53,882
Cash Flows From Financing Activities:
Short-term borrowings (repayments), net	600	(37,600)	120,900
Repayment of long-term debt	0	(29,468)	(2,387)
Proceeds from stock option exercise	6,999	4,618	11,684
Purchases to satisfy awards of common stock	(17,319)	(13,807)	(25,168)
Dividends paid	(58,940)	(50,980)	(44,609)
Other, net	81	0	0
Net cash flows from financing activities	(68,579)	(127,237)	60,420
Change in Cash and Cash Equivalents	290	63	(212)
Cash and Cash Equivalents at Beginning of Year	92	29	241
Cash and Cash Equivalents at End of Year	382	92	29
Supplemental Cash Flow Disclosures:
Interest paid	12,152	14,510	15,007
Income taxes paid (refunded), net	$ (2,014)	$ 22,378	$ 1,501

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Construction Program and Jointly-Owned Electric Generating Plants Construction Program and Jointly-Owned Electric Generating Plants (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014		Dec. 31, 2013	Dec. 31, 2012
Construction Expenditures	$ 460,658		$ 348,039	$ 308,909
Public Utilities, Property, Plant and Equipment, Plant in Service	5,941,581		5,563,061
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(1,939,760)		(1,838,832)
Operating Lease, Extended Term	2 years
Joint Projects [Member] | Public Service Company of New Mexico [Member]
Construction Expenditures	316,800
Joint Projects [Member] | Texas-New Mexico Power Company [Member]
Construction Expenditures	127,200
Joint Projects [Member] | PNMR [Member]
Construction Expenditures	460,700
Four Corners Units 4 and 5 (Coal) [Member] | Public Service Company of New Mexico [Member]
Public Utilities, Property, Plant and Equipment, Plant in Service	162,111
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(101,007)
Public Utilities, Property, Plant and Equipment, Construction Work in Progress	8,253
Jointly Owned Utility Plant, Proportionate Ownership Share	13.00%
Luna (Gas) [Member] | Other Unrelated Entities 9 [Member]
Jointly Owned Utility Plant, Proportionate Ownership Share	33.30%
Luna (Gas) [Member] | Public Service Company of New Mexico [Member]
Public Utilities, Property, Plant and Equipment, Plant in Service	66,169
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(20,297)
Public Utilities, Property, Plant and Equipment, Construction Work in Progress	136
Jointly Owned Utility Plant, Proportionate Ownership Share	33.33%
SJGS Units 1 and 2 [Member] | Public Service Company of New Mexico [Member]
Jointly Owned Utility Plant, Proportionate Ownership Share	50.00%
SJGS (Coal) [Member] | Unit 3 [Member] | Other Unrelated Entities 1 [Member]
Jointly Owned Utility Plant Proportionate Ownership Share, Other Entities	41.80%
SJGS (Coal) [Member] | Unit 3 [Member] | Other Unrelated Entities 2 [Member]
Jointly Owned Utility Plant, Proportionate Ownership Share	8.20%
SJGS (Coal) [Member] | Unit 4 [Member] | Other Unrelated Entities 3 [Member]
Jointly Owned Utility Plant Proportionate Ownership Share, Other Entities	28.80%
SJGS (Coal) [Member] | Unit 4 [Member] | Other Unrelated Entities 4 [Member]
Jointly Owned Utility Plant Proportionate Ownership Share, Other Entities	10.04%
SJGS (Coal) [Member] | Unit 4 [Member] | Other Unrelated Entities 5 [Member]
Jointly Owned Utility Plant Proportionate Ownership Share, Other Entities	8.475%
SJGS (Coal) [Member] | Unit 4 [Member] | Other Unrelated Entities 6 [Member]
Jointly Owned Utility Plant Proportionate Ownership Share, Other Entities	7.20%
SJGS (Coal) [Member] | Unit 4 [Member] | Other Unrelated Entities 7 [Member]
Jointly Owned Utility Plant Proportionate Ownership Share, Other Entities	7.028%
SJGS (Coal) [Member] | Public Service Company of New Mexico [Member]
Public Utilities, Property, Plant and Equipment, Plant in Service	1,009,378
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(423,364)
Public Utilities, Property, Plant and Equipment, Construction Work in Progress	25,551
Jointly Owned Utility Plant, Proportionate Ownership Share	46.30%
SJGS (Coal) [Member] | Public Service Company of New Mexico [Member] | Unit 3 [Member]
Jointly Owned Utility Plant, Proportionate Ownership Share	50.00%
SJGS (Coal) [Member] | Public Service Company of New Mexico [Member] | Unit 4 [Member]
Jointly Owned Utility Plant, Proportionate Ownership Share	38.457%
Palo Verde Nuclear Generating Station [Member] | Public Service Company of New Mexico [Member]
Public Utilities, Property, Plant and Equipment, Plant in Service	533,702	[1]
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(152,273)	[1]
Public Utilities, Property, Plant and Equipment, Construction Work in Progress	$ 42,334	[1]
Jointly Owned Utility Plant, Proportionate Ownership Share	10.20%	[1]
Operating Lease, Original term	40 years
Number of operating units	3
Operating Lease, Extended Term	20 years

[1] Includes interest in PVNGS Unit 3, interest in common facilities for all PVNGS units, and owned interests in PVNGS Units 1 and 2.

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Stock-Based Compensation Plans Weighted Average Assumptions (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Restricted Stock and Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected quarterly dividends per share, in dollars per share	$ 0.185	$ 0.165	$ 0.145
Risk-free interest rates, percentage	0.62%	0.34%	1.22%
Market-Based Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Risk-free interest rates, percentage	0.64%	0.36%	1.04%
Dividend yield	2.82%	2.86%	3.45%
Expected volatility	25.11%	25.11%	43.98%

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Document and Entity Information Document (USD $)	12 Months Ended
	Dec. 31, 2014	Feb. 20, 2015	Jun. 30, 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-K
Document Period End Date	Dec. 31, 2014
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Common Stock, Shares Outstanding		79,653,624
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 2,336,240,792
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
Document Type	10-K
Document Period End Date	Dec. 31, 2014
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Common Stock, Shares Outstanding		39,117,799
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Texas-New Mexico Power Company [Member]
Document Information [Line Items]
Entity Registrant Name	TEXAS NEW MEXICO POWER CO
Entity Central Index Key	0000022767
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Document Type	10-K
Document Period End Date	Dec. 31, 2014
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Common Stock, Shares Outstanding		6,358
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	Yes
Entity Current Reporting Status	No

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Earnings and Dividends Per Share

12 Months Ended

Dec. 31, 2014

Earnings Per Share [Abstract]

Earnings and Dividends Per Share

Earnings and Dividends Per Share

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

	Year Ended December 31,
	2014		2013		2012
	(In thousands, except per share amounts)
Earnings Attributable to PNMR	$	116,254	$	100,507	$	105,547
Average Number of Common Shares:
Outstanding during year	79,654		79,654		79,654
Vested awards of restricted stock	134		191		145
Average Shares – Basic	79,788		79,845		79,799
Dilutive Effect of Common Stock Equivalents (1):
Stock options and restricted stock	491		586		618
Average Shares – Diluted	80,279		80,431		80,417
Net Earnings Per Share of Common Stock:
Basic	$	1.46	$	1.26	$	1.32
Diluted	$	1.45	$	1.25	$	1.31
Dividends Declared per Common Share	$	0.755	$	0.680	0.580

⁽¹⁾  Excludes out-of-the-money options for 254,050 shares of common stock at December 31, 2014. See Note 13.

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Income Taxes Accumulated Accrued Interest Receivable (Payable) Related to Income Taxes (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
PNMR [Member]
Income Taxes [Line Items]
Accumulated accrued interest receivable	$ 3,569	$ 4,048
Accumulated accrued interest payable	(1,120)	(1,118)
Public Service Company of New Mexico [Member]
Income Taxes [Line Items]
Accumulated accrued interest receivable	3,569	4,048
Accumulated accrued interest payable	(24)	(24)
Texas-New Mexico Power Company [Member]
Income Taxes [Line Items]
Accumulated accrued interest receivable	0	0
Accumulated accrued interest payable	$ (120)	$ (118)

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Stock-Based Compensation Plans Performance Equity Plan/ Accounting for Stock Awards and ESPP (Details) (USD $) In Millions, except Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	$ 5.9	$ 5.3	$ 3.6
Public Service Company of New Mexico [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	4.2	3.8	2.7
Texas-New Mexico Power Company [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	1.7	1.5	1.0
Restricted Stock and Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized	4.7
Market-Based Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized	$ 1.8
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized, Period for Recognition (years)	1 year 9 months 19 days
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, Vesting Rate	100.00%
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized, Shares	13,500,000

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Consolidated Statements of Comprehensive Income (Loss) (Parenthetical) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Unrealized holding gains (losses) arising during the period, income tax (expense)	$ (6,812)	$ (10,855)	$ (15,262)
Reclassification adjustment for (gains) included in net earnings (loss), income tax expense	5,461	4,734	14,755
Experience gain (loss), income tax (expense) benefit	6,024	(6,781)	11,910
Reclassification adjustment for amortization of experience (gain) loss recognized as net periodic benefit cost, income tax (expense) benefit	(2,032)	(2,524)	(1,825)
Change in fair market value, income tax (expense)	53	98	153
Reclassification adjustment for (gains) losses included in net earnings (loss), income tax expense (benefit)	(195)	(73)	(65)
Texas-New Mexico Power Company [Member]
Change in fair market value, income tax (expense)	53	98	153
Reclassification adjustment for (gains) losses included in net earnings (loss), income tax expense (benefit)	(195)	(73)	(65)
Public Service Company of New Mexico [Member]
Unrealized holding gains (losses) arising during the period, income tax (expense)	(6,812)	(10,855)	(15,262)
Reclassification adjustment for (gains) included in net earnings (loss), income tax expense	5,461	4,734	14,755
Experience gain (loss), income tax (expense) benefit	6,024	(6,781)	11,910
Reclassification adjustment for amortization of experience (gain) loss recognized as net periodic benefit cost, income tax (expense) benefit	$ (2,032)	$ (2,524)	$ (1,825)

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Regulatory Assets and Liabilities

12 Months Ended

Dec. 31, 2014

Regulated Operations [Abstract]

Regulatory Assets and Liabilities

Regulatory Assets and Liabilities

The operations of PNM and TNMP are regulated by the NMPRC, PUCT, and FERC and the provisions of GAAP for rate-regulated enterprises are applied to its regulated operations. Regulatory assets represent probable future recovery of previously incurred costs that will be collected from customers through the ratemaking process. Regulatory liabilities represent probable future reductions in revenues associated with amounts that are to be credited to customers through the ratemaking process. Regulatory assets and liabilities reflected in the Consolidated Balance Sheets are presented below.

PNM

	December 31,
	2014			2013
Assets:	(In thousands)
Current:
FPPAC	$	43,980		$	19,394
Non-Current:
Coal mine reclamation costs	34,224			40,144
Deferred income taxes	63,645			61,850
Loss on reacquired debt	25,439			27,490
Pension and OPEB	222,545			206,691
FPPAC	—			25,386
Renewable energy costs	5,263			13,311
Other	5,929			9,345
	357,045			384,217
Total regulatory assets	$	401,025		$	403,611
Liabilities:
Current:
Other	$	(1,703	)	$	(1,081	)
Non-Current:
Cost of removal	(277,148		)	(266,075		)
Deferred income taxes	(75,941		)	(80,495		)
AROs	(35,834		)	(37,567		)
Renewable energy tax benefits	(24,854		)	(26,011		)
Other	(11,704		)	(4,463		)
	(425,481		)	(414,611		)
Total regulatory liabilities	$	(427,184	)	$	(415,692	)

TNMP

	December 31,
	2014			2013
Assets:	(In thousands)
Current:
Transmission cost recovery factor	$	2,482		$	4,250
Other	1,393			772
	3,875			5,022
Non-Current:
CTC, including carrying charges	55,292			63,606
Deferred income taxes	10,556			10,868
Pension	23,803			19,938
Loss on reacquired debt	36,703			38,616
AMS retirement costs	6,453			5,083
Other	1,155			1,627
	133,962			139,738
Total regulatory assets	$	137,837		$	144,760
Liabilities:
Non-Current:
Cost of removal	$	(29,391	)	$	(30,863	)
Deferred income taxes	(3,923		)	(4,563		)
AMS surcharge	(5,227		)	(7,251		)
OPEB	(2,121		)	(3,361		)
Total regulatory liabilities	$	(40,662	)	$	(46,038	)

The Company’s regulatory assets and regulatory liabilities are reflected in rates charged to customers or have been addressed in a regulatory proceeding. The Company does not receive or pay a rate of return on the following regulatory assets and regulatory liabilities (and their remaining amortization periods): coal mine reclamation costs (through 2020); deferred income taxes (over the remaining life of the taxable item, up to the remaining life of utility plant); pension and OPEB costs (through 2033); and AROs (to be determined in a future regulatory proceeding). In addition, TNMP does not receive a return on substantially all of its loss on reacquired debt (through 2043).

The Company is permitted, under rate regulation, to accrue and record a regulatory liability for the estimated cost of removal and salvage associated with certain of its assets through depreciation expense. Under GAAP, actuarial losses and prior service costs for pension plans are required to be recorded in AOCI; however, to the extent authorized for recovery through the regulatory process these amounts are recorded as regulatory assets or liabilities. Based on prior regulatory approvals, the amortization of these amounts will be included in the Company’s rates.

Based on a current evaluation of the various factors and conditions that are expected to impact future cost recovery, the Company believes that future recovery of its regulatory assets are probable.

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Sale of First Choice

12 Months Ended

Dec. 31, 2014

Discontinued Operations and Disposal Groups [Abstract]

Sale of First Choice

Sale of First Choice

PNMR completed the sale of First Choice, which was also a subsidiary of TNP, on November 1, 2011. First Choice was a competitive REP operating in Texas. The amount received was subject to adjustment based on the actual amounts of the components of working capital at October 31, 2011. In 2012, PNMR received an additional amount and recorded a pre-tax gain of $1.0 million, which is included in Other income in the Consolidated Statements of Earnings. PNMR Services Company continued to provide certain services at cost to First Choice for a transitional period through August 1, 2012. Because PNMR continues to have direct cash flows resulting from transmission and distribution services provided by TNMP to First Choice, First Choice is not reflected as discontinued operations.

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Asset Retirement Obligations

12 Months Ended

Dec. 31, 2014

Asset Retirement Obligation Disclosure [Abstract]

Asset Retirement Obligations

Asset Retirement Obligations

AROs are recorded based on the determination of underlying assumptions, such as discount rates, estimates of the future costs for decommissioning, and the timing of the removal activities to be performed. Any changes in these assumptions underlying the required calculations may require revisions to the estimated AROs when identified. A reconciliation of the ARO liability is as follows:

	PNMR			PNM			TNMP
	(In thousands)
Liability at December 31, 2011	$	79,233		$	78,425		$	699
Liabilities incurred	—			—			—
Liabilities settled	(25		)	—			(25		)
Accretion expense	6,685			6,617			58
Liability at December 31, 2012	85,893			85,042			732
Liabilities incurred	—			—			—
Liabilities settled	(79		)	(67		)	(12		)
Accretion expense	7,245			7,174			62
Revisions to estimated cash flows(1)	3,076			3,076			—
Liability at December 31, 2013	96,135			95,225			782
Liabilities incurred	—			—			—
Liabilities settled	—			—			—
Accretion expense	7,984			7,906			66
Revisions to estimated cash flows	51			51			—
Liability at December 31, 2014	$	104,170		$	103,182		$	848

⁽¹⁾  Based on studies to estimate the amount and timing of future ARO expenditures. PNM has an ARO for PVNGS that includes the obligations for nuclear decommissioning of that facility. In 2013, a new decommissioning study for PVNGS was implemented reflecting updated cash flow estimates, including the extended operating licenses. The new study resulted in an increase of $0.5 million to the ARO. In addition, a new decommissioning study for SJGS was implemented in 2013, resulting in a $2.5 million increase to the ARO.

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Income Taxes

12 Months Ended

Dec. 31, 2014

Income Tax Disclosure [Abstract]

Income Taxes

Income Taxes

PNMR

PNMR’s income taxes consist of the following components:

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Current federal income tax	$	(2,015	)	$	—		$	(1,296	)
Current state income tax	(728		)	(917		)	(37		)
Deferred federal income tax	59,814			50,044			51,559
Deferred state income tax	14,831			12,578			6,921
Amortization of accumulated investment tax credits	(2,164		)	(2,192		)	(2,237		)
Total income taxes	$	69,738		$	59,513		$	54,910

PNMR’s provision for income taxes differed from the federal income tax computed at the statutory rate for each of the years shown. The differences are attributable to the following factors:

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Federal income tax at statutory rates	$	70,226		$	61,274		$	61,262
Amortization of accumulated investment tax credits	(2,164		)	(2,192		)	(2,237		)
Flow-through of depreciation items	1,344			1,132			1,284
Earnings attributable to non-controlling interest in Valencia	(4,945		)	(5,082		)	(4,918		)
State income tax, net of federal benefit	5,723			3,818			4,646
Impairment of state net operating loss carryforwards	3,129			—			—
Impairment of state production tax credits, net of federal benefit	894			3,880			718
Other	(4,469		)	(3,317		)	(5,845		)
Total income taxes	$	69,738		$	59,513		$	54,910
Effective tax rate	34.76		%	33.99		%	31.37		%

The components of PNMR’s net accumulated deferred income tax liability were:

	December 31,
	2014			2013
	(In thousands)
Deferred tax assets:
Net operating loss	$	153,858		$	134,418
Regulatory liabilities related to income taxes	78,858			83,838
Federal tax credit carryforwards	54,748			40,708
Other	68,566			75,832
Total deferred tax assets	356,030			334,796
Deferred tax liabilities:
Depreciation and plant related	(914,926		)	(814,671		)
Investment tax credit	(36,790		)	(25,855		)
Regulatory assets related to income taxes	(67,910		)	(66,352		)
CTC	(19,352		)	(22,262		)
Pension	(66,498		)	(58,780		)
Other	(115,282		)	(115,458		)
Total deferred tax liabilities	(1,220,758		)	(1,103,378		)
Net accumulated deferred income tax liabilities	(864,728		)	(768,582		)
Current accumulated deferred income tax (asset) liability	(26,383		)	(58,681		)
Non-current accumulated deferred income tax liability	$	(891,111	)	$	(827,263	)

The following table reconciles the change in PNMR’s net accumulated deferred income tax liability to the deferred income tax benefit included in the Consolidated Statement of Earnings:

	Year Ended
	December 31, 2014
	(In thousands)
Net change in deferred income tax liability per above table	$	96,146
Change in tax effects of income tax related regulatory assets and liabilities	(6,538		)
Tax effect of mark-to-market adjustments	(1,612		)
Tax effect of excess pension liability	3,993
Adjustment for uncertain income tax positions	(4,858		)
Reclassification of unrecognized tax benefits	(15,031		)
Other	381
Deferred income taxes	$	72,481

PNM

PNM’s income taxes consist of the following components:

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Current federal income tax	$	(2,175	)	$	(479	)	$	(12,951	)
Current state income tax	(979		)	(760		)	(1,815		)
Deferred federal income tax	45,890			42,806			56,194
Deferred state income tax	12,061			9,429			11,522
Amortization of accumulated investment tax credits	(2,164		)	(2,192		)	(2,237		)
Total income taxes	$	52,633		$	48,804		$	50,713

PNM’s provision for income taxes differed from the federal income tax computed at the statutory rate for each of the years shown. The differences are attributable to the following factors:

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Federal income tax at statutory rates	$	53,930		$	53,018		$	54,710
Amortization of accumulated investment tax credits	(2,164		)	(2,192		)	(2,237		)
Flow-through of depreciation items	1,325			1,115			1,268
Earnings attributable to non-controlling interest in Valencia	(4,945		)	(5,082		)	(4,918		)
State income tax, net of federal benefit	5,522			6,202			6,500
Impairment of state net operating loss carryforwards	2,145			—			—
Other	(3,180		)	(4,257		)	(4,610		)
Total income taxes	$	52,633		$	48,804		$	50,713
Effective tax rate	34.16		%	32.22		%	32.44		%

The components of PNM’s net accumulated deferred income tax liability were:

	December 31,
	2014			2013
	(In thousands)
Deferred tax assets:
Net operating loss	$	108,505		$	99,247
Regulatory liabilities related to income taxes	74,293			78,849
Federal tax credit carryforwards	35,259			22,509
Other	35,681			37,008
Total deferred tax assets	253,738			237,613
Deferred tax liabilities:
Depreciation and plant related	(733,519		)	(661,239		)
Investment tax credit	(36,790		)	(25,855		)
Regulatory assets related to income taxes	(57,637		)	(55,844		)
Pension	(58,474		)	(52,104		)
Other	(70,714		)	(75,838		)
Total deferred tax liabilities	(957,134		)	(870,880		)
Net accumulated deferred income tax liabilities	(703,396		)	(633,267		)
Current accumulated deferred income tax (asset) liability	(12,418		)	(43,827		)
Non-current accumulated deferred income tax liability	$	(715,814	)	$	(677,094	)

The following table reconciles the change in PNM’s net accumulated deferred income tax liability to the deferred income tax benefit included in the Consolidated Statement of Earnings:

	Year Ended
	December 31, 2014
	(In thousands)
Net change in deferred income tax liability per above table	$	70,129
Change in tax effects of income tax related regulatory assets and liabilities	(6,349		)
Tax effect of mark-to-market adjustments	(1,470		)
Tax effect of excess pension liability	3,993
Adjustment for uncertain income tax positions	1,155
Reclassification of unrecognized tax benefits	(12,228		)
Other	557
Deferred income taxes	$	55,787

TNMP

TNMP’s income taxes consist of the following components:

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Current federal income tax	$	35		$	(4,957	)	$	9,152
Current state income tax	1,939			1,916			1,822
Deferred federal income tax	20,577			20,688			4,406
Deferred state income tax	(28		)	(26		)	(28		)
Total income taxes	$	22,523		$	17,621		$	15,352

TNMP’s provision for income taxes differed from the federal income tax computed at the statutory rate for each of the periods shown. The differences are attributable to the following factors:

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Federal income tax at statutory rates	$	21,115		$	16,349		$	14,735
State income tax, net of federal benefit	1,257			1,247			1,185
Other	151			25			(568		)
Total income taxes	$	22,523		$	17,621		$	15,352
Effective tax rate	37.33		%	37.72		%	36.47		%

The components of TNMP’s net accumulated deferred income tax liability at December 31, were:

	December 31,
	2014			2013
	(In thousands)
Deferred tax assets:
Regulatory liabilities related to income taxes	$	4,565		$	4,988
Other	13,429			23,479
Total deferred tax assets	17,994			28,467
Deferred tax liabilities:
Depreciation and plant related	(174,510		)	(151,581		)
CTC	(19,352		)	(22,262		)
Regulatory assets related to income taxes	(10,197		)	(10,509		)
Loss on reacquired debt	(12,846		)	(13,516		)
Other	(12,636		)	(14,295		)
Total deferred tax liabilities	(229,541		)	(212,163		)
Net accumulated deferred income tax liabilities	(211,547		)	(183,696		)
Current accumulated deferred income tax (asset)	(6,398		)	(6,501		)
Non-current accumulated deferred income tax liability	$	(217,945	)	$	(190,197	)

The following table reconciles the change in TNMP’s net accumulated deferred income tax liability to the deferred income tax benefit included in the Consolidated Statement of Earnings:

	Year Ended
	December 31, 2014
	(In thousands)
Net change in deferred income tax liability per above table	$	27,851
Change in tax effects of income tax related regulatory assets and liabilities	(111		)
Adjustment for uncertain tax positions	(6,796		)
Other	(395		)
Deferred income taxes	$	20,549

Other Disclosures

GAAP requires that the Company recognize only the impact of tax positions that, based on their technical merits, are more likely than not to be sustained upon an audit by the taxing authority. A reconciliation of unrecognized tax benefits (expenses) is as follows:

	PNMR			PNM			TNMP
	(In thousands)
Balance at December 31, 2011	$	19,580		$	10,752		$	7,701
Additions based on tax positions related to 2012	2,046			1,152			—
Reductions for tax positions of prior years	(2,428		)	(1,522		)	(905		)
Settlement payments	—			—			—
Balance at December 31, 2012	19,198			10,382			6,796
Additions based on tax positions related to 2013	(54		)	(54		)	—
Additions for tax positions of prior years	745			745			—
Settlement payments	—			—			—
Balance at December 31, 2013	19,889			11,073			6,796
Additions based on tax positions related to 2014	623			623			—
Additions (reductions) for tax positions of prior years	(5,481		)	532			(6,796		)
Settlement payments	—			—			—
Balance at December 31, 2014	$	15,031		$	12,228		$	—

Included in the balance at December 31, 2014 are $4.7 million and $1.9 million of unrecognized tax benefits that, if recognized, would affect the effective tax rate for PNMR and PNM. The Company does not anticipate that any unrecognized tax expenses or unrecognized tax benefits will be reduced or settled in 2015.

Estimated interest income related to refunds the Company expects to receive is included in Other Income and estimated interest expense and penalties related to potential cash settlements are included in interest expense in the Consolidated Statements of Earnings (Loss). Interest income (expense) related to income taxes is as follows:

	PNMR		PNM		TNMP
	(In thousands)
2014	$	146	$	148	$	(2	)
2013	$	242	$	251	$	(2	)
2012	$	243	$	244	$	(3	)

Accumulated accrued interest receivable (payable) related to income taxes is as follows:

	PNMR			PNM			TNMP
	(In thousands)
December 31, 2014:
Accumulated accrued interest receivable	$	3,569		$	3,569		$	—
Accumulated accrued interest payable	$	(1,120	)	$	(24	)	$	(120	)
December 31, 2013:
Accumulated accrued interest receivable	$	4,048		$	4,048		$	—
Accumulated accrued interest payable	$	(1,118	)	$	(24	)	$	(118	)

The Company files a federal consolidated and several consolidated and separate state income tax returns. The tax years prior to 2011 are closed to examination by either federal or state taxing authorities other than Arizona. The tax years prior to 2009 are closed to examination by Arizona taxing authorities. Other tax years are open to examination by federal and state taxing authorities. At December 31, 2014, the Company has $405.7 million of federal net operating loss carryforwards that expire beginning in 2030 and $54.7 million of federal tax credit carryforwards that expire beginning in 2023. State net operating losses expire beginning in 2015 and vary from federal due to differences between state and federal tax law.

PNMR has New Mexico wind energy production tax credit carry forwards with statutory expiration dates beginning in 2014. In 2012, PNMR impaired $0.7 million, after federal tax benefit, of the New Mexico wind energy production tax credit carry forwards that were not expected to be utilized prior to their expiration due to the Company’s net operating loss position. The impairment is reflected in PNMR’s Corporate and Other segment.

On January 3, 2013, the American Taxpayer Relief Act of 2012, which extended fifty percent bonus depreciation for 2013, 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 year ended December 31, 2013. The 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 is being phased in from 2014 to 2018. In accordance with GAAP, PNMR and PNM adjusted accumulated deferred income taxes to reflect the tax rate at which the balances are expected to reverse during the period that includes the date of enactment, which was in the year ended December 31, 2013. At that time, the portion of the adjustment related to PNM's regulated activities was recorded as a reduction in deferred tax liabilities, which was offset by an increase in a regulatory liability, on the assumption that PNM will be required to return the benefit to customers over time. 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 in PNMR’s Corporate and Other segment as a reduction in deferred tax assets and an increase in income tax expense of $1.2 million during the year ended December 31, 2013. 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 year ended December 31, 2014, PNM’s deferred tax liabilities were increased by $4.6 million, which reduced regulatory liabilities. Additionally, deferred tax assets not related to PNM’s regulatory activities were increased by $0.1 million, of which $0.2 million increased income tax expense in PNMR's Corporate and Other segment and $0.3 million decreased income tax expense in PNM.

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 year ended December 31, 2013. This impairment is reflected in PNMR's Corporate and Other segment.

On December 19, 2014, the Tax Increase Prevention Act of 2014, which retroactively extended fifty percent bonus tax depreciation for 2014, was signed into law.  Due to provisions in the act, taxes payable to the State of New Mexico for 2014 were reduced, which resulted in an impairment of New Mexico wind energy production tax credits, which after federal income tax benefit, amounted to $0.9 million. The impairment is reflected in PNMR’s Corporate and Other segment. Additionally, the act resulted in an impairment of New Mexico net operating loss carryforwards, which after federal income tax benefit, amounted to $3.1 million. Of this amount, $2.1 million is reflected in PNM and $1.0 million is reflected in PNMR’s Corporate and Other segment. In accordance with GAAP, these impairments were recorded as additional income tax expense during the year ended December 31, 2014. The impairment of the New Mexico net operating loss carryforward is reflected as a valuation allowance against deferred tax assets. No such impairments occurred in prior years. TNMP had no such impairment.

The impairments of the New Mexico wind energy production tax credits discussed above are reflected as a valuation allowance against deferred tax assets. At December 31, 2014, PNMR had a total valuation allowance for these credits of $5.5 million. During the years ended December 31, 2014, 2013, and 2012, the valuation allowance for these credits increased by $0.9 million, $3.9 million, and $0.7 million. PNM and TNMP have no such valuation allowances.

In April 2013, the IRS issued Revenue Procedure 2013-24, which provides a safe harbor method of accounting that taxpayers may use to determine repair costs for electric generation property.  Adoption of the safe harbor method is elective for years ending on or after December 31, 2012.  On July 11, 2013, the IRS issued a directive that suspends most current examination activity related to generation repairs methodology for any company that is eligible for the safe harbor. PNM is evaluating the possible effects of adopting the safe harbor method and the ultimate outcome cannot be determined at this time although the effects are not expected to be material due to PNMR’s net operating loss carryforward position.

In September 2013, the IRS issued final regulations addressing the recovery of amounts paid to acquire, produce, or improve tangible personal property and the accounting for and retirement of depreciable property. Also issued were proposed regulations addressing dispositions of property. Repairs of electric transmission and distribution property and repairs of electric generation property are specifically addressed in other Revenue Procedures issued by the IRS. The effects of the remainder of regulations are being evaluated by the Company and cannot be determined at this time. However, due to PNMR's net operating loss carryforward position for income tax purposes, the effects are not expected to be material.

In May 2013, PNMR received a refund of federal income taxes paid in prior years, which primarily was due to bonus tax depreciation and changes in the Company's method of accounting for repairs expense for income tax purposes. The total refund was $96.2 million of which $77.4 million was attributable to PNM.

In 2013, the FASB issued Accounting Standards Update 2013-11, which requires entities to present liabilities for uncertain tax positions 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 those liabilities upon settlement.  The Company adopted the change for 2014.  Had the Company applied the update at December 31, 2013, the effect would have been decreases in net operating loss 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 uncertain tax positions. There was no impact to earnings from adopting the update.

In June 2014, the Company settled the IRS examination of income tax years 2003 and 2005 through 2008. As a result of the settlement, the Company received net federal tax refunds of $2.0 million. The IRS examination resulted in the settlement of certain issues for which the Company had previously reflected liabilities related to uncertain tax positions. The settlement of the IRS examination, including the uncertain tax position matters, resulted in PNMR recording an income tax benefit of $0.2 million on a consolidated basis in the year ended December 31, 2014. PNM recorded an income tax expense of $1.1 million, TNMP reflected no impact, and an income tax benefit of $1.3 million was recorded in PNMR’s Corporate and Other segment.

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Pension and Other Postretirement Benefits Pre-Tax Information about Prior Service Cost and Net Actuarial (Gain) loss in AOCI (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014
Public Service Company of New Mexico [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Prior service cost (credit) - Amounts in AOCI not yet recognized in net periodic benefit cost (income) at beginning of year	$ (2,665)
Net actuarial (gain) loss - Amounts in AOCI not yet recognized in net periodic benefit cost (income) at beginning of year	139,256
Prior service cost (credit) - Experience loss (gain)	0
Net actuarial (gain) loss - Experience loss (gain)	34,345
Prior service cost (credit) - Regulatory asset (liability) adjustment	0
Net actuarial (gain) loss - Regulatory asset (liability) adjustment	(19,920)
Prior service cost (credit) - Amortization recognized in net periodic benefit cost (income)	405
Net actuarial (gain) loss - Amortization recognized in net periodic benefit cost (income)	(5,469)
Prior service cost (credit) - Amounts in AOCI not yet recognized in net periodic benefit cost (income) at end of year	(2,260)
Net actuarial (gain) loss - Amounts in AOCI not yet recognized in net periodic benefit cost (income) at end of year	148,212
Prior service cost (credit) - Amortization expected to be recognized in in 2015	(405)
Net actuarial (gain) loss - Amortization expected to be recognized in in 2015	6,224
Public Service Company of New Mexico [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Net actuarial (gain) loss - Experience loss (gain)	2,800
Public Service Company of New Mexico [Member] | Executive Retirement Program [Member]
Defined Benefit Plan Disclosure [Line Items]
Net actuarial (gain) loss - Amounts in AOCI not yet recognized in net periodic benefit cost (income) at beginning of year	1,833
Net actuarial (gain) loss - Experience loss (gain)	2,040
Net actuarial (gain) loss - Regulatory asset (liability) adjustment	(1,183)
Net actuarial (gain) loss - Amortization recognized in net periodic benefit cost (income)	(88)
Net actuarial (gain) loss - Amounts in AOCI not yet recognized in net periodic benefit cost (income) at end of year	2,602
Net actuarial (gain) loss - Amortization expected to be recognized in in 2015	136
Texas-New Mexico Power Company [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Net actuarial (gain) loss - Amounts in AOCI not yet recognized in net periodic benefit cost (income) at beginning of year	0
Net actuarial (gain) loss - Experience loss (gain)	4,420
Net actuarial (gain) loss - Regulatory asset (liability) adjustment	(4,420)
Net actuarial (gain) loss - Amortization recognized in net periodic benefit cost (income)	0
Net actuarial (gain) loss - Amounts in AOCI not yet recognized in net periodic benefit cost (income) at end of year	0
Net actuarial (gain) loss - Amortization expected to be recognized in in 2015	0
Texas-New Mexico Power Company [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Net actuarial (gain) loss - Experience loss (gain)	1,300
Texas-New Mexico Power Company [Member] | Executive Retirement Program [Member]
Defined Benefit Plan Disclosure [Line Items]
Net actuarial (gain) loss - Amounts in AOCI not yet recognized in net periodic benefit cost (income) at beginning of year	0
Net actuarial (gain) loss - Experience loss (gain)	(110)
Net actuarial (gain) loss - Regulatory asset (liability) adjustment	110
Net actuarial (gain) loss - Amortization recognized in net periodic benefit cost (income)	0
Net actuarial (gain) loss - Amounts in AOCI not yet recognized in net periodic benefit cost (income) at end of year	0
Net actuarial (gain) loss - Amortization expected to be recognized in in 2015	$ 0

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Lease Commitments

12 Months Ended

Dec. 31, 2014

Leases [Abstract]

Leases Commitments

Lease Commitments

The Company leases office buildings, vehicles, and other equipment under operating leases. In addition, PNM leases interests in Units 1 and 2 of PVNGS and an interest in the EIP transmission line. Many of PNM’s electric transmission and distribution facilities are located on lands that require the grant of rights-of-way from governmental entities, Native American tribes, or private parties. PNM has completed several renewals of rights-of-way, the largest of which is a renewal with the Navajo Nation, and has no significant rights-of-way that will expire within the next five years. PNM is obligated to pay the Navajo Nation annual payments of $6.0 million, subject to adjustment each year based on the Consumer Price Index, through 2029. All of the Company’s leases, including the Navajo Nation rights-of-way agreement, are accounted for as operating leases.

The PVNGS leases were entered into in 1985 and 1986 and were scheduled to expire on January 15, 2015 for the four Unit 1 leases and January 15, 2016 for the four Unit 2 leases. Each of the leases provided PNM with an option to purchase the leased assets at fair market value at the end of the leases, but PNM does not have a fixed price purchase option. In addition, the leases provided PNM with options to renew the leases at fixed rates set forth in each of the leases for two years beyond the termination of the original lease terms. The option periods on certain leases could be further extended for up to an additional six years (the “Maximum Option Period”) if the appraised remaining useful lives and fair value of the leased assets are greater than parameters set forth in the leases. The rental payments during the fixed renewal option periods would be 50% of the amounts during the original terms of the leases. Gross annual lease payments, before considering the impacts of amounts returned to PNM through ownership of the lessor notes, aggregate $33.0 million for the Unit 1 leases and $23.7 million for the Unit 2 leases. For leases that are extended, the leases provide PNM with the option to purchase the leased assets at fair market value at the end of the extended lease terms.

Each lease provided that no later than three years prior to the expiration of the lease, PNM was required to give notice to the lessor if it would “retain” the leased assets (but without specifying whether it would purchase the leased assets or extend the lease) or “return” the leased assets to the lessor. Furthermore, each lease provided that, if PNM gave notice to “retain” the leased assets, PNM was required to give notice as to which of the purchase or renewal options it would exercise no later than two years prior to the expiration of the lease. The election made under each of the leases was independent of the elections made under the other 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 January 15, 2024. The annual payments during the renewal periods aggregate $16.5 million for the PVNGS Unit 1 leases and $1.6 million for the Unit 2 lease. The table of future lease payments as of December 31, 2014 shown below includes payments during the renewal periods for those leases that will be extended at the end of their original terms.

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 31.25 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 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 was $79.9 million on June 1, 2014, $81.8 million on December 31, 2014, and escalates 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 was $5.8 million on June 1, 2014, $4.5 million on December 31, 2014, and declines to $1.2 million on January 14, 2016. PNMR and PNM are unable to predict whether or not the early purchase will occur.

Covenants in PNM’s PVNGS Units 1 and 2 lease agreements limit PNM’s ability, without consent of the owner participants in the lease transactions, (i) to enter into any merger or consolidation, or (ii) except in connection with normal dividend policy, to convey, transfer, lease or dividend more than 5% of its assets in any single transaction or series of related transactions. PNM is exposed to losses under the PVNGS lease arrangements upon the occurrence of certain events that PNM does not consider to be reasonably likely to occur. Under certain circumstances (for example, the NRC issuing specified violation orders with respect to PVNGS or the occurrence of specified nuclear events), PNM would be required to make specified payments to the equity participants, and take title to the leased interests. If such an event had occurred as of December 31, 2014, PNM could have been required to pay the equity participants up to approximately $122.2 million on January 15, 2015 in addition to the scheduled lease payments due on January 15, 2015. In such event, PNM would record the acquired assets at the lower of their fair value or the aggregate of the amount paid and PNM’s carrying value of its investment in PVNGS lessor notes. Exercise of renewal options under the leases requires that amounts payable to equity participants under the circumstances described above would increase to the fair market value as of the renewal date. Reflecting the lease renewals that were effective on January 15, 2015, if such an event were to occur, amounts payable to equity participants under the circumstances described above would be up to $217.3 million on July 15, 2015 in addition to the scheduled lease payments due on July 15, 2015.

PNM owns 60% of the EIP and leases the other 40%, under a lease that expires on April 1, 2015. The lease provides PNM the option, with 24 months advance notice, of purchasing the leased assets at the end of the lease for fair market value, as well as options to renew the lease. On November 1, 2012, PNM and the lessor entered into a definitive agreement for PNM to exercise the option to purchase on April 1, 2015 the leased capacity at fair market value, which the parties agreed would be $7.7 million. The lease remains in existence and PNM will record the purchase at the termination of the lease on April 1, 2015. The definitive agreement sets forth the terms and conditions under which PNM would also assume responsibility for scheduling long-term transmission service on the leased capacity.

PNMR leases a building that was used as part of its corporate headquarters, as well as housing certain support functions for the utility operations of PNM and TNMP. The lease expires on November 30, 2015 and provides for annual rents of $1.9 million, which are included in the tables below. PNMR is also obligated to pay taxes, insurance, and utilities applicable to the building. In November 2011, PNMR notified the lessor of its intent to vacate the building by the end of 2012 and made a settlement offer to terminate the lease. A termination agreement was not reached with the lessor. As of December 31, 2012, PNMR completed the abandonment of this building, as well as the partial abandonment of another leased building. In accordance with GAAP, PNMR recorded an abandonment expense of $7.4 million at December 31, 2012. PNM was allocated $6.2 million and TNMP was allocated $1.2 million of the abandonment expense for the period ended December 31, 2012, which is reflected as administrative and general expense.

Operating lease expense, including the PVNGS and EIP leases, was:

	PNMR		PNM		TNMP
	(In thousands)
2014	$	82,756	$	76,745	$	3,932
2013	$	82,882	$	78,306	$	2,663
2012	$	84,794	$	78,483	$	2,871

As discussed under Investments in Note 1, the PVNGS Capital Trust, which is consolidated by PNM, acquired the lessor notes that were issued by the PVNGS lessors. Future minimum operating lease payments at December 31, 2014 shown below have been reduced by payments on the PVNGS lessor notes of $24.0 million in 2015 and $9.0 million in 2016 that will be returned in cash to PNM:

	PNMR		PNM		TNMP
	(In thousands)
2015	$	36,350	$	33,144	$	1,186
2016	28,892		27,986		636
2017	25,185		24,907		—
2018	25,194		24,907		—
2019	25,203		24,907		—
Later years	134,068		133,842		—
Total minimum lease payments	$	274,892	$	269,693	$	1,822

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Financing Schedule of Long-term Debt Maturities (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2014
Long-term Debt, by Maturity [Abstract]
2015	$ 333,066
2016	100,000
2017	57,000
2018	450,025
2019	172,302
Thereafter	842,743
Total	1,955,136
PNMR [Member]
Long-term Debt, by Maturity [Abstract]
2015	118,766
2016	0
2017	0
2018	0
2019	0
Thereafter	0
Total	118,766
Public Service Company of New Mexico [Member]
Long-term Debt, by Maturity [Abstract]
2015	214,300
2016	100,000
2017	57,000
2018	450,025
2019	0
Thereafter	669,545
Total	1,490,870
Texas-New Mexico Power Company [Member]
Long-term Debt, by Maturity [Abstract]
2015	0
2016	0
2017	0
2018	0
2019	172,302
Thereafter	173,198
Total	$ 345,500

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Stockholders' Equity

12 Months Ended

Dec. 31, 2014

Stockholders' Equity Note [Abstract]

Stockholders' Equity

Stockholders’ Equity

Common Stock and Equity Contributions

PNMR, PNM, and TNMP did not issue any common stock during the three year period ended December 31, 2014. PNMR funded a cash equity contribution of $13.8 million to TNMP in 2013. PNMR offers shares of PNMR common stock through the PNMR Direct Plan. PNMR utilizes shares of its common stock purchased on the open market, by an independent agent, rather than issuing additional shares to satisfy subscriptions under the PNMR Direct Plan. The shares of PNMR common stock utilized in the PNMR Direct Plan are offered under a SEC shelf registration statement that expires in August 2015.

Dividends on Common Stock

The declaration of common dividends by PNMR is dependent upon a number of factors, including the ability of PNMR’s subsidiaries to pay dividends. PNMR’s primary sources of dividends are its operating subsidiaries.

PNM declared and paid cash dividends to PNMR of $30.3 million, $155.0 million, and $34.4 million in 2014, 2013, and 2012. TNMP paid cash dividends to PNMR of $16.3 million, $3.7 million, and $26.0 million in 2014, 2013, and 2012. TNMP recorded dividends paid in 2012 as reductions of paid-in-capital.

The NMPRC has placed certain restrictions on the ability of PNM to pay dividends to PNMR, including the restriction that PNM cannot pay dividends that cause its debt rating to fall below investment grade. The NMPRC provisions allow PNM to pay dividends from equity contributions previously made by PNMR and current earnings, determined on a rolling four quarter basis, without prior NMPRC approval. The Federal Power Act also imposes certain restrictions on dividends by public utilities. Each of the PNMR Revolving Credit Facility, PNMR Term Loan Agreement, PNM Revolving Credit Facility, PNM New Mexico Credit Facility, PNM 2014 Term Loan Agreement, PNM Multi-draw Term Loan, and TNMP Revolving Credit Facility contain a covenant requiring the maintenance of debt-to-capital ratios of not more than 65%, which could limit amounts of dividends that could be paid. For PNMR and PNM, these ratios reflect the present value of payments under the PVNGS leases as debt. PNM also has other financial covenants that limit the transfer of assets, through dividends or other means, including a requirement to obtain approval of certain financial counterparties to transfer more than five percent of PNM’s assets. As of December 31, 2014, none of the numerical tests would restrict the payment of dividends from the retained earnings of PNMR, PNM, or TNMP, except that PNM would not be able to distribute amounts in excess of approximately $223 million and TNMP would not be able to distribute amounts in excess of approximately $203 million without approval of regulators or financial counterparties.

In addition, the ability of PNMR to declare dividends is dependent upon the extent to which cash flows will support dividends, the availability of retained earnings, financial circumstances and performance, current and future regulatory decisions, Congressional and legislative acts, and economic conditions. Conditions imposed by the NMPRC or PUCT, future growth plans and related capital requirements, and business considerations may also affect PNMR’s ability to pay dividends.

Preferred Stock

PNM’s cumulative preferred shares outstanding bear dividends at 4.58% per annum. PNM preferred stock does not have a mandatory redemption requirement but may be redeemed, at PNM’s option, at 102% of the stated value plus accrued dividends. The holders of the PNM preferred stock are entitled to payment before the holders of common stock in the event of any liquidation or dissolution or distribution of assets of PNM. In addition, PNM’s preferred stock is not entitled to a sinking fund and cannot be converted into any other class of stock of PNM.

PNMR and TNMP have no preferred stock outstanding. The authorized shares of PNMR and TNMP preferred stock are 10 million shares and 1 million shares.

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Financing

12 Months Ended

Dec. 31, 2014

Debt Disclosure [Abstract]

Financing

Financing

Financing Activities

PNMR

In the year ended December 31, 2013, PNMR purchased $23.8 million aggregate principal amount of its outstanding 9.25% Senior Unsecured Notes, Series A, due 2015, through several open-market purchases, for $26.9 million plus accrued and unpaid interest. PNMR recognized losses of $3.3 million on these purchases, including transaction costs and write-off of the proportionate amount of the deferred costs of the original issuance of the notes, which are included in Other deductions on the Consolidated Statements of Earnings.

On December 14, 2012, PNMR entered into a $100.0 million Term Loan Agreement (as amended and restated, the “PNMR Term Loan Agreement”) among PNMR, the lenders identified therein, and JPMorgan Chase Bank, N.A., as Administrative Agent. On December 27, 2012, PNMR borrowed $100.0 million under the agreement and used the funds to repay $100.0 million in borrowings made under the PNMR Revolving Credit Facility. On December 27, 2013, PNMR entered into an agreement that amended and restated the PNMR Term Loan Agreement extending the maturity date to December 26, 2014 from December 27, 2013. On December 22, 2014, PNMR entered into another agreement that amends and restates the PNMR Term Loan Agreement extending the maturity date to December 21, 2015. The PNMR 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 PNMR Term Loan Agreement has a cross default provision and a change of control provision.

PNM

In September 2012, PNM participated in the issuance of $20.0 million of new PCRBs by the City of Farmington, New Mexico, which bear interest at 2.54% and mature September 1, 2042, with a mandatory tender on June 1, 2017. The new PCRBs refunded a $20.0 million series of PCRBs, which bore interest at 5.15% and matured in 2037, that were redeemed at par and retired.

On April 22, 2013, PNM entered into a $75.0 million Term Loan Agreement (the “PNM 2013 Term Loan Agreement”) among PNM, the lenders identified therein, and Union Bank, N.A., as Administrative Agent. Funding of the PNM 2013 Term Loan Agreement occurred on April 22, 2013, at which time the funds were used to repay $75.0 million in borrowings made under 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 the PNM 2013 Term Loan Agreement. PNM also used the funds to repay other short-term amounts outstanding. The PNM 2013 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 2013 Term Loan Agreement. The PNM 2014 Term Loan Agreement bears interest at a variable rate, which was 1.11% at December 31, 2014, must be repaid on or before September 4, 2015, and is reflected in current maturities of long-term debt on the Consolidated Balance Sheets. The PNM 2014 Term Loan Agreement includes customary covenants, including requirements to not exceed a maximum consolidated debt-to-capital ratio and customary events of default. The PNM 2014 Term Loan Agreement has a cross default provision and a change of control provision.

On December 22, 2014, PNM entered into a new multi-draw term loan facility (the “PNM Multi-draw Term Loan”) with JPMorgan Chase Bank, N.A., as Lender and Administrative Agent. The $125.0 million facility has a maturity date of June 21, 2016. At December 31, 2014, outstanding borrowings under the PNM Multi-draw Term Loan were $100.0 million and remaining capacity was $25.0 million. The PNM Multi-draw Term Loan bears interest at a variable rate, which was 0.75% at December 31, 2014. The PNM Multi-draw Term Loan includes customary covenants, including requirements to not exceed a maximum consolidated debt-to-consolidated capitalization ratio and customary events of default. The PNM Multi-draw Term Loan Agreement has a cross default provision and a change of control provision.

PNM has a shelf registration statement for the issuance of up to $500.0 million of senior unsecured notes that will expire in May 2017.

TNMP

On September 30, 2011, TNMP entered into the TNMP 2011 Term Loan Agreement and borrowed $50.0 million under it. Borrowings under the TNMP 2011 Term Loan Agreement were due by June 30, 2014. TNMP entered into hedging agreements whereby it effectively established fixed interest rates for such borrowing over the life of the debt. This hedge was accounted for as a cash-flow hedge and had a fair value loss of $0.2 million at December 31, 2013, using Level 2 inputs under GAAP determined using forward LIBOR curves under the mid-market convention to discount cash flows over the remaining term of the swap agreements.

On March 6, 2013, TNMP commenced an offer to exchange any and all of TNMP’s $265.5 million aggregate principal amount outstanding 9.50% First Mortgage Bonds, due 2019, Series 2009A, for a new series of 6.95% First Mortgage Bonds, due 2043, Series 2013A, and up to $140 in cash for each $1,000 of bonds exchanged. Settlement of the exchange offer occurred on April 3, 2013. Upon settlement, TNMP issued $93.2 million of 6.95% First Mortgage Bonds and paid an aggregate of $13.0 million in cash in exchange for $93.2 million of 9.50% First Mortgage Bonds, in addition to payment of accrued and unpaid interest on the exchanged bonds. The exchange resulted in a premium on the 6.95% First Mortgage Bonds reflecting the contractual interest rate being in excess of the market rate of interest on the date of the exchange. The premium amounted to $23.2 million, after reduction for the cash paid in the exchange. A regulatory asset was recorded offsetting the premium, including the cash consideration paid in the exchange.

On December 9, 2013, TNMP entered into an agreement (the “TNMP 2013 Bond Purchase Agreement”), which provided that TNMP would issue $80.0 million aggregate principal amount of 4.03% first mortgage bonds, due 2024 (the “Series 2014A Bonds”) on or about June 27, 2014, subject to satisfaction of certain conditions. TNMP issued the Series 2014A Bonds on June 27, 2014. TNMP used $50.0 million of the proceeds to repay the full outstanding amount of the TNMP 2011 Term Loan Agreement and used the remaining $30.0 million of proceeds to reduce short-term debt. In accordance with GAAP, borrowings under the TNMP 2011 Term Loan Agreement were reflected as being long-term in the Consolidated Balance Sheet at December 31, 2013 since the TNMP 2013 Bond Purchase Agreement demonstrated TNMP’s ability and intent to re-finance the TNMP 2011 Term Loan Agreement on a long-term basis.

Short-term Debt

The PNMR Revolving Credit Facility has a financing capacity of $300.0 million and the PNM Revolving Credit Facility has a financing capacity of $400.0 million. In December 2014, both of these facilities were amended to extend their maturity from October 31, 2018 to October 31, 2019. In addition, the amendments provide for an additional one-year extension option for each facility, subject to approval by a majority of the lenders. The TNMP Revolving Credit Facility is a $75.0 million revolving credit facility secured by $75.0 million aggregate principal amount of TNMP first mortgage bonds. The TNMP Revolving Credit Facility matures on September 18, 2018. Each of these 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 leases as debt.

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.

At December 31, 2014, interest rates on outstanding borrowings were 1.02% for the PNMR Term Loan Agreement (discussed under Financing Activities above), 1.67% for the PNMR Revolving Credit Facility, and 1.17% for the TNMP Revolving Credit Facility. The PNM Revolving Credit Facility and the PNM New Mexico Credit Facility had no borrowings outstanding at December 31, 2014. Short-term debt outstanding consists of:

	December 31,
Short-term Debt	2014		2013
	(In thousands)
PNM:
Revolving Credit Facility	$	—	$	49,200
PNM New Mexico Credit Facility	—		—
TNMP Revolving Credit Facility	5,000		—
PNMR
Revolving Credit Facility	600		—
PNMR Term Loan Agreement	100,000		100,000
	$	105,600	$	149,200

In addition to the above borrowings, PNMR, PNM, and TNMP had letters of credit outstanding of $7.7 million, $3.2 million, and $0.1 million at December 31, 2014 that reduce the available capacity under their respective revolving credit facilities.

At February 20, 2015, PNMR, PNM, and TNMP had $291.5 million, $386.8 million, and $54.9 million of availability under their respective revolving credit facilities, including reductions of availability due to outstanding letters of credit, and PNM had $35.0 million of availability under the PNM New Mexico Credit Facility. Total availability at February 20, 2015, on a consolidated basis, was $768.2 million for PNMR. At February 20, 2015, PNMR had invested cash of $1.9 million, PNM had invested cash of $42.5 million, and TNMP had no invested cash. The above availability does not include remaining capacity of $25.0 million available under the PNM Multi-draw Term Loan at February 20, 2015.

Long-Term Debt

Information concerning long-term debt outstanding is as follows:

	December 31,
Long-term Debt	2014			2013
	(In thousands)
PNM Debt
Senior Unsecured Notes, Pollution Control Revenue Bonds:
4.875% due 2033	$	146,000		$	146,000
6.25% due 2038	36,000			36,000
4.75% due 2040, mandatory tender at June 1, 2017	37,000			37,000
5.20% due 2040, mandatory tender at June 1, 2020	40,045			40,045
5.90% due 2040	255,000			255,000
6.25% due 2040	11,500			11,500
2.54% due 2042, mandatory tender at June 1, 2017	20,000			20,000
4.00% due 2043, mandatory tender at June 1, 2015	39,300			39,300
5.20% due 2043, mandatory tender at June 1, 2020	21,000			21,000
Senior Unsecured Notes:
7.95% due 2018	350,000			350,000
7.50% due 2018	100,025			100,025
5.35% due 2021	160,000			160,000
PNM Term Loan Agreement due 2014	—			75,000
PNM Term Loan Agreement due 2015	175,000			—
PNM Multi-draw Term Loan due 2016	100,000			—
Unamortized premiums (discounts)	(213		)	(252		)
	1,490,657			1,290,618
Less current maturities	214,300			75,000
	1,276,357			1,215,618
TNMP Debt
First Mortgage Bonds:
2011 Term Loan Agreement, due 2014	—			50,000
9.50% due 2019, Series 2009A	172,302			172,302
6.95% due 2043, Series 2013A	93,198			93,198
4.03% due 2024, Series 2014A	80,000			—
Unamortized premiums (discounts)	20,167			20,536
	365,667			336,036
Less current maturities	—			—
	365,667			336,036
PNMR Debt
Senior unsecured notes, 9.25% due 2015	118,766			118,766
Less current maturities	118,766			—
	—			118,766
Total Consolidated PNMR Debt	1,975,090			1,745,420
Less current maturities	333,066			75,000
	$	1,642,024		$	1,670,420

Reflecting mandatory tender dates, long-term debt matures as follows:

	PNMR		PNM		TNMP		PNMR Consolidated
	(In thousands)
2015	$	118,766	$	214,300	$	—	$	333,066
2016	—		100,000		—		100,000
2017	—		57,000		—		57,000
2018	—		450,025		—		450,025
2019	—		—		172,302		172,302
Thereafter	—		669,545		173,198		842,743
Total	$	118,766	$	1,490,870	$	345,500	$	1,955,136

Borrowing Arrangements Between PNMR and its Subsidiaries

PNMR has one-year intercompany loan agreements with its subsidiaries. Individual subsidiary loan agreements vary in amount up to $100.0 million and have either reciprocal or non-reciprocal terms. Interest charged to the subsidiaries is equivalent to interest paid by PNMR on its short-term borrowings. As of December 31, 2014 and 2013, PNM had outstanding borrowings of zero and $32.5 million and TNMP had outstanding borrowings of $22.7 million and $29.4 million from PNMR. At February 20, 2015, PNM and TNMP had borrowings of zero and $17.3 million from PNMR.

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Fair Value of Derivative and Other Financial Instruments

12 Months Ended

Dec. 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. PNM’s operations are managed primarily through a net asset-backed strategy, whereby PNM’s aggregate net open forward contract position is covered by its forecasted excess generation capabilities or market purchases. PNM could be exposed to market risk if its generation capabilities were to be disrupted or if its load requirements were to be greater than anticipated. If all or a portion of load requirements were required to be covered as a result of such unexpected situations, commitments would have to be met through market purchases.

Commodity Risk

Marketing and procurement of energy often involve market risks associated with managing energy commodities and establishing open positions in the energy markets, primarily on a short-term basis. PNM routinely enters into various derivative instruments such as forward contracts, option agreements, and price basis swap agreements to economically hedge price and volume risk on power commitments and fuel requirements and to minimize the effect of market fluctuations in wholesale portfolios. PNM monitors the market risk of its commodity contracts using VaR calculations to maintain total exposure within management-prescribed limits in accordance with approved risk and credit policies.

Accounting for Derivatives

Under derivative accounting and related rules for energy contracts, the Company accounts for its various derivative instruments for the purchase and sale of energy based on the Company’s intent. During the years ended December 31, 2014 and 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
	December 31,
	2014			2013
	(In thousands)
PNM and PNMR
Current assets	$	11,232		$	4,064
Deferred charges	—			3,002
	11,232			7,066
Current liabilities	(1,209		)	(2,699		)
Long-term liabilities	(477		)	(1,094		)
	(1,686		)	(3,793		)
Net	$	9,546		$	3,273

Included in the above table are $3.0 million of current assets at December 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 December 31, 2014 and 2013.

At December 31, 2014 and 2013, PNMR and PNM had no amounts recognized for the legal right to reclaim cash collateral. In addition, at December 31, 2014 and 2013, amounts posted as cash collateral under margin arrangements were $3.8 million and $2.8 million for both PNMR and PNM. At December 31, 2014 and 2013, obligations to return cash collateral were $0.2 million and $0.2 million for both PNMR and PNM. Cash collateral amounts are included in other current assets and other current liabilities on the Consolidated Balance Sheets.

PNM has a NMPRC approved hedging plan to manage fuel and purchased power costs related to customers covered by its FPPAC. The table above includes $0.4 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 Consolidated Balance Sheets. At December 31, 2014, there were no hedges in place under this plan.

The following table presents the effect of mark-to-market commodity derivative instruments on earnings, excluding income tax effects. Commodity derivatives had no impact on OCI for the periods presented.

	Economic Hedges
	Year Ended December 31,
	2014		2013		2012
	(In thousands)
PNMR and PNM
Electric operating revenues	$	4,491	$	1,727	$	6,168
Cost of energy	593		1,109		(460		)
Total gain	$	5,084	$	2,836	$	5,708

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
December 31, 2014
PNMR and PNM	650,000	(1,919,000	)
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)
December 31, 2014
PNMR and PNM	$	1,686	$	—	$	167
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 currently 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 December 31, 2014, PNM had contracted to sell 100% of PVNGS Unit 3 output through 2015, at market price plus a premium.  Through hedging arrangements that are accounted for as economic hedges, PNM has established fixed rates, which average approximately $37 per MWh, for substantially all of these sales.

Non-Derivative Financial Instruments

The carrying amounts reflected on the Consolidated Balance Sheets approximate fair value for cash, receivables, and payables due to the short period of maturity. Available-for-sale securities are carried at fair value. Available-for-sale securities for PNMR and PNM consist of PNM assets held in the NDT for its share of decommissioning costs of PVNGS and, beginning in August 2012, a trust for PNM’s share of post-term reclamation costs related to the coal mines serving SJGS (Note 16). The fair value and gross unrealized gains of investments in available-for-sale securities are presented in the following table. At December 31, 2014 and 2013, the fair value of available-for-sale securities included $244.6 million and $222.5 million for the NDT and $5.5 million and $4.4 million for the mine reclamation trust.

	December 31, 2014				December 31, 2013
	Unrealized  Gains		Fair Value		Unrealized  Gains		Fair Value
PNMR and PNM			(In thousands)
Cash and cash equivalents	$	—	$	8,276	$	—	$	3,356
Equity securities:
Domestic value	17,418		45,340		14,523		39,460
Domestic growth	21,354		74,053		25,656		76,292
International and other	156		16,599		1,040		16,633
Fixed income securities:
U.S. Government	903		22,563		158		21,941
Municipals	5,851		68,973		1,018		58,568
Corporate and other	666		14,341		207		10,605
	$	46,348	$	250,145	$	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 . Gross realized losses shown below exclude the change in realized impairment losses of $(0.7) million, $0.6 million, and $5.2 million.

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Proceeds from sales	$	117,989		$	271,140		$	167,330
Gross realized gains	$	15,162		$	14,308		$	15,907
Gross realized (losses)	$	(3,964	)	$	(4,298	)	$	(8,170	)

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 December 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	$	3,946	$	8,019	$	8,019
After 1 year through 5 years	20,275		25,430		24,817
After 5 years through 10 years	13,422		—		—
After 10 years through 15 years	10,367		—		—
After 15 years through 20 years	11,539		—		—
After 20 years	46,328		—		—
	$	105,877	$	33,449	$	32,836

Fair Value Disclosures

The Company determines the fair values of its derivative and other financial instruments based on the hierarchy established in GAAP, which requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. GAAP describes three levels of inputs that may be used to measure fair value. Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities that the reporting entity has the ability to access at the measurement date. Level 2 inputs are inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly. Level 3 inputs are unobservable inputs for the asset or liability. Level 3 inputs used in determining fair values for the Company consist of internal valuation models. The Company records any transfers between fair value hierarchy levels as of the end of each calendar quarter. There were no transfers between levels during the years ended December 31, 2014 and 2013.

For available-for-sale securities, Level 2 fair values are provided by the trustee utilizing a pricing service. The pricing provider predominantly uses the market approach using bid side market value based upon a hierarchy of information for specific securities or securities with similar characteristics. For commodity derivatives, Level 2 fair values are determined based on market observable inputs, which are validated using multiple broker quotes, including forward price, volatility, and interest rate curves to establish expectations of future prices. Credit valuation adjustments are made for estimated credit losses based on the overall exposure to each counterparty. For the Company’s long-term debt, Level 2 fair values are provided by an external pricing service. The pricing service primarily utilizes quoted prices for similar debt in active markets when determining fair value. For investments categorized as Level 3, primarily the PVNGS lessor notes and certain items in other investments, fair values were determined by discounted cash flow models that take into consideration discount rates that are observable for similar types of assets and liabilities. Management of the Company independently verifies the information provided by pricing services.

Items recorded at fair value on the Consolidated Balance Sheets are presented below by level of the fair value hierarchy. There were no Level 3 fair value measurements at December 31, 2014 and 2013 for items recorded at fair value.

				GAAP Fair Value Hierarchy
	Total			Quoted Prices in Active Market for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)
December 31, 2014				(In thousands)
PNMR and PNM
Available-for-sale securities
Cash and cash equivalents	$	8,276		$	8,276	$	—
Equity securities:
Domestic value	45,340			45,340		—
Domestic growth	74,053			74,053		—
International and other	16,599			16,599		—
Fixed income securities:
U.S. Government	22,563			20,808		1,755
Municipals	68,973			—		68,973
Corporate and other	14,341			4,843		9,498
	$	250,145		$	169,919	$	80,226
Commodity derivative assets	$	11,232		$	—	$	11,232
Commodity derivative liabilities	(1,686		)	—		(1,686		)
Net	$	9,546		$	—	$	9,546

				GAAP Fair Value Hierarchy
	Total			Quoted Prices in Active Market for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)
December 31, 2013				(In thousands)
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 carrying amounts and fair values of investments in PVNGS lessor notes, other investments, and long-term debt are presented below:

					GAAP Fair Value Hierarchy
	Carrying Amount		Fair Value		Level 1		Level 2		Level 3
December 31, 2014	(In thousands)
PNMR
Long-term debt	$	1,975,090	$	2,173,117	$	—	$	2,173,117	$	—
Investment in PVNGS lessor notes	$	31,232	$	32,836	$	—	$	—	$	32,836
Other investments	$	1,762	$	2,375	$	639	$	—	$	1,736
PNM
Long-term debt	$	1,490,657	$	1,624,222	$	—	$	1,624,222	$	—
Investment in PVNGS lessor notes	$	31,232	$	32,836	$	—	$	—	$	32,836
Other investments	$	397	$	397	$	397	$	—	$	—
TNMP
Long-term debt	$	365,667	$	427,356	$	—	$	427,356	$	—
Other investments	$	242	$	242	$	242	$	—	$	—
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	$	—	$	—

Investments Held by Employee Benefit Plans

As discussed in Note 12, PNM and TNMP have trusts that hold investment assets for their pension and other postretirement benefit plans. The fair value of the assets held by the trusts impacts the determination of the funded status of each plan, but the assets are not reflected on the Company’s Consolidated Balance Sheets. Both the PNM Pension Plan and the TNMP Pension Plan hold units of participation in the PNM Resources, Inc. Master Trust (the “PNMR Master Trust”), which was established for the investment of assets of the pension plans. Level 2 and Level 3 fair values are provided by fund managers utilizing a pricing service. For level 2 fair values, the pricing provider predominately uses the market approach using bid side market value based upon a hierarchy of information for specific securities or securities with similar characteristics. Level 2 investments in mutual funds are measured at net asset value as year-end. Level 3 investments are comprised of alternative investments, which are measured at net asset value at year-end and include private equity funds, hedge funds, and real estate funds. The private equity funds are not voluntarily redeemable. These investments are realized through periodic distributions occurring over a 10 to 15-year term after the initial investment. The real estate funds and hedge funds may be voluntarily redeemed, but are subject to redemption provisions that may result in the funds not being able to be redeemed in the near term. Audited financial statements are received for each fund and are reviewed by the Company annually.

The valuation of alternative investments requires significant judgment by the pricing provider due to the absence of quoted market values, changes in market conditions, and the long-term nature of the assets. The significant unobservable inputs include the trading multiples of public companies that are considered comparable to the company being valued, company specific issues, estimates of liquidation value, current operating performance and future expectations of performance, changes in market outlook and the financing environment, capitalization rates, discount rates and cash flows. The fair values of investments held by the employee benefit plans are as follows:

			GAAP Fair Value Hierarchy
	Total		Quoted Prices in Active Market for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
December 31, 2014			(In thousands)
PNM Pension Plan
Participation in PNMR Master Trust Total Plan Investments	$	588,112	$	123,668	$	398,819	$	65,625
TNMP Pension Plan
Participation in PNMR Master Trust Total Plan Investments	$	69,207	$	14,823	$	44,425	$	9,959
PNM OPEB Plan
Cash and cash equivalents	$	1,242	$	1,242	$	—	$	—
Equity securities:
International funds	10,332		—		10,332		—
Domestic value	8,365		8,365		—		—
Domestic growth	5,960		5,960		—		—
Other funds	30,997		—		30,997		—
Fixed income securities:
Mutual funds	22,122		22,122		—		—
	$	79,018	$	37,689	$	41,329	$	—
TNMP OPEB Plan
Cash and cash equivalents	$	168	$	168	$	—	$	—
Equity securities:
International funds	1,277		—		1,277		—
Domestic value	403		403		—		—
Domestic growth	1,024		1,024		—		—
Other funds	3,790		—		3,790		—
Fixed income securities:
Mutual funds	3,549		3,549		—		—
	$	10,211	$	5,144	$	5,067	$	—

			GAAP Fair Value Hierarchy
	Total		Quoted Prices in Active Market for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
December 31, 2013	(In thousands)
PNM Pension Plan
Participation in PNMR Master Trust	$	557,258	$	145,364	$	330,903	$	80,991
TNMP Pension Plan
Participation in PNMR Master Trust	$	66,285	$	18,657	$	32,620	$	15,008
PNM OPEB Plan
Cash and cash equivalents	$	1,152	$	1,152	$	—	$	—
Equity securities:
International funds	11,634		—		11,634		—
Domestic value	6,388		6,388		—		—
Domestic growth	24,135		7,094		17,041		—
Other funds	14,028		—		14,028		—
Fixed income securities:
Mutual funds	16,796		16,796		—		—
	$	74,133	$	31,430	$	42,703	$	—
TNMP OPEB Plan
Cash and cash equivalents	$	302	$	302	$	—	$	—
Equity securities:
International funds	1,334		—		1,334		—
Domestic value	381		381		—		—
Domestic growth	4,171		1,848		2,323		—
Other funds	1,844		—		1,844		—
Fixed income securities:
Mutual funds	1,702		1,702		—		—
	$	9,734	$	4,233	$	5,501	$	—

The fair values of investments in the PNMR Master Trust are as follows:

			GAAP Fair Value Hierarchy
	Total		Quoted Prices in Active Market for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
December 31, 2014	(In thousands)
PNMR Master Trust
Cash and cash equivalents	$	15,645	$	15,645	$	—	$	—
Equity securities:
International	23,282		—		23,282		—
Domestic value	41,778		41,778		—		—
Domestic growth	28,370		28,370		—		—
Other funds	29,719		—		29,719		—
Fixed income securities:
Corporate	242,742		—		242,015		727
U.S. Government	106,634		52,537		54,097		—
Municipals	20,156		—		20,156		—
Other funds	74,136		161		73,975		—
Alternative investments:
Private equity funds	37,220		—		—		37,220
Hedge funds	23,876		—		—		23,876
Real estate funds	13,761		—		—		13,761
	$	657,319	$	138,491	$	443,244	$	75,584
December 31, 2013
PNMR Master Trust
Cash and cash equivalents	$	16,281	$	16,281	$	—	$	—
Equity securities:
International	24,471		24,471		—		—
Domestic value	41,451		41,451		—		—
Domestic growth	36,805		36,805		—		—
Other funds	22,522		—		22,522		—
Fixed income securities:
Corporate	202,897		363		202,358		176
U.S. Government	99,748		44,541		55,207		—
Municipals	17,259		—		17,259		—
Other funds	66,286		109		66,177		—
Alternative investments:
Private equity funds	39,122		—		—		39,122
Hedge funds	34,912		—		—		34,912
Real estate funds	21,789		—		—		21,789
	$	623,543	$	164,021	$	363,523	$	95,999

A reconciliation of the changes in Level 3 fair value measurements is as follows:

	Year Ended December 31,
	2014			2013
Level 3 Fair Value Assets and Liabilities	(In thousands)
PNM Pension	Master Trust			Master Trust
Balance at beginning of period	$	80,991		$	79,017
Actual return on assets sold during the period	10,376			3,303
Actual return on assets still held at period end	(5,731		)	3,361
Purchases	8,832			15,110
Sales	(28,843		)	(19,800		)
Balance at end of period	65,625			80,991
TNMP Pension
Balance at beginning of period	$	15,008		$	14,171
Actual return on assets sold during the period	3,409			1,400
Actual return on assets still held at period end	(1,883		)	1,425
Purchases	2,902			6,408
Sales	(9,477		)	(8,396		)
Balance at end of period	9,959			15,008
Total	$	75,584		$	95,999

Additional information concerning changes in Level 3 fair value measurements for the PNMR Master Trust is as follows:

Level 3 Fair Value Assets and Liabilities

PNMR Master Trust	Private equity funds			Hedge funds			Real estate funds			Fixed income - corporate			Total
				(In thousands)
Balance at December 31, 2012	$	38,212		$	31,277		$	23,699		$	—		$	93,188
Actual return on assets sold during the period	4,677			135			(109		)	1			4,704
Actual return on assets still held at period end	1,162			3,500			123			—			4,785
Purchases	3,117			16,151			2,076			175			21,519
Sales	(8,046		)	(16,151		)	(4,000		)	—			(28,197		)
Balance at December 31, 2013	39,122			34,912			21,789			176			95,999
Actual return on assets sold during the period	5,355			8,667			(236		)	—			13,786
Actual return on assets still held at period end	(296		)	(7,536		)	237			(20		)	(7,615		)
Purchases	3,656			5,500			1,971			608			11,735
Sales	(10,617		)	(17,667		)	(10,000		)	(37		)	(38,321		)
Balance at December 31, 2014	$	37,220		$	23,876		$	13,761		$	727		$	75,584

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Fair Value of Derivative and Other Financial Instruments, Derivative Balance Sheet Information (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Derivatives, Fair Value [Line Items]
Commodity derivative instruments, Current assets	$ 11,232,000	$ 4,064,000
Commodity derivative instruments, Deferred charges	0	3,002,000
Commodity derivative instruments, Current liabilities	(1,209,000)	(2,699,000)
Commodity derivative instruments, Long-term liabilities	(477,000)	(1,094,000)
PNMR and PNM [Member]
Derivatives, Fair Value [Line Items]
Derivative, Collateral, Right to Reclaim Cash	0
Margin Deposit Assets	3,800,000	2,800,000
Derivative, Collateral, Obligation to Return Cash	200,000	200,000
PNMR and PNM [Member] | Economic hedges [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative instruments, Current assets	11,232,000	4,064,000
Commodity derivative instruments, Deferred charges	0	3,002,000
Commodity derivative instruments, Assets	11,232,000	7,066,000
Commodity derivative instruments, Current liabilities	(1,209,000)	(2,699,000)
Commodity derivative instruments, Long-term liabilities	(477,000)	(1,094,000)
Commodity derivative instruments, Liabilities	(1,686,000)	(3,793,000)
Commodity derivative instruments, Net	9,546,000	3,273,000
PNMR and PNM [Member] | Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Palo Verde Nuclear Generating Station [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative instruments, Current assets	3,000,000	3,000,000
Commodity derivative instruments, Deferred charges		3,000,000
Public Service Company of New Mexico [Member] | Economic hedges [Member] | Commodity Contract [Member] | Fuel and purchased power adjustment clause [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative instruments, Current assets	0	400,000
Commodity derivative instruments, Current liabilities		$ (100,000)

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Pension and Other Postretirement Benefits Components of Net Periodic Benefit Cost (Income) Recognized (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Public Service Company of New Mexico [Member] | Pension Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	$ 0	$ 0	$ 0
Interest cost	30,163	28,142	32,232
Expected return on plan assets	(38,044)	(41,930)	(41,301)
Amortization of net (gain) loss	13,020	14,840	10,516
Amortization of prior service cost (credit)	(965)	76	317
Net periodic benefit cost	4,174	1,128	1,764
Public Service Company of New Mexico [Member] | Executive Retirement Program [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	0	0	0
Interest cost	822	720	876
Amortization of net (gain) loss	210	232	83
Amortization of prior service cost (credit)	0	0	0
Net periodic benefit cost	1,032	952	959
Public Service Company of New Mexico [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	181	260	217
Interest cost	4,630	4,113	5,293
Expected return on plan assets	(5,638)	(5,043)	(4,901)
Amortization of net (gain) loss	2,225	4,242	3,888
Amortization of prior service cost (credit)	(1,343)	(1,343)	(1,343)
Net periodic benefit cost	55	2,229	3,154
Texas-New Mexico Power Company [Member] | Pension Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	0	0	0
Interest cost	3,193	3,087	3,635
Expected return on plan assets	(4,526)	(4,849)	(5,324)
Amortization of net (gain) loss	665	1,049	462
Amortization of prior service cost (credit)	0	0	0
Net periodic benefit cost	(668)	(713)	(1,227)
Texas-New Mexico Power Company [Member] | Executive Retirement Program [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	0	0	0
Interest cost	39	36	45
Amortization of net (gain) loss	0	0	0
Amortization of prior service cost (credit)	0	0	0
Net periodic benefit cost	39	36	45
Texas-New Mexico Power Company [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	237	299	244
Interest cost	619	566	624
Expected return on plan assets	(534)	(503)	(516)
Amortization of net (gain) loss	(122)	0	(209)
Amortization of prior service cost (credit)	32	57	57
Net periodic benefit cost	$ 232	$ 419	$ 200

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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	Dec. 31, 2014	Dec. 31, 2013
Derivative [Line Items]
Contractual Liability	$ 1,686	$ 2,398
Existing Cash Collateral	0	0
Net Exposure	$ 167	$ 2,152
Long [Member] | Commodity Contract [Member] | Economic hedges [Member]
Derivative [Line Items]
Volume positions (MMBTU/ MWh)	650,000,000	905,000,000
Short [Member] | Commodity Contract [Member] | Economic hedges [Member]
Derivative [Line Items]
Volume positions (MMBTU/ MWh)	1,919,000,000	3,343,783,000

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Schedule I - Condensed Financial Information of Parent Company (Statements of Earnings) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Condensed Financial Statements, Captions [Line Items]
Operating Expenses									$ 1,136,156	$ 1,101,081	$ 1,068,682
Operating income	62,849	116,799	71,296	48,753	40,532	117,739	77,867	50,704	299,697	286,842	273,721
Other Income and Deductions:
Other income									12,048	10,572	12,746
Other (deductions)									(10,481)	(21,552)	(17,636)
Net other income and deductions									20,577	9,675	22,159
Earnings before Income Taxes									200,647	175,069	175,035
Income Taxes									69,738	59,513	54,910
Net Earnings Attributable to Company	18,992	55,653	29,141	12,468	7,648	54,555	27,678	10,626	116,254	100,507	105,547
PNM Resources [Member]
Condensed Financial Statements, Captions [Line Items]
Non-affiliates									0	0	0
Operating Expenses									650	941	3,287
Operating income									(650)	(941)	(3,287)
Other Income and Deductions:
Equity in earnings of subsidiaries									124,543	116,634	117,900
Other income									622	769	670
Other (deductions)									(13,650)	(22,825)	(20,904)
Net other income and deductions									111,515	94,578	97,666
Earnings before Income Taxes									110,865	93,637	94,379
Income Taxes									(5,389)	(6,870)	(11,168)
Net Earnings Attributable to Company									$ 116,254	$ 100,507	$ 105,547

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Lease Commitments Schedule of Future Minimum Rental Payments for Operating Leases (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2014
PNMR [Member]
Lease commitments
2015	$ 36,350
2016	28,892
2017	25,185
2018	25,194
2019	25,203
Later years	134,068
Total minimum lease payments	274,892
Public Service Company of New Mexico [Member]
Lease commitments
2015	33,144
2016	27,986
2017	24,907
2018	24,907
2019	24,907
Later years	133,842
Total minimum lease payments	269,693
Texas-New Mexico Power Company [Member]
Lease commitments
2015	1,186
2016	636
2017	0
2018	0
2019	0
Later years	0
Total minimum lease payments	1,822
Palo Verde Nuclear Generating Station, Unit 2 Leases [Member] | Public Service Company of New Mexico [Member]
Lease commitments
2015	24,000
2016	$ 9,000

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Stock-Based Compensation Plans (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Jan. 01, 2015	Feb. 28, 2014	Feb. 26, 2015
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]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized	135,000
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]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized	35,000
Subsequent Event [Member] | Achieved performance target for 2015 and 2016 [Member] | Common Stock [Member] | Executive Vice President and Chief Financial Officer [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Share-based compensation arrangement by share-based payment award, Purchase price of common stock				$ 100,000
Subsequent Event [Member] | Achieved performance target for 2015, 2016 and 2017 [Member] | Common Stock [Member] | Executive Vice President and Chief Financial Officer [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Share-based compensation arrangement by share-based payment award, Purchase price of common stock				275,000
Performance Shares [Member] | Executive [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Excluded from Shares Outstanding, Number	179,845	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 2013	179,811
Share-based Compensation Arrangement by Share-based Payment Award, Maximum Number of Shares in 2014	163,152
Performance Shares [Member] | Subsequent Event [Member] | Executive [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Share based Compensation, weighted percentage assigned to achieving market targets						60.00%
Share based Compensation, weighted percentage assigned to achieving performance targets						40.00%
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Restricted Stock, at Beginning of period, Shares	315,305
Restricted Stock, at Beginning of period, Weighted-Average Grant-Date Fair Value, in dollars per share	$ 17.87
Restricted Stock, Granted, Shares	242,164
Restricted Stock, Granted, Fair Value, in dollars per share	$ 21.27	$ 20.03	$ 16.75
Restricted Stock, Vested, Shares	(295,423)
Restricted Stock, Vested, Weighted-Average Grant-Date Fair Value, in dollars per share	$ 16.70
Restricted Stock, Forfeited, Shares	(3,276)
Restricted Stock, Forfeited, Weighted-Average Grant-Date Fair Value, in dollars per share	$ 22.46
Restricted Stock, at end of period, Shares	258,770	315,305
Restricted Stock, at end of period, Weighted-Average Grant-Date Fair Value, in dollars per share	$ 22.31	$ 17.87
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Additional Disclosures [Abstract]
Weighted-average grant date fair value	$ 21.27	$ 20.03	$ 16.75
Total fair value of restricted shares that vested (in thousands)	4,933,000	4,395,000	5,099,000
Stock Options [Member]
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	(345,426)
Options, Exercised, Weighted-Average Exercise Price, in dollars per share	$ 20.04
Options, Forfeited, Shares	(17,151)
Options, Forfeited, Weighted-Average Exercise Price, in dollars per share	$ 26.43
Options, Expired, Shares	(60,584)
Options, Expired, Weighted-Average Exercise Price, in dollars per share	$ 27.98
Options, Outstanding at end of period, Shares	920,505	1,343,666
Options, Outstanding at end of period, Weighted-Average Exercise Price, in dollars per share	$ 20.39	$ 20.63
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Options, Outstanding at end of period, Aggregate Intrinsic Value	8,900,000
Options, Outstanding at end of period, Weighted-Average Remaining Contract Life (years)	2 years 9 months 29 days
Options, Outstanding at end of period, No intrinsic value	254,050,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Additional Disclosures [Abstract]
Weighted-average grant date fair value options granted, in dollars per share	$ 0.00	$ 0.00	$ 0.00
Total fair value of options that vested	0	625,000	1,054,000
Total intrinsic value of options exercised	$ 2,473,000	$ 2,721,000	$ 6,356,000

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Segment Information (Tables)

12 Months Ended

Dec. 31, 2014

Segment Reporting [Abstract]

Schedule of Segment Reporting Information, by Segment

PNMR SEGMENT INFORMATION

2014	PNM			TNMP			Corporate and Other			Consolidated
	(In thousands)
Electric operating revenues	$	1,147,914		$	287,939		$	—		$	1,435,853
Cost of energy	403,626			67,930			—			471,556
Margin	744,288			220,009			—			964,297
Other operating expenses	422,051			84,365			(14,450		)	491,966
Depreciation and amortization	109,524			50,056			13,054			172,634
Operating income	212,713			85,588			1,396			299,697
Interest income	8,557			—			(74		)	8,483
Other income (deductions)	12,258			2,138			(2,302		)	12,094
Interest charges	(79,442		)	(27,396		)	(12,789		)	(119,627		)
Segment earnings (loss) before income taxes	154,086			60,330			(13,769		)	200,647
Income taxes (benefit)	52,633			22,523			(5,418		)	69,738
Segment earnings (loss)	101,453			37,807			(8,351		)	130,909
Valencia non-controlling interest	(14,127		)	—			—			(14,127		)
Subsidiary preferred stock dividends	(528		)	—			—			(528		)
Segment earnings (loss) attributable to PNMR	$	86,798		$	37,807		$	(8,351	)	$	116,254
Gross property additions	$	316,800		$	127,191		$	16,667		$	460,658
At December 31, 2014:
Total Assets	$	4,473,652		$	1,240,241		$	115,432		$	5,829,325
Goodwill	$	51,632		$	226,665		$	—		$	278,297

2013	PNM			TNMP			Corporate and Other			Consolidated
Electric operating revenues	$	1,116,312		$	271,611		$	—		$	1,387,923
Cost of energy	374,710			57,606			—			432,316
Margin	741,602			214,005			—			955,607
Other operating expenses	428,591			91,601			(18,308		)	501,884
Depreciation and amortization	103,826			50,219			12,836			166,881
Operating income	209,185			72,185			5,472			286,842
Interest income	10,182			—			(139		)	10,043
Other income (deductions)	11,288			1,919			(13,575		)	(368		)
Interest charges	(79,175		)	(27,393		)	(14,880		)	(121,448		)
Segment earnings (loss) before income taxes	151,480			46,711			(23,122		)	175,069
Income taxes (benefit)	48,804			17,621			(6,912		)	59,513
Segment earnings (loss)	102,676			29,090			(16,210		)	115,556
Valencia non-controlling interest	(14,521		)	—			—			(14,521		)
Subsidiary preferred stock dividends	(528		)	—			—			(528		)
Segment earnings (loss) attributable to PNMR	$	87,627		$	29,090		$	(16,210	)	$	100,507
Gross property additions	$	239,906		$	89,117		$	19,016		$	348,039
At December 31, 2013:
Total Assets	$	4,227,616		$	1,162,431		$	110,163		$	5,500,210
Goodwill	$	51,632		$	226,665		$	—		$	278,297

2012	PNM			TNMP			Corporate and Other			Consolidated
Electric operating revenues	$	1,092,264		$	250,140		$	(1	)	$	1,342,403
Cost of energy	353,649			46,201			—			399,850
Margin	738,615			203,939			(1		)	942,553
Other operating expenses	435,442			87,079			(17,862		)	504,659
Depreciation and amortization	97,291			49,340			17,542			164,173
Operating income	205,882			67,520			319			273,721
Interest income	13,243			1			(172		)	13,072
Gain on sale of First Choice	—			—			1,012			1,012
Other income (deductions)	13,290			2,739			(7,954		)	8,075
Interest charges	(76,101		)	(28,161		)	(16,583		)	(120,845		)
Segment earnings (loss) before income taxes	156,314			42,099			(23,378		)	175,035
Income taxes (benefit)	50,713			15,352			(11,155		)	54,910
Segment earnings (loss)	105,601			26,747			(12,223		)	120,125
Valencia non-controlling interest	(14,050		)	—			—			(14,050		)
Subsidiary preferred stock dividends	(528		)	—			—			(528		)
Segment earnings (loss) attributable to PNMR	$	91,023		$	26,747		$	(12,223	)	$	105,547
Gross property additions	$	196,800		$	92,973		$	19,136		$	308,909
At December 31, 2012:
Total Assets	$	4,163,907		$	1,086,229		$	122,447		$	5,372,583
Goodwill	$	51,632		$	226,665		$	—		$	278,297

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Summary of the Business and Significant Accounting Policies (Inventories/Depreciation and Amortization) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Public Utilities, Inventory [Line Items]
Inventory, Net	63,628	67,223
Coal [Member]
Public Utilities, Inventory [Line Items]
Inventory, Net	17,525	24,872
Materials and supplies [Member]
Public Utilities, Inventory [Line Items]
Inventory, Net	46,103	42,351
Public Service Company of New Mexico [Member]
Public Utilities, Inventory [Line Items]
Inventory, Net	60,859	64,520
Public Service Company of New Mexico [Member] | Coal [Member]
Public Utilities, Inventory [Line Items]
Inventory, Net	17,525	24,872
Public Service Company of New Mexico [Member] | Materials and supplies [Member]
Public Utilities, Inventory [Line Items]
Inventory, Net	43,334	39,648
Public Service Company of New Mexico [Member] | Electric plant [Member]
Public Utilities, Inventory [Line Items]
Depreciation average rates used (as a percent)	2.26%	2.27%	2.25%
Public Service Company of New Mexico [Member] | Common, intangible, and general plant [Member]
Public Utilities, Inventory [Line Items]
Depreciation average rates used (as a percent)	4.64%	4.87%	5.35%
Texas-New Mexico Power Company [Member]
Public Utilities, Inventory [Line Items]
Inventory, Net	2,769	2,703
Depreciation average rates used (as a percent)	3.59%	3.66%	3.56%
Texas-New Mexico Power Company [Member] | Coal [Member]
Public Utilities, Inventory [Line Items]
Inventory, Net	0	0
Texas-New Mexico Power Company [Member] | Materials and supplies [Member]
Public Utilities, Inventory [Line Items]
Inventory, Net	2,769	2,703

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Stock-Based Compensation Plans

12 Months Ended

Dec. 31, 2014

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Stock-Based Compensation Plans

Stock-Based Compensation Plans

PNMR has various stock-based compensation programs, including stock options, restricted stock, and performance shares granted under the Performance Equity Plan (“PEP”). Although certain PNM and TNMP employees participate in the PNMR plans, PNM and TNMP do not have separate employee stock-based compensation plans. In 2011, the Company changed its approach to awarding stock-based compensation. As a result, no stock options have been granted since 2010 and awards of restricted stock have increased. Certain restricted stock awards are subject to achieving performance or market targets and some of these awards also have time vesting requirements. Other awards of restricted stock are only subject to time vesting requirements.

Performance Equity Plan

The PEP provides for the granting of non-qualified stock options, restricted stock rights, performance shares, performance units, and stock appreciation rights to officers, key employees, and non-employee board members. Restricted stock under the PEP refers to awards of stock subject to vesting, performance, or market conditions rather than to shares with contractual post-vesting restrictions. Generally, the awards vest ratably over three years from the grant date of the award. However, 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 certain stock awards. The total number of shares of PNMR common stock subject to all awards under the PEP, as approved by PNMR’s shareholders in May 2014, may not exceed 13.5 million shares, subject to adjustment and certain share counting rules set forth in the PEP. This current share pool is charged five shares for each share subject to restricted stock or other full value award. Re-pricing of stock options is prohibited unless specific shareholder approval is obtained.

Source of Shares

The source of shares for exercised stock options and vested restricted stock is shares acquired on the open market by an independent agent, rather than newly issued shares.

Accounting for Stock Awards

The stock-based compensation expense related to 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.

In June 2014, the FASB issued Accounting Standards Update 2014-12 – Compensation – Stock Compensation (Topic 718) Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period, which requires that a performance target that affects vesting and that could be achieved after the requisite service period be treated as a performance condition and should not be reflected in estimating the grant date fair value of the award. The FASB issued ASU 2012-12 to eliminate diversity in practice. The Company currently treats the performance targets covered by the standard as performance conditions, so this ASU has no impact on the Company.

Total compensation expense for stock-based payment arrangements recognized by PNMR for the years ended December 31, 2014, 2013, and 2012 was $5.9 million, $5.3 million, and $3.6 million. Stock compensation expense of $4.2 million, $3.8 million, and $2.7 million was charged to PNM and $1.7 million, $1.5 million, and $1.0 million was charged to TNMP.

PNMR receives a tax deduction for certain stock option exercises during the period the options are exercised, generally for the excess of the price at which the options are sold over the exercise prices of the options, and a tax deduction for the value of restricted stock at the vesting date.

At December 31, 2014, PNMR had unrecognized compensation expense of $4.7 million related to restricted stock and performance-based shares and $1.8 million related to market-based shares, which are expected to be recognized over an average of 1.8 years.

The grant date fair value for restricted stock and stock awards with Company internal performance targets is determined based on the market price of PNMR common stock on the date of the agreements reduced by the present value of future dividends, which will not be received prior to vesting, applied to the total number of shares that are anticipated to vest, although the number of performance shares that ultimately vest cannot be determined until after the performance periods end. The grant date fair value of stock awards with market targets is determined using Monte Carlo simulation models, which provide grant date fair values that include an expectation of the number of shares to vest at the end of the measurement period.

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

	Year Ended December 31,
Restricted Shares and Performance-Based Shares	2014			2013			2012
Expected quarterly dividends per share	$	0.185		$	0.165		$	0.145
Risk-free interest rate	0.62		%	0.34		%	1.22		%
Market-Based Shares
Dividend yield	2.82		%	2.86		%	3.45		%
Expected volatility	25.11		%	25.11		%	43.98		%
Risk-free interest rate	0.64		%	0.36		%	1.04		%

The following table summarizes activity in restricted stock awards, including performance-based and market-based shares, and stock options:

	Restricted Stock				Stock Options
	Shares		Weighted-Average Grant Date Fair Value		Shares		Weighted Average Exercise Price
Outstanding at December 31, 2013	315,305		$	17.87	1,343,666		$	20.63
Granted	242,164		$	21.27	—		$	—
Exercised	(295,423	)	$	16.70	(345,426	)	$	20.04
Forfeited	(3,276	)	$	22.46	(17,151	)	$	26.43
Expired	—		—		(60,584	)	$	27.98
Outstanding at December 31, 2014	258,770		$	22.31	920,505		$	20.39

Included as restricted stock granted and exercised 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 2011 through 2013 performance period.

As of December 31, 2014, PNMR’s stock-based compensation program provides for performance and market targets through 2016. Excluded from the above table are 179,845 shares approved by the Board in February 2015 (based upon achieving market targets, weighted at 60%, at target levels and performance targets, weighted at 40%, at maximum levels for the 2012 through 2014 performance period), as well as maximums of 179,811 and 163,152 shares for the three-year performance periods ending in 2015 and 2016 that would be awarded if all performance and market criteria are achieved at maximum levels and all executives remain eligible.

In March 2012, the Company entered into a retention award agreement with its Chairman, President, and Chief Executive Officer under which she would receive 135,000 shares of PNMR’s common stock if PNMR meets specific market targets at the end of 2016 and she remains an employee of the Company. Under the agreement, she would receive 35,000 of the total shares if PNMR achieved specific market targets at the end of 2014. The specified market target was achieved at the end of 2014 and the Board approved her receiving the 35,000 shares in February 2015. 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 this retention award agreement.

Effective as of January 1, 2015, the Company entered into a retention award agreement with its Executive Vice President and Chief Financial Officer under which he would receive awards of restricted stock if PNMR meets specific performance targets at the end of 2016 and 2017 and he remains an employee of the Company. If PNMR achieves the specific performance target for the period from January 1, 2015 through December 31, 2016, he would receive $100,000 of PNMR common stock based on the market value per share on the grant date in early 2017. Similarly, if PNMR achieves the specific performance target for the period from January 1, 2015 through December 31, 2017, he would receive $275,000 of PNMR common stock based on the market value per share on the grant date in early 2018. If the target for the first performance period is not met, but the target for the second performance period is met, he would receive both awards, less any amount received previously under the agreement. The retention award was made under the PEP and was approved by the Board on December 9, 2014. The above table does not include any restricted stock shares under this retention award agreement.

At December 31, 2014, the aggregate intrinsic value of stock options outstanding, all of which are exercisable, was $8.9 million with a weighted-average remaining contract life of 2.83 years. At December 31, 2014, the exercise price of 254,050 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:

	Year Ended December 31,
Restricted Stock	2014		2013		2012
Weighted-average grant date fair value	$	21.27	$	20.03	$	16.75
Total fair value of restricted shares that vested (in thousands)	$	4,933	$	4,395	$	5,099
Stock Options
Weighted-average grant date fair value of options granted	$	—	$	—	$	—
Total fair value of options that vested (in thousands)	$	—	$	625	$	1,054
Total intrinsic value of options exercised (in thousands)	$	2,473	$	2,721	$	6,356

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Related Party Transactions

12 Months Ended

Dec. 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. These services are billed at cost on a monthly basis to the business units.

PNMR files a consolidated federal income tax return with its affiliated companies. A tax allocation agreement exists between PNMR and each of its affiliated companies. These agreements provide that the subsidiary company will compute its taxable income on a stand-alone basis. If the result is a net tax liability, such amount shall be paid to PNMR. If there are net operating losses and/or tax credits, the subsidiary shall receive payment for the tax savings from PNMR to the extent that PNMR is able to utilize those benefits.

See Note 6 for information on intercompany borrowing arrangements. The table below summarizes the nature and amount of related party transactions of PNMR, PNM and TNMP:    

	Year Ended December 31,
	2014		2013		2012
			(In thousands)
Services billings:
PNMR to PNM	$	86,871	$	92,597	$	99,986
PNMR to TNMP	28,349		28,937		29,110
PNM to TNMP	524		562		595
TNMP to PNMR	31		7		15
Income tax sharing payments:
PNMR to TNMP	—		—		1,951
PNMR to PNM	—		77,433		63,114
TNMP to PNMR	—		3,643		—
Interest payments:
PNM to PNMR	65		4		1
TNMP to PNMR	309		481		137

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Asset Retirement Obligations (Details) (USD $)	12 Months Ended
	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Liability Beginning Balance	$ 96,135,000		$ 85,893,000		$ 79,233,000
Liabilities incurred	0		0		0
Liabilities settled	0		(79,000)		(25,000)
Accretion expense	7,984,000		7,245,000		6,685,000
Revisions to estimated cash flows	51,000	[1]	3,076,000	[1]
Liability Ending Balance	104,170,000		96,135,000		85,893,000
Public Service Company of New Mexico [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Liability Beginning Balance	95,225,000		85,042,000		78,425,000
Liabilities incurred	0		0		0
Liabilities settled	0		(67,000)		0
Accretion expense	7,906,000		7,174,000		6,617,000
Revisions to estimated cash flows	51,000	[1]	3,076,000	[1]
Liability Ending Balance	103,182,000		95,225,000		85,042,000
Public Service Company of New Mexico [Member] | Palo Verde Nuclear Generating Station [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset Retirement Obligation, Period Increase (Decrease)	500,000
Public Service Company of New Mexico [Member] | San Juan Generating Station [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset Retirement Obligation, Period Increase (Decrease)	2,500,000
Texas-New Mexico Power Company [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Liability Beginning Balance	782,000		732,000		699,000
Liabilities incurred	0		0		0
Liabilities settled	0		(12,000)		(25,000)
Accretion expense	66,000		62,000		58,000
Revisions to estimated cash flows	0	[1]	0	[1]
Liability Ending Balance	$ 848,000		$ 782,000		$ 732,000

[1] Based on studies to estimate the amount and timing of future ARO expenditures. PNM has an ARO for PVNGS that includes the obligations for nuclear decommissioning of that facility. In 2013, a new decommissioning study for PVNGS was implemented reflecting updated cash flow estimates, including the extended operating licenses. The new study resulted in an increase of $0.5 million to the ARO. In addition, a new decommissioning study for SJGS was implemented in 2013, resulting in a $2.5 million increase to the ARO.

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Schedule I - Condensed Financial Information of Parent Company (Tables)

12 Months Ended

Dec. 31, 2014

Condensed Financial Information of Parent Company Only Disclosure [Abstract]

Condensed Income Statement

	Year ended December 31,
	2014			2013			2012
	(In thousands)
Operating Revenues	$	—		$	—		$	—
Operating Expenses	650			941			3,287
Operating income (loss)	(650		)	(941		)	(3,287		)
Other Income and Deductions:
Equity in earnings of subsidiaries	124,543			116,634			117,900
Other income	622			769			670
Other deductions	(13,650		)	(22,825		)	(20,904		)
Net other income (deductions)	111,515			94,578			97,666
Earnings Before Income Taxes	110,865			93,637			94,379
Income Tax Expense (Benefit)	(5,389		)	(6,870		)	(11,168		)
Net Earnings	$	116,254		$	100,507		$	105,547

Condensed Cash Flow Statement

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Cash Flows From Operating Activities:
Net earnings	$	116,254		$	100,507		$	105,547
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	680			4,192			5,000
Deferred income tax expense	(69,442		)	(51,820		)	(46,632		)
Equity in (earnings) of subsidiaries	(124,543		)	(116,634		)	(117,900		)
Loss on reacquired debt	—			3,253			—
Stock based compensation expense	5,931			5,320			3,585
Changes in certain assets and liabilities:
Other current assets	22,955			28,460			(43,638		)
Other assets	51,644			46,558			34,096
Accounts payable	(88		)	620			8
Accrued interest and taxes	(7,683		)	(9,266		)	(28,855		)
Other current liabilities	(1,668		)	(146		)	3,876
Other liabilities	28,704			(27,756		)	(29,601		)
Net cash flows from operating activities	22,744			(16,712		)	(114,514		)
Cash Flows From Investing Activities:
Utility plant additions	(474		)	(960		)	(7,524		)
Investments in subsidiaries	—			(13,800		)	—
Cash dividends from subsidiaries	46,599			158,772			61,406
Net cash flows from investing activities	46,125			144,012			53,882
Cash Flows From Financing Activities:
Short-term borrowings (repayments), net	600			(37,600		)	120,900
Repayment of long-term debt	—			(29,468		)	(2,387		)
Proceeds from stock option exercise	6,999			4,618			11,684
Purchases to satisfy awards of common stock	(17,319		)	(13,807		)	(25,168		)
Dividends paid	(58,940		)	(50,980		)	(44,609		)
Other, net	81			—			—
Net cash flows from financing activities	(68,579		)	(127,237		)	60,420
Change in Cash and Cash Equivalents	290			63			(212		)
Cash and Cash Equivalents at Beginning of Period	92			29			241
Cash and Cash Equivalents at End of Period	$	382		$	92		$	29
Supplemental Cash Flow Disclosures:
Interest paid	$	12,152		$	14,510		$	15,007
Income taxes paid (refunded), net	$	(2,014	)	$	22,378		$	1,501

Condensed Balance Sheet

	December 31,
	2014			2013
	(In thousands)
Assets
Cash and cash equivalents	$	382		$	92
Intercompany receivables	107,619			136,387
Income taxes receivable	29			14,989
Other, net	8,115			8,544
Total current assets	116,145			160,012
Property, plant and equipment, net of accumulated depreciation of $10,251 and $9,167	27,076			26,601
Investment in subsidiaries	1,757,650			1,683,321
Other long-term assets	70,939			53,892
Total long-term assets	1,855,665			1,763,814
	$	1,971,810		$	1,923,826
Liabilities and Stockholders’ Equity
Short-term debt	$	100,600		$	100,000
Short-term debt-affiliate	8,819			8,819
Current maturities of long-term debt	118,766			—
Accrued interest and taxes	2,816			2,797
Other current liabilities	16,320			16,876
Total current liabilities	247,321			128,492
Long-term debt	—			118,766
Other long-term liabilities	2,943			2,999
Total liabilities	250,264			250,257
Common stock (no par value; 120,000,000 shares authorized; issued and outstanding 79,653,624 shares)	1,173,845			1,178,369
Accumulated other comprehensive income (loss), net of tax	(61,755		)	(58,140		)
Retained earnings	609,456			553,340
Total common stockholders’ equity	1,721,546			1,673,569
	$	1,971,810		$	1,923,826

See Notes 6, 7, 14, and 16 for information regarding commitments, contingencies, and maturities of long-term debt.

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Schedule I - Condensed Financial Information of Parent Company (Parenthetical) (Details) (USD $) In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Condensed Financial Statements, Captions [Line Items]
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
PNM Resources [Member]
Condensed Financial Statements, Captions [Line Items]
Accumulated Depreciation	$ 10,251	$ 9,167
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

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Income Taxes (Tables)

12 Months Ended

Dec. 31, 2014

Income Taxes [Line Items]

Schedule of Components of Income Tax Expense (Benefit)

PNMR’s income taxes consist of the following components:

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Current federal income tax	$	(2,015	)	$	—		$	(1,296	)
Current state income tax	(728		)	(917		)	(37		)
Deferred federal income tax	59,814			50,044			51,559
Deferred state income tax	14,831			12,578			6,921
Amortization of accumulated investment tax credits	(2,164		)	(2,192		)	(2,237		)
Total income taxes	$	69,738		$	59,513		$	54,910

Schedule of Effective Income Tax Rate Reconciliation

PNMR’s provision for income taxes differed from the federal income tax computed at the statutory rate for each of the years shown. The differences are attributable to the following factors:

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Federal income tax at statutory rates	$	70,226		$	61,274		$	61,262
Amortization of accumulated investment tax credits	(2,164		)	(2,192		)	(2,237		)
Flow-through of depreciation items	1,344			1,132			1,284
Earnings attributable to non-controlling interest in Valencia	(4,945		)	(5,082		)	(4,918		)
State income tax, net of federal benefit	5,723			3,818			4,646
Impairment of state net operating loss carryforwards	3,129			—			—
Impairment of state production tax credits, net of federal benefit	894			3,880			718
Other	(4,469		)	(3,317		)	(5,845		)
Total income taxes	$	69,738		$	59,513		$	54,910
Effective tax rate	34.76		%	33.99		%	31.37		%

Schedule of Deferred Tax Assets and Liabilities

The components of PNMR’s net accumulated deferred income tax liability were:

	December 31,
	2014			2013
	(In thousands)
Deferred tax assets:
Net operating loss	$	153,858		$	134,418
Regulatory liabilities related to income taxes	78,858			83,838
Federal tax credit carryforwards	54,748			40,708
Other	68,566			75,832
Total deferred tax assets	356,030			334,796
Deferred tax liabilities:
Depreciation and plant related	(914,926		)	(814,671		)
Investment tax credit	(36,790		)	(25,855		)
Regulatory assets related to income taxes	(67,910		)	(66,352		)
CTC	(19,352		)	(22,262		)
Pension	(66,498		)	(58,780		)
Other	(115,282		)	(115,458		)
Total deferred tax liabilities	(1,220,758		)	(1,103,378		)
Net accumulated deferred income tax liabilities	(864,728		)	(768,582		)
Current accumulated deferred income tax (asset) liability	(26,383		)	(58,681		)
Non-current accumulated deferred income tax liability	$	(891,111	)	$	(827,263	)

Schedule of Deferred Income Tax Components

The following table reconciles the change in PNMR’s net accumulated deferred income tax liability to the deferred income tax benefit included in the Consolidated Statement of Earnings:

	Year Ended
	December 31, 2014
	(In thousands)
Net change in deferred income tax liability per above table	$	96,146
Change in tax effects of income tax related regulatory assets and liabilities	(6,538		)
Tax effect of mark-to-market adjustments	(1,612		)
Tax effect of excess pension liability	3,993
Adjustment for uncertain income tax positions	(4,858		)
Reclassification of unrecognized tax benefits	(15,031		)
Other	381
Deferred income taxes	$	72,481

Summary of Income Tax Contingencies

A reconciliation of unrecognized tax benefits (expenses) is as follows:

	PNMR			PNM			TNMP
	(In thousands)
Balance at December 31, 2011	$	19,580		$	10,752		$	7,701
Additions based on tax positions related to 2012	2,046			1,152			—
Reductions for tax positions of prior years	(2,428		)	(1,522		)	(905		)
Settlement payments	—			—			—
Balance at December 31, 2012	19,198			10,382			6,796
Additions based on tax positions related to 2013	(54		)	(54		)	—
Additions for tax positions of prior years	745			745			—
Settlement payments	—			—			—
Balance at December 31, 2013	19,889			11,073			6,796
Additions based on tax positions related to 2014	623			623			—
Additions (reductions) for tax positions of prior years	(5,481		)	532			(6,796		)
Settlement payments	—			—			—
Balance at December 31, 2014	$	15,031		$	12,228		$	—

Interest Income (Expense) Related to Income Taxes

Interest income (expense) related to income taxes is as follows:

	PNMR		PNM		TNMP
	(In thousands)
2014	$	146	$	148	$	(2	)
2013	$	242	$	251	$	(2	)
2012	$	243	$	244	$	(3	)

Accumulated Accrued Interest Receivable (Payable) Related to Income Taxes

Accumulated accrued interest receivable (payable) related to income taxes is as follows:

	PNMR			PNM			TNMP
	(In thousands)
December 31, 2014:
Accumulated accrued interest receivable	$	3,569		$	3,569		$	—
Accumulated accrued interest payable	$	(1,120	)	$	(24	)	$	(120	)
December 31, 2013:
Accumulated accrued interest receivable	$	4,048		$	4,048		$	—
Accumulated accrued interest payable	$	(1,118	)	$	(24	)	$	(118	)

Public Service Company of New Mexico [Member]

Income Taxes [Line Items]

Schedule of Components of Income Tax Expense (Benefit)

PNM’s income taxes consist of the following components:

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Current federal income tax	$	(2,175	)	$	(479	)	$	(12,951	)
Current state income tax	(979		)	(760		)	(1,815		)
Deferred federal income tax	45,890			42,806			56,194
Deferred state income tax	12,061			9,429			11,522
Amortization of accumulated investment tax credits	(2,164		)	(2,192		)	(2,237		)
Total income taxes	$	52,633		$	48,804		$	50,713

Schedule of Effective Income Tax Rate Reconciliation

The differences are attributable to the following factors:

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Federal income tax at statutory rates	$	53,930		$	53,018		$	54,710
Amortization of accumulated investment tax credits	(2,164		)	(2,192		)	(2,237		)
Flow-through of depreciation items	1,325			1,115			1,268
Earnings attributable to non-controlling interest in Valencia	(4,945		)	(5,082		)	(4,918		)
State income tax, net of federal benefit	5,522			6,202			6,500
Impairment of state net operating loss carryforwards	2,145			—			—
Other	(3,180		)	(4,257		)	(4,610		)
Total income taxes	$	52,633		$	48,804		$	50,713
Effective tax rate	34.16		%	32.22		%	32.44		%

Schedule of Deferred Tax Assets and Liabilities

The components of PNM’s net accumulated deferred income tax liability were:

	December 31,
	2014			2013
	(In thousands)
Deferred tax assets:
Net operating loss	$	108,505		$	99,247
Regulatory liabilities related to income taxes	74,293			78,849
Federal tax credit carryforwards	35,259			22,509
Other	35,681			37,008
Total deferred tax assets	253,738			237,613
Deferred tax liabilities:
Depreciation and plant related	(733,519		)	(661,239		)
Investment tax credit	(36,790		)	(25,855		)
Regulatory assets related to income taxes	(57,637		)	(55,844		)
Pension	(58,474		)	(52,104		)
Other	(70,714		)	(75,838		)
Total deferred tax liabilities	(957,134		)	(870,880		)
Net accumulated deferred income tax liabilities	(703,396		)	(633,267		)
Current accumulated deferred income tax (asset) liability	(12,418		)	(43,827		)
Non-current accumulated deferred income tax liability	$	(715,814	)	$	(677,094	)

Schedule of Deferred Income Tax Components

The following table reconciles the change in PNM’s net accumulated deferred income tax liability to the deferred income tax benefit included in the Consolidated Statement of Earnings:

	Year Ended
	December 31, 2014
	(In thousands)
Net change in deferred income tax liability per above table	$	70,129
Change in tax effects of income tax related regulatory assets and liabilities	(6,349		)
Tax effect of mark-to-market adjustments	(1,470		)
Tax effect of excess pension liability	3,993
Adjustment for uncertain income tax positions	1,155
Reclassification of unrecognized tax benefits	(12,228		)
Other	557
Deferred income taxes	$	55,787

Texas-New Mexico Power Company [Member]

Income Taxes [Line Items]

Schedule of Components of Income Tax Expense (Benefit)

TNMP’s income taxes consist of the following components:

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Current federal income tax	$	35		$	(4,957	)	$	9,152
Current state income tax	1,939			1,916			1,822
Deferred federal income tax	20,577			20,688			4,406
Deferred state income tax	(28		)	(26		)	(28		)
Total income taxes	$	22,523		$	17,621		$	15,352

Schedule of Effective Income Tax Rate Reconciliation

The differences are attributable to the following factors:

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Federal income tax at statutory rates	$	21,115		$	16,349		$	14,735
State income tax, net of federal benefit	1,257			1,247			1,185
Other	151			25			(568		)
Total income taxes	$	22,523		$	17,621		$	15,352
Effective tax rate	37.33		%	37.72		%	36.47		%

Schedule of Deferred Tax Assets and Liabilities

The components of TNMP’s net accumulated deferred income tax liability at December 31, were:

	December 31,
	2014			2013
	(In thousands)
Deferred tax assets:
Regulatory liabilities related to income taxes	$	4,565		$	4,988
Other	13,429			23,479
Total deferred tax assets	17,994			28,467
Deferred tax liabilities:
Depreciation and plant related	(174,510		)	(151,581		)
CTC	(19,352		)	(22,262		)
Regulatory assets related to income taxes	(10,197		)	(10,509		)
Loss on reacquired debt	(12,846		)	(13,516		)
Other	(12,636		)	(14,295		)
Total deferred tax liabilities	(229,541		)	(212,163		)
Net accumulated deferred income tax liabilities	(211,547		)	(183,696		)
Current accumulated deferred income tax (asset)	(6,398		)	(6,501		)
Non-current accumulated deferred income tax liability	$	(217,945	)	$	(190,197	)

Schedule of Deferred Income Tax Components

The following table reconciles the change in TNMP’s net accumulated deferred income tax liability to the deferred income tax benefit included in the Consolidated Statement of Earnings:

	Year Ended
	December 31, 2014
	(In thousands)
Net change in deferred income tax liability per above table	$	27,851
Change in tax effects of income tax related regulatory assets and liabilities	(111		)
Adjustment for uncertain tax positions	(6,796		)
Other	(395		)
Deferred income taxes	$	20,549

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Consolidated Statements of Cash Flows (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Cash Flows From Operating Activities:
Net Earnings	$ 130,909	$ 115,556	$ 120,125
Net earnings	116,254	100,507	105,547
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	209,867	208,173	206,499
Deferred income tax expense	72,481	60,430	56,243
(Gain) on sale of First Choice	0	0	(1,012)
Net unrealized (gains) on derivatives	(6,504)	(1,866)	(1,598)
Realized (gains) on available-for-sale securities	(10,527)	(10,612)	(12,965)
Loss on reacquired debt	0	3,253	0
Abandonment of leased premises	0	0	7,411
Stock based compensation expense	5,931	5,320	3,585
Regulatory disallowances	1,062	12,235	0
Other, net	(1,518)	(1,647)	(798)
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	(4,975)	(7,562)	(2,547)
Materials, supplies, and fuel stock	5,504	(7,580)	(5,412)
Other current assets	(30,436)	8,577	(2,598)
Other assets	290	(12,801)	(30,778)
Accounts payable	(2,311)	4,484	14,020
Accrued interest and taxes	2,040	91,537	255
Other current liabilities	(2,453)	(19,648)	(19,905)
Proceeds from governmental grants	0	0	21,567
Other liabilities	45,516	(61,262)	(70,743)
Net cash flows from operating activities	414,876	386,587	281,349
Cash Flows From Investing Activities:
Additions to utility and non-utility plant	(460,658)	(348,039)	(308,909)
Proceeds from sales of available-for-sale securities	117,989	271,140	167,330
Purchases of available-for-sale securities	(127,016)	(282,000)	(176,748)
Proceeds from sale of First Choice	0	0	(4,034)
Return of principal on PVNGS lessor notes	20,758	23,357	23,455
Purchase of Rio Bravo	(36,235)	0	0
Other, net	(167)	4,096	4,943
Net cash flows from investing activities	(485,329)	(331,446)	(285,895)
Cash Flows From Financing Activities:
Short-term loan			100,000
Revolving credit facilities borrowings (repayments), net	(43,600)	(9,500)	(24,000)
Long-term borrowings	355,000	75,000	20,000
Repayment of long-term debt	(125,000)	(29,468)	(22,387)
Cash paid in debt exchange		(13,048)
Proceeds from stock option exercise	6,999	4,618	11,684
Purchase of common stock	(17,319)	(13,807)	(25,168)
Dividends paid	(59,468)	(51,508)	(45,137)
Valencia’s transactions with its owner	(17,610)	(18,335)	(15,630)
Other, net	(2,808)	(5,545)	(922)
Net cash flows from financing activities	96,194	(61,593)	(1,560)
Change in Cash and Cash Equivalents	25,741	(6,452)	(6,106)
Cash and Cash Equivalents at Beginning of Year	2,533	8,985	15,091
Cash and Cash Equivalents at End of Year	28,274	2,533	8,985
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	108,741	110,768	113,265
Income taxes paid (refunded), net	(2,597)	(95,327)	5,302
Supplemental schedule of noncash investing and financing activities:
Changes in accrued plant additions	3,089	6,006	(17,983)
Premium on long-term debt incurred in connection with debt exchange		36,297
Public Service Company of New Mexico [Member]
Cash Flows From Operating Activities:
Net Earnings	101,453	102,676	105,601
Net earnings	87,326	88,155	91,551
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	143,303	136,732	129,514
Deferred income tax expense	55,787	50,043	65,479
Net unrealized (gains) on derivatives	(6,504)	(1,866)	(1,598)
Realized (gains) on available-for-sale securities	(10,527)	(10,612)	(12,965)
Regulatory disallowances	1,062	12,235	0
Other, net	(1,391)	(1,614)	(170)
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	(5,919)	(3,021)	(4,756)
Materials, supplies, and fuel stock	5,570	(7,730)	(5,268)
Other current assets	(29,146)	8,556	(3,014)
Other assets	7,150	(13,363)	(27,338)
Accounts payable	212	2,807	11,028
Accrued interest and taxes	(3,599)	72,740	47,666
Other current liabilities	(659)	(27,376)	(2,539)
Proceeds from governmental grants	0	0	21,567
Other liabilities	42,325	(59,753)	(54,787)
Net cash flows from operating activities	299,117	260,454	268,420
Cash Flows From Investing Activities:
Additions to utility and non-utility plant	(316,800)	(239,906)	(196,800)
Proceeds from sales of available-for-sale securities	117,989	271,140	167,330
Purchases of available-for-sale securities	(127,016)	(282,000)	(176,748)
Return of principal on PVNGS lessor notes	20,758	23,357	23,455
Purchase of Rio Bravo	(36,235)	0	0
Other, net	(363)	3,843	2,406
Net cash flows from investing activities	(341,667)	(223,566)	(180,357)
Cash Flows From Financing Activities:
Revolving credit facilities borrowings (repayments), net	(49,200)	28,100	(44,900)
Short-term borrowings (repayments) - affiliate, net	(32,500)	32,500	0
Long-term borrowings	275,000	75,000	20,000
Repayment of long-term debt	(75,000)	0	(20,000)
Dividends paid	(30,791)	(155,556)	(34,961)
Valencia’s transactions with its owner	(17,610)	(18,335)	(15,630)
Other, net	(1,890)	(2,534)	(921)
Net cash flows from financing activities	68,009	(40,825)	(96,412)
Change in Cash and Cash Equivalents	25,459	(3,937)	(8,349)
Cash and Cash Equivalents at Beginning of Year	21	3,958	12,307
Cash and Cash Equivalents at End of Year	25,480	21	3,958
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	73,787	71,306	73,036
Income taxes paid (refunded), net	(228)	(77,434)	(63,113)
Supplemental schedule of noncash investing and financing activities:
Changes in accrued plant additions	1,616	7,921	(19,732)
Texas-New Mexico Power Company [Member]
Cash Flows From Operating Activities:
Net Earnings	37,807	29,090	26,747
Net earnings	37,807	29,090	26,747
Adjustments to reconcile net earnings to net cash flows from operating activities:
Depreciation and amortization	52,847	54,395	54,396
Deferred income tax expense	20,549	20,662	4,378
Other, net	(10)	(30)	(889)
Changes in certain assets and liabilities:
Accounts receivable and unbilled revenues	944	(4,542)	2,208
Materials, supplies, and fuel stock	(66)	150	(143)
Other current assets	380	(1,137)	(3,515)
Other assets	(6,607)	941	(3,145)
Accounts payable	2,514	3,709	(666)
Accrued interest and taxes	4,796	(6,713)	9,825
Other current liabilities	(203)	(3,197)	(2,106)
Other liabilities	3,112	460	4,311
Net cash flows from operating activities	116,063	93,788	91,401
Cash Flows From Investing Activities:
Additions to utility and non-utility plant	(127,191)	(89,117)	(92,973)
Net cash flows from investing activities	(127,191)	(89,117)	(92,973)
Cash Flows From Financing Activities:
Revolving credit facilities borrowings (repayments), net	5,000	0	0
Short-term borrowings (repayments) - affiliate, net	(6,700)	1,100	27,600
Long-term borrowings	80,000	0	0
Repayment of long-term debt	(50,000)	0	0
Cash paid in debt exchange	0	(13,048)	0
Equity contribution from parent	0	13,800	0
Dividends paid	(16,336)	(3,726)	(26,028)
Other, net	(836)	(2,797)	0
Net cash flows from financing activities	11,128	(4,671)	1,572
Change in Cash and Cash Equivalents	0	0	0
Cash and Cash Equivalents at Beginning of Year	1	1	1
Cash and Cash Equivalents at End of Year	1	1	1
Supplemental Cash Flow Disclosures:
Interest paid, net of amounts capitalized	22,803	25,436	25,360
Income taxes paid (refunded), net	(355)	4,484	1,848
Supplemental schedule of noncash investing and financing activities:
Changes in accrued plant additions	(854)	141	(2,749)
Premium on long-term debt incurred in connection with debt exchange		$ 36,297

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Pension and Other Postretirement Benefits Assumed Health Care Cost Trend Rates and Impact of a One-Percentage-Point Change in Assumed Health Care Cost Trend Rates (Details) (Public Service Company of New Mexico [Member], Other Postretirement Benefits [Member], USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Public Service Company of New Mexico [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan, Assumed Health Care Cost Trend Rates [Abstract]
Health care cost trend rate assumed for next year (as a percent)	7.00%	7.50%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) (as a percent)	5.00%	5.00%
Year that the rate reaches the ultimate trend rate	2023	2019
Defined Benefit Plan, Effect of One-Percentage Point Change in Assumed Health Care Cost Trend Rates [Abstract]
Defined Benefit Plan, Effect of One Percentage Point Increase on Service and Interest Cost Components	$ 350
Defined Benefit Plan, Effect of One Percentage Point Decrease on Service and Interest Cost Components	(281)
Defined Benefit Plan, Effect of One Percentage Point Increase on Accumulated Postretirement Benefit Obligation	5,305
Defined Benefit Plan, Effect of One Percentage Point Decrease on Accumulated Postretirement Benefit Obligation	$ (4,622)

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Segment Information

12 Months Ended

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

TNMP

TNMP is an electric utility providing 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

2014	PNM			TNMP			Corporate and Other			Consolidated
	(In thousands)
Electric operating revenues	$	1,147,914		$	287,939		$	—		$	1,435,853
Cost of energy	403,626			67,930			—			471,556
Margin	744,288			220,009			—			964,297
Other operating expenses	422,051			84,365			(14,450		)	491,966
Depreciation and amortization	109,524			50,056			13,054			172,634
Operating income	212,713			85,588			1,396			299,697
Interest income	8,557			—			(74		)	8,483
Other income (deductions)	12,258			2,138			(2,302		)	12,094
Interest charges	(79,442		)	(27,396		)	(12,789		)	(119,627		)
Segment earnings (loss) before income taxes	154,086			60,330			(13,769		)	200,647
Income taxes (benefit)	52,633			22,523			(5,418		)	69,738
Segment earnings (loss)	101,453			37,807			(8,351		)	130,909
Valencia non-controlling interest	(14,127		)	—			—			(14,127		)
Subsidiary preferred stock dividends	(528		)	—			—			(528		)
Segment earnings (loss) attributable to PNMR	$	86,798		$	37,807		$	(8,351	)	$	116,254
Gross property additions	$	316,800		$	127,191		$	16,667		$	460,658
At December 31, 2014:
Total Assets	$	4,473,652		$	1,240,241		$	115,432		$	5,829,325
Goodwill	$	51,632		$	226,665		$	—		$	278,297

2013	PNM			TNMP			Corporate and Other			Consolidated
Electric operating revenues	$	1,116,312		$	271,611		$	—		$	1,387,923
Cost of energy	374,710			57,606			—			432,316
Margin	741,602			214,005			—			955,607
Other operating expenses	428,591			91,601			(18,308		)	501,884
Depreciation and amortization	103,826			50,219			12,836			166,881
Operating income	209,185			72,185			5,472			286,842
Interest income	10,182			—			(139		)	10,043
Other income (deductions)	11,288			1,919			(13,575		)	(368		)
Interest charges	(79,175		)	(27,393		)	(14,880		)	(121,448		)
Segment earnings (loss) before income taxes	151,480			46,711			(23,122		)	175,069
Income taxes (benefit)	48,804			17,621			(6,912		)	59,513
Segment earnings (loss)	102,676			29,090			(16,210		)	115,556
Valencia non-controlling interest	(14,521		)	—			—			(14,521		)
Subsidiary preferred stock dividends	(528		)	—			—			(528		)
Segment earnings (loss) attributable to PNMR	$	87,627		$	29,090		$	(16,210	)	$	100,507
Gross property additions	$	239,906		$	89,117		$	19,016		$	348,039
At December 31, 2013:
Total Assets	$	4,227,616		$	1,162,431		$	110,163		$	5,500,210
Goodwill	$	51,632		$	226,665		$	—		$	278,297

2012	PNM			TNMP			Corporate and Other			Consolidated
Electric operating revenues	$	1,092,264		$	250,140		$	(1	)	$	1,342,403
Cost of energy	353,649			46,201			—			399,850
Margin	738,615			203,939			(1		)	942,553
Other operating expenses	435,442			87,079			(17,862		)	504,659
Depreciation and amortization	97,291			49,340			17,542			164,173
Operating income	205,882			67,520			319			273,721
Interest income	13,243			1			(172		)	13,072
Gain on sale of First Choice	—			—			1,012			1,012
Other income (deductions)	13,290			2,739			(7,954		)	8,075
Interest charges	(76,101		)	(28,161		)	(16,583		)	(120,845		)
Segment earnings (loss) before income taxes	156,314			42,099			(23,378		)	175,035
Income taxes (benefit)	50,713			15,352			(11,155		)	54,910
Segment earnings (loss)	105,601			26,747			(12,223		)	120,125
Valencia non-controlling interest	(14,050		)	—			—			(14,050		)
Subsidiary preferred stock dividends	(528		)	—			—			(528		)
Segment earnings (loss) attributable to PNMR	$	91,023		$	26,747		$	(12,223	)	$	105,547
Gross property additions	$	196,800		$	92,973		$	19,136		$	308,909
At December 31, 2012:
Total Assets	$	4,163,907		$	1,086,229		$	122,447		$	5,372,583
Goodwill	$	51,632		$	226,665		$	—		$	278,297

Major Customers

No individual customer accounted for more than 10% of the electric operating revenues of PNMR or PNM. The acquiror of First Choice, including the former First Choice operations, accounted for 15% and 17% of TNMP’s electric operating revenues in 2014 and 2013. Two other unaffiliated customers of TNMP accounted for revenues of 15% in 2014, 16% in 2013, and 17% in 2012 and 11% in 2014, 10% in 2013, and 10% in 2012.

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Financing Short-term Debt (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Feb. 20, 2015	Apr. 30, 2009
Short-term Debt [Line Items]
Line of Credit Facility, Extension Option, Years	1 year
Debt, Weighted Average Interest Rate	6.60%	6.90%	6.60%
Short-term debt	$ 105,600,000	$ 149,200,000
Letters of Credit Outstanding, Amount	7,700,000
Public Service Company of New Mexico [Member]
Short-term Debt [Line Items]
Letters of Credit Outstanding, Amount	3,200,000
Public Service Company of New Mexico [Member] | PNM 2014 Multi-Draw Term Loan Agreement [Member]
Short-term Debt [Line Items]
Debt Instrument, Unused Borrowing Capacity, Amount	25,000,000
Texas-New Mexico Power Company [Member]
Short-term Debt [Line Items]
Letters of Credit Outstanding, Amount	100,000
New Mexico Revolving Credit Facility [Member] | Public Service Company of New Mexico [Member]
Short-term Debt [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	50,000,000
PNMR Term Loan Agreement [Member]
Short-term Debt [Line Items]
Debt, Weighted Average Interest Rate	1.02%
Short-term debt	100,000,000	100,000,000
Subsequent Event [Member]
Short-term Debt [Line Items]
Line of Credit Facility, Remaining Borrowing Capacity				291,500,000
Invested Cash and Cash Equivalents				1,900,000
Subsequent Event [Member] | Public Service Company of New Mexico [Member]
Short-term Debt [Line Items]
Line of Credit Facility, Remaining Borrowing Capacity				386,800,000
Invested Cash and Cash Equivalents				42,500,000
Subsequent Event [Member] | Public Service Company of New Mexico [Member] | PNM 2014 Multi-Draw Term Loan Agreement [Member]
Short-term Debt [Line Items]
Debt Instrument, Unused Borrowing Capacity, Amount				25,000,000
Subsequent Event [Member] | Texas-New Mexico Power Company [Member]
Short-term Debt [Line Items]
Line of Credit Facility, Remaining Borrowing Capacity				54,900,000
Invested Cash and Cash Equivalents				0
Available Borrowing Capacity [Member]
Short-term Debt [Line Items]
Line of Credit Facility, Remaining Borrowing Capacity				768,200,000
PNMR Revolving Credit Facility [Member]
Short-term Debt [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	300,000,000
Debt, Weighted Average Interest Rate	1.67%
Short-term debt	600,000	0
PNM Revolving Credit Facility [Member] | Public Service Company of New Mexico [Member]
Short-term Debt [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	400,000,000
Short-term debt	0	49,200,000
TNMP Revolving Credit Facility [Member]
Short-term Debt [Line Items]
Debt, Weighted Average Interest Rate	1.17%
TNMP Revolving Credit Facility [Member] | Texas-New Mexico Power Company [Member]
Short-term Debt [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	75,000,000
Short-term debt	5,000,000	0
TNMP Revolving Credit Facility [Member] | First Mortgage Bonds Due 2014, Series 2009A, at 9 point 50 percent [Member] | Texas-New Mexico Power Company [Member]
Short-term Debt [Line Items]
Securities Received as Collateral					75,000,000
Revolving Credit Facility [Member]
Short-term Debt [Line Items]
Ratio of debt to capital, maximum (as a percent)	65.00%
New Mexico Revolving Credit Facility [Member] | Public Service Company of New Mexico [Member]
Short-term Debt [Line Items]
Short-term debt	0	0
New Mexico Revolving Credit Facility [Member] | Subsequent Event [Member] | Public Service Company of New Mexico [Member]
Short-term Debt [Line Items]
Line of Credit Facility, Remaining Borrowing Capacity				$ 35,000,000

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Pension and Other Postretirement Benefits Narrative (Details) (USD $)	12 Months Ended			1 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Jan. 31, 2015
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Expected return on plan assets	4.00%
Defined Benefit Plans, Gains and losses that lie outside the corridor, amortized (in years)	5 years
Defined Contribution Plan, Maximum Annual Contributions Per Employee, Percent	75.00%
Defined Contribution Plan, Employer Matching Contribution, Percent of Employees' Gross Pay	6.00%
Pension Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Expected long-term return resulting from effect of one-percentage point decrease (as a percent)	1.00%
Expected long-term return resulting from effect of one-percentage point increase (as a percent)	1.00%
Other Postretirement Benefits [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Expected long-term return resulting from effect of one-percentage point decrease (as a percent)	1.00%
Public Service Company of New Mexico [Member] | Pension Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Expected return on plan assets	7.20%	7.65%	8.25%
Defined Benefit Plan, Other Changes	50,600,000	$ (60,900,000)
Defined Benefit Plan, Actuarial Gain (Loss) resulting from changes in demographics and other trends	(200,000)	(4,400,000)
Defined Benefit Plan, Actuarial Gain (Loss) resulting from changes in other assumptions and experience	200,000	100,000
Actual plan asset allocations (as a percent)	14.30%
Expected Long-term return on assets decrease resulting in increase net periodic costs In next fiscal year	5,800,000
Employer contributions	0	60,000,000
Estimated future employer contributions from 2013-2017	22,000,000
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, before Tax	(34,345,000)
Public Service Company of New Mexico [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Expected return on plan assets	8.50%	8.50%	8.50%
Defined Benefit Plan, Other Changes	6,700,000	(8,800,000)
Defined Benefit Plan, Actuarial Gain (Loss) resulting from changes in demographics and other trends	5,400,000	(4,200,000)
Actual plan asset allocations (as a percent)	10.20%
Expected Long-term return on assets decrease resulting in increase net periodic costs In next fiscal year	700,000
Employer contributions	3,532,000	3,576,000
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, before Tax	(2,800,000)
Estimated future employer contributions in next fiscal year	3,500,000
Defined Benefit Plan, Estimated Future Employer Contributions in Year Two Through Year Five	14,000,000
Texas-New Mexico Power Company [Member] | Pension Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Expected return on plan assets	7.20%	7.65%	8.25%
Defined Benefit Plan, Other Changes	5,100,000	(6,400,000)
Defined Benefit Plan, Actuarial Gain (Loss) resulting from changes in demographics and other trends	400,000	1,400,000
Defined Benefit Plan, Actuarial Gain (Loss) resulting from changes in other assumptions and experience	(1,300,000)	(100,000)
Actual plan asset allocations (as a percent)	13.50%
Expected Long-term return on assets decrease resulting in increase net periodic costs In next fiscal year	600,000
Employer contributions	0	1,000,000
Estimated future employer contributions from 2013-2017	0
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, before Tax	(4,420,000)
Texas-New Mexico Power Company [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Expected return on plan assets	6.50%	6.50%	6.50%
Defined Benefit Plan, Other Changes	1,100,000	(1,300,000)
Defined Benefit Plan, Actuarial Gain (Loss) resulting from changes in demographics and other trends	(100,000)	(200,000)
Actual plan asset allocations (as a percent)	8.90%
Expected Long-term return on assets decrease resulting in increase net periodic costs In next fiscal year	100,000
Employer contributions	343,000	342,000
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, before Tax	(1,300,000)
Effect of One-Percentage-Point Change in Assumed Health Care Cost Trend Rates, Net periodic expense and APBO	0
Estimated future employer contributions in next fiscal year	300,000
Defined Benefit Plan, Estimated Future Employer Contributions in Year Two Through Year Five	1,400,000
PNM and TNMP [Domain] | Other Postretirement Benefits [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Benefit Plan, Amounts Recognized in Other Comprehensive Income (Loss), Net Prior Service Cost (Credit), before Tax	0
Equity Securities [Member] | Pension Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations (as a percent)	21.00%
Equity Securities [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations (as a percent)	70.00%
Debt Securities [Member] | Pension Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations (as a percent)	65.00%
Debt Securities [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations (as a percent)	30.00%
Alternative Investments [Member] | Pension Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations (as a percent)	14.00%
Minimum [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Contribution Plan, non matching contribution of eligible compensation based on eligible employee's age	3.00%
Minimum [Member] | Pension Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Weighted average discount rate related to anticipated contributions (as a percent)	4.80%
Maximum [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Contribution Plan, non matching contribution of eligible compensation based on eligible employee's age	10.00%
Maximum [Member] | Pension Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Weighted average discount rate related to anticipated contributions (as a percent)	5.50%
Developed Countries Outside of United States [Member] | Equity Securities [Member] | Pension Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target plan asset allocations (as a percent)	6.00%
Revised Mortality Tables [Member] | Public Service Company of New Mexico [Member] | Pension Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Benefit Plan, Other Changes	21,900,000
Revised Mortality Tables [Member] | Public Service Company of New Mexico [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Benefit Plan, Other Changes	3,200,000
Revised Mortality Tables [Member] | Texas-New Mexico Power Company [Member] | Pension Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Benefit Plan, Other Changes	2,500,000
Revised Mortality Tables [Member] | Texas-New Mexico Power Company [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Benefit Plan, Other Changes	500,000
Revised Mortality Tables [Member] | Subsequent Event [Member] | Public Service Company of New Mexico [Member] | Pension Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Employer contributions				$ 30,000,000

XML

Schedule II - Valuation and Qualifying Accounts (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of year	$ 1,423	$ 1,751	$ 1,778
Charged to costs and expenses	3,267	2,849	3,367
Charged to other accounts	0	0	0
Write-offs and other	3,224	3,177	3,394
Balance at end of year	1,466	1,423	1,751
Public Service Company of New Mexico [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of year	1,423	1,751	1,778
Charged to costs and expenses	3,275	2,864	3,384
Charged to other accounts	0	0	0
Write-offs and other	3,232	3,192	3,411
Balance at end of year	1,466	1,423	1,751
Texas-New Mexico Power Company [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of year	0	0	0
Charged to costs and expenses	(8)	(15)	(17)
Charged to other accounts	0	0	0
Write-offs and other	(8)	(15)	(17)
Balance at end of year	$ 0	$ 0	$ 0

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Fair Value of Derivative and Other Financial Instruments, Debt Maturities (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2014
PNMR and PNM [Member]
Available-for-sale Securities, Debt Maturities, Fair Value [Abstract]
Available-for-sale debt securities, Within 1 year	$ 3,946
Available-for-sale debt securities, After 1 year through 5 years	20,275
Available-for-sale debt securities, After 5 years through 10 years	13,422
Available-for-sale debt securities, After 10 years through 15 years	10,367
Available-for-sale debt securities, After 15 years through 20 years	11,539
Available-for-sale debt securities, After 20 years	46,328
Available-for-sale debt securities	105,877
PNM Resources [Member]
Held-to-maturity Securities, Debt Maturities, Fair Value [Abstract]
Held-to-maturity debt securities, Due within 1 year	8,019
Held-to-maturity debt securities, After 1 year through 5 years	25,430
Held-to-maturity debt securities, After 5 years through 10 years	0
Held to Maturity Securities, Debt Maturities, after Ten Years Through Fifteen Years, Fair Value	0
Held to Maturity Securities, Debt Maturities, after Fifteen Years Through Twenty Years, Fair Value	0
Held to Maturity Securities, Debt Maturities, after Twenty Years, Fair Value	0
Held-to-maturity debt securities	33,449
Public Service Company of New Mexico [Member]
Held-to-maturity Securities, Debt Maturities, Fair Value [Abstract]
Held-to-maturity debt securities, Due within 1 year	8,019
Held-to-maturity debt securities, After 1 year through 5 years	24,817
Held-to-maturity debt securities, After 5 years through 10 years	0
Held to Maturity Securities, Debt Maturities, after Ten Years Through Fifteen Years, Fair Value	0
Held to Maturity Securities, Debt Maturities, after Fifteen Years Through Twenty Years, Fair Value	0
Held to Maturity Securities, Debt Maturities, after Twenty Years, Fair Value	0
Held-to-maturity debt securities	$ 32,836

XML

Accumulated Other Comprehensive Income (Loss)

12 Months Ended

Dec. 31, 2014

Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]

Accumulated Other Comprehensive Income (Loss)

Accumulated Other Comprehensive Income (Loss)

AOCI reports a measure for accumulated changes in equity that result from transactions and other economic events other than transactions with shareholders. Information regarding AOCI is as follows:

	Accumulated Other Comprehensive Income (Loss)
	Unrealized Gain on Available-for-Sale Securities			Pension Liability Adjustment			Fair Value Adjustment for Cash Flow Hedges			Total
				(In thousands)
PNMR
Balance at December 31, 2011	$	15,634		$	(82,432	)	$	(58	)	$	(66,856	)
Amounts reclassified from AOCI (pre-tax)	(37,269		)	4,611			182			(32,476		)
Income tax impact of amounts reclassified	14,755			(1,825		)	(65		)	12,865
Other OCI changes (pre-tax)	38,548			(30,084		)	(428		)	8,036
Income tax impact of other OCI changes	(15,262		)	11,910			153			(3,199		)
Net change after income taxes	772			(15,388		)	(158		)	(14,774		)
Balance at December 31, 2012	16,406			(97,820		)	(216		)	(81,630		)
Amounts reclassified from AOCI (pre-tax)	(11,956		)	6,364			207			(5,385		)
Income tax impact of amounts reclassified	4,734			(2,524		)	(73		)	2,137
Other OCI changes (pre-tax)	27,419			17,136			(279		)	44,276
Income tax impact of other OCI changes	(10,855		)	(6,781		)	98			(17,538		)
Net change after income taxes	9,342			14,195			(47		)	23,490
Balance at December 31, 2013	25,748			(83,625		)	(263		)	(58,140		)
Amounts reclassified from AOCI (pre-tax)	(13,862		)	5,152			558			(8,152		)
Income tax impact of amounts reclassified	5,461			(2,032		)	(195		)	3,234
Other OCI changes (pre-tax)	17,473			(15,282		)	(153		)	2,038
Income tax impact of other OCI changes	(6,812		)	6,024			53			(735		)
Net change after income taxes	2,260			(6,138		)	263			(3,615		)
Balance at December 31, 2014	$	28,008		$	(89,763	)	$	—		$	(61,755	)

	Accumulated Other Comprehensive Income (Loss)
	Unrealized Gain on Available-for-Sale Securities			Pension Liability Adjustment			Fair Value Adjustment for Cash Flow Hedges		Total
				(In thousands)
PNM
Balance at December 31, 2011	$	15,634		$	(82,432	)	$	—	$	(66,798	)
Amounts reclassified from AOCI (pre-tax)	(37,269		)	4,611			—		(32,658		)
Income tax impact of amounts reclassified	14,755			(1,825		)	—		12,930
Other OCI changes (pre-tax)	38,548			(30,084		)	—		8,464
Income tax impact of other OCI changes	(15,262		)	11,910			—		(3,352		)
Net change after income taxes	772			(15,388		)	—		(14,616		)
Balance at December 31, 2012	16,406			(97,820		)	—		(81,414		)
Amounts reclassified from AOCI (pre-tax)	(11,956		)	6,364			—		(5,592		)
Income tax impact of amounts reclassified	4,734			(2,524		)	—		2,210
Other OCI changes (pre-tax)	27,419			17,136			—		44,555
Income tax impact of other OCI changes	(10,855		)	(6,781		)	—		(17,636		)
Net change after income taxes	9,342			14,195			—		23,537
Balance at December 31, 2013	25,748			(83,625		)	—		(57,877		)
Amounts reclassified from AOCI (pre-tax)	(13,862		)	5,152			—		(8,710		)
Income tax impact of amounts reclassified	5,461			(2,032		)	—		3,429
Other OCI changes (pre-tax)	17,473			(15,282		)	—		2,191
Income tax impact of other OCI changes	(6,812		)	6,024			—		(788		)
Net change after income taxes	2,260			(6,138		)	—		(3,878		)
Balance at December 31, 2014	$	28,008		$	(89,763	)	$	—	$	(61,755	)

	Accumulated Other Comprehensive Income (Loss)
	Unrealized Gain on Available-for-Sale Securities		Pension Liability Adjustment		Fair Value Adjustment for Cash Flow Hedges			Total
			(In thousands)
TNMP
Balance at December 31, 2011	$	—	$	—	$	(58	)	$	(58	)
Amounts reclassified from AOCI (pre-tax)	—		—		182			182
Income tax impact of amounts reclassified	—		—		(65		)	(65		)
Other OCI changes (pre-tax)	—		—		(428		)	(428		)
Income tax impact of other OCI changes	—		—		153			153
Net change after income taxes	—		—		(158		)	(158		)
Balance at December 31, 2012	—		—		(216		)	(216		)
Amounts reclassified from AOCI (pre-tax)	—		—		207			207
Income tax impact of amounts reclassified	—		—		(73		)	(73		)
Other OCI changes (pre-tax)	—		—		(279		)	(279		)
Income tax impact of other OCI changes	—		—		98			98
Net change after income taxes	—		—		(47		)	(47		)
Balance at December 31, 2013	—		—		(263		)	(263		)
Amounts reclassified from AOCI (pre-tax)	—		—		558			558
Income tax impact of amounts reclassified	—		—		(195		)	(195		)
Other OCI changes (pre-tax)	—		—		(153		)	(153		)
Income tax impact of other OCI changes	—		—		53			53
Net change after income taxes	—		—		263			263
Balance at December 31, 2014	$	—	$	—	$	—		$	—

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 Consolidated Statements of Earnings. Pre-tax amounts reclassified from AOCI related to Pension Liability Adjustment are reclassified to Operating Expenses – Administrative and general in the Consolidated Statements of Earnings. For the years ended December 31, 2014 and 2013, approximately 24.4% and 18.7% of the amount reclassified were capitalized into construction work in process and approximately 2.0% and 3.0% were capitalized into other accounts. Pre-tax amounts reclassified from AOCI related to Fair Value Adjustment for Cash Flow Hedges are reclassified to Interest Charges in the Consolidated Statements of Earnings. An insignificant amount is then capitalized as AFUDC. The income tax impacts of all amounts reclassified from AOCI are included in Income Taxes in the Consolidated Statements of Earnings.

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Income Taxes Schedule of Components of Income Tax Expense (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Taxes [Line Items]
Current federal income tax	$ (2,015)	$ 0	$ (1,296)
Current state income tax	(728)	(917)	(37)
Deferred federal income tax	59,814	50,044	51,559
Deferred state income tax	14,831	12,578	6,921
Amortization of accumulated investment tax credits	(2,164)	(2,192)	(2,237)
Total income taxes	69,738	59,513	54,910
Public Service Company of New Mexico [Member]
Income Taxes [Line Items]
Current federal income tax	(2,175)	(479)	(12,951)
Current state income tax	(979)	(760)	(1,815)
Deferred federal income tax	45,890	42,806	56,194
Deferred state income tax	12,061	9,429	11,522
Amortization of accumulated investment tax credits	(2,164)	(2,192)	(2,237)
Total income taxes	52,633	48,804	50,713
Texas-New Mexico Power Company [Member]
Income Taxes [Line Items]
Current federal income tax	35	(4,957)	9,152
Current state income tax	1,939	1,916	1,822
Deferred federal income tax	20,577	20,688	4,406
Deferred state income tax	(28)	(26)	(28)
Total income taxes	$ 22,523	$ 17,621	$ 15,352

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Fair Value of Derivative and Other Financial Instruments (Tables)

12 Months Ended

Dec. 31, 2014

Fair Value of Derivative and Other Financial Instruments [Abstract]

Schedule of Derivative Instruments in Statement of Financial Position, Fair Value

Commodity derivative instruments that are recorded at fair value, all of which are accounted for as economic hedges, are summarized as follows:

	Economic Hedges
	December 31,
	2014			2013
	(In thousands)
PNM and PNMR
Current assets	$	11,232		$	4,064
Deferred charges	—			3,002
	11,232			7,066
Current liabilities	(1,209		)	(2,699		)
Long-term liabilities	(477		)	(1,094		)
	(1,686		)	(3,793		)
Net	$	9,546		$	3,273

Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance

The following table presents the effect of mark-to-market commodity derivative instruments on earnings, excluding income tax effects. Commodity derivatives had no impact on OCI for the periods presented.

	Economic Hedges
	Year Ended December 31,
	2014		2013		2012
	(In thousands)
PNMR and PNM
Electric operating revenues	$	4,491	$	1,727	$	6,168
Cost of energy	593		1,109		(460		)
Total gain	$	5,084	$	2,836	$	5,708

Schedule of Notional Amounts of Outstanding Derivative Positions

The table below presents PNMR’s and PNM’s net buy (sell) volume positions:

	Economic Hedges
	MMBTU	MWh
December 31, 2014
PNMR and PNM	650,000	(1,919,000	)
December 31, 2013
PNMR and PNM	905,000	(3,343,783	)

Schedule of Collateral Related to Derivative

Contingent Feature – Credit Rating Downgrade	Contractual Liability		Existing Cash Collateral		Net Exposure
	(In thousands)
December 31, 2014
PNMR and PNM	$	1,686	$	—	$	167
December 31, 2013
PNMR and PNM	$	2,398	$	—	$	2,152

Available-for-sale Securities

The fair value and gross unrealized gains of investments in available-for-sale securities are presented in the following table. At December 31, 2014 and 2013, the fair value of available-for-sale securities included $244.6 million and $222.5 million for the NDT and $5.5 million and $4.4 million for the mine reclamation trust.

	December 31, 2014				December 31, 2013
	Unrealized  Gains		Fair Value		Unrealized  Gains		Fair Value
PNMR and PNM			(In thousands)
Cash and cash equivalents	$	—	$	8,276	$	—	$	3,356
Equity securities:
Domestic value	17,418		45,340		14,523		39,460
Domestic growth	21,354		74,053		25,656		76,292
International and other	156		16,599		1,040		16,633
Fixed income securities:
U.S. Government	903		22,563		158		21,941
Municipals	5,851		68,973		1,018		58,568
Corporate and other	666		14,341		207		10,605
	$	46,348	$	250,145	$	42,602	$	226,855

Schedule of Realized Gain (Loss)

Gross realized losses shown below exclude the change in realized impairment losses of $(0.7) million, $0.6 million, and $5.2 million.

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
Proceeds from sales	$	117,989		$	271,140		$	167,330
Gross realized gains	$	15,162		$	14,308		$	15,907
Gross realized (losses)	$	(3,964	)	$	(4,298	)	$	(8,170	)

Investments Classified by Contractual Maturity Date

At December 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	$	3,946	$	8,019	$	8,019
After 1 year through 5 years	20,275		25,430		24,817
After 5 years through 10 years	13,422		—		—
After 10 years through 15 years	10,367		—		—
After 15 years through 20 years	11,539		—		—
After 20 years	46,328		—		—
	$	105,877	$	33,449	$	32,836

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis

Items recorded at fair value on the Consolidated Balance Sheets are presented below by level of the fair value hierarchy. There were no Level 3 fair value measurements at December 31, 2014 and 2013 for items recorded at fair value.

				GAAP Fair Value Hierarchy
	Total			Quoted Prices in Active Market for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)
December 31, 2014				(In thousands)
PNMR and PNM
Available-for-sale securities
Cash and cash equivalents	$	8,276		$	8,276	$	—
Equity securities:
Domestic value	45,340			45,340		—
Domestic growth	74,053			74,053		—
International and other	16,599			16,599		—
Fixed income securities:
U.S. Government	22,563			20,808		1,755
Municipals	68,973			—		68,973
Corporate and other	14,341			4,843		9,498
	$	250,145		$	169,919	$	80,226
Commodity derivative assets	$	11,232		$	—	$	11,232
Commodity derivative liabilities	(1,686		)	—		(1,686		)
Net	$	9,546		$	—	$	9,546

				GAAP Fair Value Hierarchy
	Total			Quoted Prices in Active Market for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)
December 31, 2013				(In thousands)
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

Fair Value, by Balance Sheet Grouping

The carrying amounts and fair values of investments in PVNGS lessor notes, other investments, and long-term debt are presented below:

					GAAP Fair Value Hierarchy
	Carrying Amount		Fair Value		Level 1		Level 2		Level 3
December 31, 2014	(In thousands)
PNMR
Long-term debt	$	1,975,090	$	2,173,117	$	—	$	2,173,117	$	—
Investment in PVNGS lessor notes	$	31,232	$	32,836	$	—	$	—	$	32,836
Other investments	$	1,762	$	2,375	$	639	$	—	$	1,736
PNM
Long-term debt	$	1,490,657	$	1,624,222	$	—	$	1,624,222	$	—
Investment in PVNGS lessor notes	$	31,232	$	32,836	$	—	$	—	$	32,836
Other investments	$	397	$	397	$	397	$	—	$	—
TNMP
Long-term debt	$	365,667	$	427,356	$	—	$	427,356	$	—
Other investments	$	242	$	242	$	242	$	—	$	—
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	$	—	$	—

Fair Value, Assets Measured on Recurring Basis

The fair values of investments held by the employee benefit plans are as follows:

			GAAP Fair Value Hierarchy
	Total		Quoted Prices in Active Market for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
December 31, 2014			(In thousands)
PNM Pension Plan
Participation in PNMR Master Trust Total Plan Investments	$	588,112	$	123,668	$	398,819	$	65,625
TNMP Pension Plan
Participation in PNMR Master Trust Total Plan Investments	$	69,207	$	14,823	$	44,425	$	9,959
PNM OPEB Plan
Cash and cash equivalents	$	1,242	$	1,242	$	—	$	—
Equity securities:
International funds	10,332		—		10,332		—
Domestic value	8,365		8,365		—		—
Domestic growth	5,960		5,960		—		—
Other funds	30,997		—		30,997		—
Fixed income securities:
Mutual funds	22,122		22,122		—		—
	$	79,018	$	37,689	$	41,329	$	—
TNMP OPEB Plan
Cash and cash equivalents	$	168	$	168	$	—	$	—
Equity securities:
International funds	1,277		—		1,277		—
Domestic value	403		403		—		—
Domestic growth	1,024		1,024		—		—
Other funds	3,790		—		3,790		—
Fixed income securities:
Mutual funds	3,549		3,549		—		—
	$	10,211	$	5,144	$	5,067	$	—

			GAAP Fair Value Hierarchy
	Total		Quoted Prices in Active Market for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
December 31, 2013	(In thousands)
PNM Pension Plan
Participation in PNMR Master Trust	$	557,258	$	145,364	$	330,903	$	80,991
TNMP Pension Plan
Participation in PNMR Master Trust	$	66,285	$	18,657	$	32,620	$	15,008
PNM OPEB Plan
Cash and cash equivalents	$	1,152	$	1,152	$	—	$	—
Equity securities:
International funds	11,634		—		11,634		—
Domestic value	6,388		6,388		—		—
Domestic growth	24,135		7,094		17,041		—
Other funds	14,028		—		14,028		—
Fixed income securities:
Mutual funds	16,796		16,796		—		—
	$	74,133	$	31,430	$	42,703	$	—
TNMP OPEB Plan
Cash and cash equivalents	$	302	$	302	$	—	$	—
Equity securities:
International funds	1,334		—		1,334		—
Domestic value	381		381		—		—
Domestic growth	4,171		1,848		2,323		—
Other funds	1,844		—		1,844		—
Fixed income securities:
Mutual funds	1,702		1,702		—		—
	$	9,734	$	4,233	$	5,501	$	—

The fair values of investments in the PNMR Master Trust are as follows:

			GAAP Fair Value Hierarchy
	Total		Quoted Prices in Active Market for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
December 31, 2014	(In thousands)
PNMR Master Trust
Cash and cash equivalents	$	15,645	$	15,645	$	—	$	—
Equity securities:
International	23,282		—		23,282		—
Domestic value	41,778		41,778		—		—
Domestic growth	28,370		28,370		—		—
Other funds	29,719		—		29,719		—
Fixed income securities:
Corporate	242,742		—		242,015		727
U.S. Government	106,634		52,537		54,097		—
Municipals	20,156		—		20,156		—
Other funds	74,136		161		73,975		—
Alternative investments:
Private equity funds	37,220		—		—		37,220
Hedge funds	23,876		—		—		23,876
Real estate funds	13,761		—		—		13,761
	$	657,319	$	138,491	$	443,244	$	75,584
December 31, 2013
PNMR Master Trust
Cash and cash equivalents	$	16,281	$	16,281	$	—	$	—
Equity securities:
International	24,471		24,471		—		—
Domestic value	41,451		41,451		—		—
Domestic growth	36,805		36,805		—		—
Other funds	22,522		—		22,522		—
Fixed income securities:
Corporate	202,897		363		202,358		176
U.S. Government	99,748		44,541		55,207		—
Municipals	17,259		—		17,259		—
Other funds	66,286		109		66,177		—
Alternative investments:
Private equity funds	39,122		—		—		39,122
Hedge funds	34,912		—		—		34,912
Real estate funds	21,789		—		—		21,789
	$	623,543	$	164,021	$	363,523	$	95,999

Schedule of Defined Benefit Plans Disclosures

A reconciliation of the changes in Level 3 fair value measurements is as follows:

	Year Ended December 31,
	2014			2013
Level 3 Fair Value Assets and Liabilities	(In thousands)
PNM Pension	Master Trust			Master Trust
Balance at beginning of period	$	80,991		$	79,017
Actual return on assets sold during the period	10,376			3,303
Actual return on assets still held at period end	(5,731		)	3,361
Purchases	8,832			15,110
Sales	(28,843		)	(19,800		)
Balance at end of period	65,625			80,991
TNMP Pension
Balance at beginning of period	$	15,008		$	14,171
Actual return on assets sold during the period	3,409			1,400
Actual return on assets still held at period end	(1,883		)	1,425
Purchases	2,902			6,408
Sales	(9,477		)	(8,396		)
Balance at end of period	9,959			15,008
Total	$	75,584		$	95,999

Additional information concerning changes in Level 3 fair value measurements for the PNMR Master Trust is as follows:

Level 3 Fair Value Assets and Liabilities

PNMR Master Trust	Private equity funds			Hedge funds			Real estate funds			Fixed income - corporate			Total
				(In thousands)
Balance at December 31, 2012	$	38,212		$	31,277		$	23,699		$	—		$	93,188
Actual return on assets sold during the period	4,677			135			(109		)	1			4,704
Actual return on assets still held at period end	1,162			3,500			123			—			4,785
Purchases	3,117			16,151			2,076			175			21,519
Sales	(8,046		)	(16,151		)	(4,000		)	—			(28,197		)
Balance at December 31, 2013	39,122			34,912			21,789			176			95,999
Actual return on assets sold during the period	5,355			8,667			(236		)	—			13,786
Actual return on assets still held at period end	(296		)	(7,536		)	237			(20		)	(7,615		)
Purchases	3,656			5,500			1,971			608			11,735
Sales	(10,617		)	(17,667		)	(10,000		)	(37		)	(38,321		)
Balance at December 31, 2014	$	37,220		$	23,876		$	13,761		$	727		$	75,584

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Pension and Other Postretirement Benefits

12 Months Ended

Dec. 31, 2014

Compensation and Retirement Disclosure [Abstract]

Pension and Other Postretirement Benefits

Pension and Other Postretirement Benefits

PNMR and its subsidiaries maintain qualified defined benefit pension plans, postretirement benefit plans providing medical and dental benefits, and executive retirement programs (collectively, the “PNM Plans” and “TNMP Plans”). PNMR maintains the legal obligation for the benefits owed to participants under these plans. The periodic costs or income of the PNM Plans and TNMP Plans are included in regulated rates to the extent attributable to regulated operations. PNM receives a regulated return on the amount it has funded for its pension plan in excess of the periodic cost or income to the extent included in retail rates.

Participants in the PNM Plans include eligible employees and retirees of PNMR and other subsidiaries of PNMR. Participants in the TNMP Plans include eligible employees and retirees of TNMP. The PNM pension plan was frozen at the end of 1997 with regard to new participants, salary levels, and benefits. Through December 31, 2007, additional credited service could be accrued under the PNM pension plan up to a limit determined by age and service. The TNMP pension plan was frozen at December 31, 2005 with regard to new participants, salary levels, and benefits.

GAAP requires a plan sponsor to (a) recognize in its statement of financial position an asset for a plan’s overfunded status or a liability for a plan’s underfunded status; (b) measure a plan’s assets and its obligations that determine its funded status as of the end of the employer’s fiscal year; and (c) recognize changes in the funded status of a defined benefit postretirement plan in the year in which the changes occur.

GAAP requires unrecognized prior service costs and unrecognized gains or losses to be recorded in AOCI and subsequently amortized. The amortization of these incurred costs is included as pension and postretirement benefit periodic cost or income in subsequent years. To the extent the amortization of these items will ultimately be recovered in future rates, PNM and TNMP record the costs as a regulatory asset or regulatory liability.

For the PNM Plans and TNMP Plans, the Company has in place a policy that defines the investment objectives, establishes performance goals of asset managers, and provides procedures for the manner in which investments are to be reviewed. The plans implement investment strategies to achieve the following objectives:

• Maximize the return on assets, commensurate with the risk that the Corporate Investment Committee deems appropriate to meet the obligations of the pension plans and OPEB plans, minimize the volatility of expense, and account for contingencies

• Transition asset mix over time to a higher proportion of high quality fixed income investments as the plans’ funded statuses improve

Management is responsible for the determination of the asset target mix and the expected rate of return. The target asset allocations are determined based on consultations with external investment advisors. The expected long-term rate of return on pension and postretirement plan assets is calculated on the market-related value of assets. GAAP requires that actual gains and losses on pension and postretirement plan assets be recognized in the market-related value of assets equally over a period of not more than five years, which reduces year-to-year volatility. For the PNM Plans and TNMP Plans, the market-related value of assets is equal to the prior year’s market related value of assets adjusted for contributions, benefit payments and investment gains and losses that are within a corridor of plus or minus 4.0% around the expected return on market value. Gains and losses that are outside the corridor are amortized over five years.

Pension Plans

For defined benefit pension plans, including the executive retirement plans, the PBO represents the actuarial present value of all benefits attributed by the pension benefit formula to employee service rendered prior to that date using assumptions regarding future compensation levels. The ABO represents the PBO without considering future compensation levels. Since the plans are frozen, the PBO and ABO are equal. The following table presents information about the PBO, fair value of plan assets, and funded status of the plans:

	PNM Plan						TNMP Plan
	Year Ended December 31,						Year Ended December 31,
	2014			2013			2014			2013
	(In thousands)
PBO at beginning of year	$	599,537		$	675,549		$	66,159		$	76,640
Service cost	—			—			—			—
Interest cost	30,163			28,142			3,193			3,087
Plan amendment	—			(6,346		)	—			—
Actuarial (gain) loss	72,524			(56,533		)	8,466			(7,820		)
Benefits paid	(44,667		)	(41,275		)	(5,513		)	(5,748		)
PBO at end of year	657,557			599,537			72,305			66,159
Fair value of plan assets at beginning of year	556,353			518,095			66,118			66,540
Actual return on plan assets	76,223			19,533			8,572			4,326
Employer contributions	—			60,000			—			1,000
Benefits paid	(44,667		)	(41,275		)	(5,513		)	(5,748		)
Fair value of plan assets at end of year	587,909			556,353			69,177			66,118
Funded status – asset (liability) for pension benefits	$	(69,648	)	$	(43,184	)	$	(3,128	)	$	(41	)

Effective January 1, 2014, the PNM Pension Plan was amended to allow for all participants, terminating after the effective date, to elect a lump sum payment of benefits. This change is reflected in the above table as of December 31, 2013.

The following table presents pre-tax information about prior service cost and net actuarial (gain) loss in AOCI as of December 31, 2014.

	PNM Plan						TNMP Plan
	December 31, 2014						December 31, 2014
	Prior service cost			Net actuarial (gain) loss			Net actuarial (gain) loss
	(In thousands)
Amounts in AOCI not yet recognized in net periodic benefit cost (income) at beginning of year	$	(2,665	)	$	139,256		$	—
Experience loss (gain)	—			34,345			4,420
Regulatory asset (liability) adjustment	—			(19,920		)	(4,420		)
Amortization recognized in net periodic benefit cost (income)	405			(5,469		)	—
Amounts in AOCI not yet recognized in net periodic benefit cost (income) at end of year	$	(2,260	)	$	148,212		$	—
Amortization expected to be recognized in 2015	$	(405	)	$	6,224		$	—

The following table presents the components of net periodic benefit cost (income):

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
PNM Plan
Service cost	$	—		$	—		$	—
Interest cost	30,163			28,142			32,232
Expected return on plan assets	(38,044		)	(41,930		)	(41,301		)
Amortization of net (gain) loss	13,020			14,840			10,516
Amortization of prior service cost	(965		)	76			317
Net periodic benefit cost	$	4,174		$	1,128		$	1,764
TNMP Plan
Service cost	$	—		$	—		$	—
Interest cost	3,193			3,087			3,635
Expected return on plan assets	(4,526		)	(4,849		)	(5,324		)
Amortization of net (gain) loss	665			1,049			462
Amortization of prior service cost	—			—			—
Net periodic benefit cost (income)	$	(668	)	$	(713	)	$	(1,227	)

The following significant weighted-average assumptions were used to determine the PBO and net periodic benefit cost (income). Should actual experience differ from actuarial assumptions, the PBO and net periodic benefit cost (income) would be affected.

	Year Ended December 31,
PNM Plan	2014		2013		2012
Discount rate for determining December 31 PBO	4.48	%	5.27	%	4.30	%
Discount rate for determining net periodic benefit cost (income)	5.27	%	4.30	%	5.67	%
Expected return on plan assets	7.20	%	7.65	%	8.25	%
Rate of compensation increase	N/A		N/A		N/A
TNMP Plan
Discount rate for determining December 31 PBO	4.39	%	5.06	%	4.19	%
Discount rate for determining net periodic benefit cost (income)	5.06	%	4.19	%	5.69	%
Expected return on plan assets	7.20	%	7.65	%	8.25	%
Rate of compensation increase	N/A		N/A		N/A

The assumed discount rate for determining the PBO was determined based on a review of long-term high-grade bonds and management’s expectations. Changes in discount rates resulted in an increase in the PNM PBO of $50.6 million at December 31, 2014 and a decrease of $60.9 million at December 31, 2013. Changes in discount rates resulted in an increase in the TNMP PBO of $5.1 million at December 31, 2014 and a decrease of $6.4 million at December 31, 2013. Changes in demographic experience resulted in actuarial losses in the PNM PBO of $0.2 million and $4.4 million at December 31, 2014 and 2013. Changes in demographic experience resulted in actuarial gains in the TNMP PBO of $0.4 million at December 31, 2014 and $1.4 million at December 31, 2013. Changes in other assumptions and experience resulted in actuarial gains in the PNM PBO of $0.2 million at December 31, 2014 and less than $0.1 million at December 31, 2013. Changes in other assumptions and experience resulted in actuarial losses in the TNMP PBO of $1.3 million and less than $0.1 million at December 31, 2014 and 2013. These changes are reflected as actuarial (gain) loss above.

In late 2014, the Society of Actuaries issued revised mortality tables that include changes in assumptions to reflect increased life expectancy and the corresponding decrease in mortality rates.  This change impacts the Company’s pension plans, as the mortality assumptions are used as the basis for stating the pension obligation in financial statements, determining funding requirements, and making minimum lump-sum calculations.  The actuarial valuation performed as of December 31, 2014 incorporated the impacts of the revised mortality tables.  Utilizing the revised mortality tables increased the PNM PBO by $21.9 million and the TNMP PBO by $2.5 million, which are reflected as the actuarial losses above.

The expected long-term rate of return on plan assets reflects the average rate of earnings expected on the funds invested, or to be invested, to provide for the benefits included in the PBO. Factors that are considered include, but are not limited to, historic returns on plan assets, current market information on long-term returns (e.g., long-term bond rates) and current and target asset allocations between asset categories. If all other factors were to remain unchanged, a 1% decrease in the expected long-term rate of return would cause PNM’s and TNMP’s 2015 net periodic cost to increase $5.8 million and $0.6 million (analogous changes would result from a 1% increase). The actual rate of return for the PNM and TNMP pension plans was 14.3% and 13.5% for the year ended December 31, 2014.

The Company’s long-term pension investment strategy is to invest in assets whose interest rate sensitivity is correlated with the pension liability. The Company has chosen to implement this strategy known as Liability Driven Investing (“LDI”) by increasing the liability matching investments as the funded status of the pension plans improves. These liability matching investments are currently fixed income securities. The pension plans current targeted asset allocation is 21% equities, 65% fixed income, and 14% alternative investments. Equity investments are primarily in domestic securities that include large, mid, and small capitalization companies. The pension plans have a 6% targeted allocation to equities of companies domiciled primarily in developed countries outside of the United States. This category includes actively managed international and domestic equity securities that are benchmarked against a variety of style indices. Fixed income investments are primarily corporate bonds of companies from diversified industries, and government securities. Alternative investments include investments in hedge funds, real estate funds, and private equity funds. The hedge funds and private equity funds are structured as multi-manager multi-strategy fund of funds to achieve a diversified position in these asset classes. The hedge funds pursue various absolute return strategies such as relative value, long-short equity, and event driven. Private equity fund strategies include mezzanine financing, buy-outs, and venture capital. The real estate investment is structured as an open-ended, commingled private real estate portfolio that invests in a diversified portfolio of assets including commercial property and multi-family housing. See Note 8 for fair value information concerning assets held by the pension plans.

The following pension benefit payments are expected to be paid:

	PNM Plan		TNMP Plan
	(In thousands)
2015	$	53,472	$	5,997
2016	53,468		5,667
2017	51,241		5,351
2018	49,640		5,585
2019	48,560		5,188
2020 – 2024	213,759		23,600

Due to declines during the recent recession in the general price levels of marketable equity securities held by the pension plans, PNM and TNMP have been making contributions to the pension plans since 2010. In January 2015, the Company made a contribution of to the PNM pension plan of $30.0 million. The Company does not anticipate making any additional contributions to the pension plans in 2015. Based on current law, including recent amendments to funding requirements, and estimates of portfolio performance, contributions to the pension plan trust for 2016-2019 are estimated to total $22.0 million for PNM and none for TNMP. These anticipated contributions were developed using current funding assumptions with discount rates of 4.8% to 5.5%. Actual amounts to be funded in the future will be dependent on the actuarial assumptions at that time, including the appropriate discount rate.

Other Postretirement Benefit Plans

For postretirement benefit plans, the APBO is the actuarial present value of all future benefits attributed under the terms of the postretirement benefit plan to employee service rendered to date.

The following table presents information about the APBO, the fair value of plan assets, and the funded status of the plans:

	PNM Plan						TNMP Plan
	Year Ended December 31,						Year Ended December 31,
	2014			2013			2014			2013
	(In thousands)
APBO at beginning of year	$	92,165		$	99,613		$	12,266		$	13,678
Service cost	181			260			237			299
Interest cost	4,630			4,113			619			566
Participant contributions	2,582			2,537			366			373
Actuarial (gain) loss	4,455			(4,566		)	1,639			(1,080		)
Benefits paid	(8,838		)	(9,792		)	(1,057		)	(1,570		)
APBO at end of year	95,175			92,165			14,070			12,266
Fair value of plan assets at beginning of year	73,565			64,464			9,601			8,643
Actual return on plan assets	7,334			12,780			841			1,813
Employer contributions	3,532			3,576			343			342
Participant contributions	2,582			2,537			366			373
Benefits paid	(8,838		)	(9,792		)	(1,057		)	(1,570		)
Fair value of plan assets at end of year	78,175			73,565			10,094			9,601
Funded status – asset (liability)	$	(17,000	)	$	(18,600	)	$	(3,976	)	$	(2,665	)

In the year ended December 31, 2014, actuarial losses of $2.8 million and $1.3 million were recorded in regulatory assets for the PNM Plan and TNMP Plan. There were no prior service costs recorded for the year ended December 31, 2014.

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

	Year Ended December 31,
	2014			2013			2012
	(In thousands)
PNM Plan
Service cost	$	181		$	260		$	217
Interest cost	4,630			4,113			5,293
Expected return on plan assets	(5,638		)	(5,043		)	(4,901		)
Amortization of net (gain) loss	2,225			4,242			3,888
Amortization of prior service credit	(1,343		)	(1,343		)	(1,343		)
Net periodic benefit cost	$	55		$	2,229		$	3,154
TNMP Plan
Service cost	$	237		$	299		$	244
Interest cost	619			566			624
Expected return on plan assets	(534		)	(503		)	(516		)
Amortization of net (gain) loss	(122		)	—			(209		)
Amortization of prior service cost	32			57			57
Net periodic benefit cost	$	232		$	419		$	200

The following significant weighted-average assumptions were used to determine the APBO and net periodic benefit cost. Should actual experience differ from actuarial assumptions, the APBO and net periodic benefit cost would be affected.

	Year Ended December 31,
PNM Plan	2014		2013		2012
Discount rate for determining December 31 APBO	4.45	%	5.21	%	4.26	%
Discount rate for determining net periodic benefit cost	5.21	%	4.26	%	5.70	%
Expected return on plan assets	8.50	%	8.50	%	8.50	%
Rate of compensation increase	N/A		N/A		N/A
TNMP Plan
Discount rate for determining December 31 APBO	4.45	%	5.21	%	4.26	%
Discount rate for determining net periodic benefit cost	5.21	%	4.26	%	5.70	%
Expected return on plan assets	6.50	%	6.50	%	6.50	%
Rate of compensation increase	N/A		N/A		N/A

The assumed discount rate for determining the APBO was determined based on a review of long-term high-grade bonds and management’s expectations. Changes in the discount rates resulted in an increase in the PNM APBO of $6.7 million at December 31, 2014 and a decrease of $8.8 million at December 31, 2013. Changes in discount rates resulted in an increase in the TNMP APBO of $1.1 million at December 31, 2014 and a decrease of $1.3 million at December 31, 2013. Changes in claims, contributions, medical trends, and demographic experience resulted in an actuarial gain in the PNM plan of $5.4 million at December 31, 2014 and an actuarial loss of $4.2 million at December 31, 2013. Changes in claims, contributions, and demographic experience resulted in actuarial losses in the TNMP plan of less than $0.1 million at December 31, 2014 and $0.2 million at December 31, 2013. These changes are reflected as actuarial (gain) loss above.

The actuarial valuation performed as of December 31, 2014 incorporated the impacts of the revised mortality tables discussed above.  Utilizing the revised mortality tables increased the PNM APBO by $3.2 million and the TNMP APBO by $0.5 million, which are reflected as actuarial losses above.

The expected long-term rate of return on plan assets reflects the average rate of earnings expected on the funds invested, or to be invested, to provide for the benefits included in the APBO. Factors that are considered include, but are not limited to, historic returns on plan assets, current market information on long-term returns (e.g., long-term bond rates), and current and target asset allocations between asset categories. If all other factors were to remain unchanged, a 1% decrease in the expected long-term rate of return would cause PNM’s and TNMP’s 2015 postretirement benefit cost to increase $0.7 million and $0.1 million (analogous changes would result from a 1% increase). The actual rate of return for the PNM and TNMP postretirement benefit plans was 10.2% and 8.9% for the year ended December 31, 2014.

The following table shows the assumed health care cost trend rates for the PNM postretirement benefit plan:

	PNM Plan
	December 31,
	2014		2013
Health care cost trend rate assumed for next year	7.0	%	7.5	%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)	5.0	%	5.0	%
Year that the rate reaches the ultimate trend rate	2023		2019

The following table shows the impact of a one-percentage-point change in assumed health care cost trend rates:

	PNM Plan
	1-Percentage- Point  Increase		1-Percentage- Point  Decrease
	(In thousands)
Effect on total of service and interest cost	$	350	$	(281	)
Effect on APBO	$	5,305	$	(4,622	)

TNMP’s exposure to cost increases in the postretirement benefit plan is minimized by a provision that limits TNMP’s share of costs under the plan. Costs of the plan in excess of the limit are wholly borne by the participants. TNMP reached the cost limit at the end of 2001. As a result, a one-percentage-point change in assumed health care cost trend rates would have no effect on either the net periodic expense or the year-end APBO.

The Company’s other postretirement benefit plans invest in a portfolio that is diversified by asset class and style strategies. The other postretirement benefit plans generally use the same pension fixed income and equity investment managers and utilize the same overall investment strategy as described above for the pension plans, except there is no allocation to alternative investments. The other postretirement benefit plans have a target asset allocation of 70% equities and 30% fixed income. See Note 8 for fair value information concerning assets held by the other postretirement benefit plans.

The following other postretirement benefit payments, which reflect expected future service, are expected to be paid:

	PNM Plan		TNMP Plan
	(In thousands)
2015	$	6,560	$	801
2016	6,635		822
2017	6,718		838
2018	6,875		860
2019	6,950		882
2020 - 2024	34,585		4,717

PNM expects to make contributions to the PNM postretirement benefit plan totaling $3.5 million in 2015 and $14.0 million for 2016-2019. TNMP expects to make contributions to the TNMP postretirement benefit plan totaling $0.3 million in 2015 and $1.4 million for 2016-2019 .

Executive Retirement Programs

For the executive retirement programs, the following table presents information about the PBO and funded status of the plans:

	PNM Plan						TNMP Plan
	Year Ended December 31,						Year Ended December 31,
	2014			2013			2014			2013
	(In thousands)
PBO at beginning of year	$	16,363		$	17,467		$	823		$	902
Service cost	—			—			—			—
Interest cost	822			720			39			36
Actuarial (gain) loss	2,040			(330		)	110			(21		)
Benefits paid	(1,495		)	(1,494		)	(94		)	(94		)
PBO at end of year – funded status	17,730			16,363			878			823
Less current liability	1,528			1,536			94			94
Non-current liability	$	16,202		$	14,827		$	784		$	729

The following table presents pre-tax information about net actuarial loss in AOCI as of December 31, 2014.

	December 31, 2014
	PNM Plan			TNMP Plan
	(In thousands)
Amount in AOCI not yet recognized in net periodic benefit cost at beginning of year	$	1,833		$	—
Experience loss (gain)	2,040			(110		)
Regulatory asset (liability) adjustment	(1,183		)	110
Amortization recognized in net periodic benefit cost (income)	(88		)	—
Amount in AOCI not yet recognized in net periodic benefit cost at end of year	$	2,602		$	—
Amortization expected to be recognized in 2015	$	136		$	—

The following table presents the components of net periodic benefit:

	Year Ended December 31,
	2014		2013		2012
	(In thousands)
PNM Plan
Service cost	$	—	$	—	$	—
Interest cost	822		720		876
Amortization of net (gain) loss	210		232		83
Amortization of prior service cost	—		—		—
Net periodic benefit cost	$	1,032	$	952	$	959
TNMP Plan
Service cost	$	—	$	—	$	—
Interest cost	39		36		45
Amortization of net (gain) loss	—		—		—
Amortization of prior service cost	—		—		—
Net periodic benefit cost	$	39	$	36	$	45

The following significant weighted-average assumptions were used to determine the PBO and net periodic benefit cost. Should actual experience differ from actuarial assumptions, the PBO and net periodic benefit cost would be affected.

	Year Ended December 31,
PNM Plan	2014		2013		2012
Discount rate for determining December 31 PBO	4.48	%	5.27	%	4.30	%
Discount rate for determining net periodic benefit cost	5.27	%	4.30	%	5.67	%
Long-term rate of return on plan assets	N/A		N/A		N/A
Rate of compensation increase	N/A		N/A		N/A
TNMP Plan
Discount rate for determining December 31 PBO	4.39	%	5.06	%	4.19	%
Discount rate for determining net periodic benefit cost	5.06	%	4.19	%	5.69	%
Long-term rate of return on plan assets	N/A		N/A		N/A
Rate of compensation increase	N/A		N/A		N/A

The assumed discount rate for determining the PBO was determined based on a review of long-term high-grade bonds and management’s expectations. The impacts of changes in assumptions or experience were not significant.

The following executive retirement plan payments, which reflect expected future service, are expected:

	PNM Plan		TNMP Plan
	(In thousands)
2015	$	1,528	$	93
2016	1,510		92
2017	1,490		91
2018	1,468		89
2019	1,445		86
2020 – 2024	6,722		384

Other Retirement Plans

PNMR sponsors a 401(k) defined contribution plan for eligible employees, including those of its subsidiaries. PNMR’s contributions to the 401(k) plan consist of a discretionary matching contribution equal to 75% of the first 6% of eligible compensation contributed by the employee on a before-tax basis. PNMR also makes a non-matching contribution ranging from 3% to 10% of eligible compensation based on the eligible employee’s age.

PNMR also provides executive deferred compensation benefits through an unfunded, non-qualified plan. The purpose of this plan is to permit certain key employees of PNMR who participate in the 401(k) defined contribution plan to defer compensation and receive credits without reference to the certain limitations on contributions. Eligible employees are allowed to save on an after-tax basis. This plan has been amended and the after-tax provision will be eliminated on June 30, 2015.

A summary of expenses for these other retirement plans is as follows:

	Year Ended December 31,
	2014		2013		2012
	(In thousands)
PNMR
401(k) plan	$	16,703	$	16,785	$	16,185
Non-qualified plan	$	2,257	$	2,204	$	1,491
PNM
401(k) plan	$	12,745	$	12,952	$	12,427
Non-qualified plan	$	1,722	$	1,691	$	1,143
TNMP
401(k) plan	$	3,958	$	3,953	$	3,739
Non-qualified plan	$	535	$	513	$	327

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Quarterly Operating Results (Unaudited) (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Operating revenues	$ 346,845	$ 413,951	$ 346,160	$ 328,897	$ 322,929	$ 399,730	$ 347,599	$ 317,665	$ 1,435,853	$ 1,387,923	$ 1,342,403
Operating income	62,849	116,799	71,296	48,753	40,532	117,739	77,867	50,704	299,697	286,842	273,721
Net earnings	22,111	59,486	33,181	16,131	11,397	58,814	31,383	13,962	130,909	115,556	120,125
Earnings Attributable to PNMR	18,992	55,653	29,141	12,468	7,648	54,555	27,678	10,626	116,254	100,507	105,547
Net Earnings Attributable to PNMR per Common Share:
Basic (dollars per share)	$ 0.24	$ 0.70	$ 0.37	$ 0.16	$ 0.10	$ 0.68	$ 0.35	$ 0.13	$ 1.46	$ 1.26	$ 1.32
Diluted (dollars per share)	$ 0.24	$ 0.69	$ 0.36	$ 0.16	$ 0.10	$ 0.68	$ 0.34	$ 0.13	$ 1.45	$ 1.25	$ 1.31
Public Service Company of New Mexico [Member]
Segment Reporting Information [Line Items]
Operating revenues	274,481	334,993	275,704	262,736	252,702	326,026	279,690	257,894
Operating income	40,988	90,615	49,806	31,304	18,427	95,217	58,302	37,239
Net earnings	16,942	49,052	24,254	11,205	6,256	51,950	29,697	14,773
Earnings Attributable to PNMR	13,955	45,351	20,346	7,674	2,639	47,823	26,124	11,569
Texas-New Mexico Power Company [Member]
Segment Reporting Information [Line Items]
Operating income	21,188	25,873	21,265	17,262	17,210	22,254	19,667	13,054
Earnings Attributable to PNMR	9,115	12,355	9,534	6,803	6,919	10,106	8,339	3,726
Electric Domestic Regulated Revenue	$ 72,364	$ 78,958	$ 70,456	$ 66,161	$ 70,227	$ 73,704	$ 67,909	$ 59,771