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 September 30, 2014

Commission   File Number	Exact name of registrant as specified in its charter and principal office address and telephone number	State of Incorporation	I.R.S. Employer Identification No.
1-16163	WGL Holdings, Inc. 101 Constitution Ave., N.W. Washington, D.C. 20080 (703) 750-2000	Virginia	52-2210912
0-49807	Washington Gas Light Company 101 Constitution Ave., N.W. Washington, D.C. 20080 (703) 750-4440	District of Columbia and Virginia	53-0162882

Securities registered pursuant to Section 12(b) of the Act (as of September 30, 2014):
Title of each class	Name of each exchange on which registered
WGL Holdings, Inc. common stock, no par value	New York Stock Exchange

Securities registered pursuant to Section 12(g) of the Act (as of September 30, 2014):
Title of each class	Name of each exchange on which registered
Washington Gas Light Company preferred stock, cumulative, without par value:
$4.25 Series	Over-the-Counter Bulletin Board
$4.80 Series	Over-the-Counter Bulletin Board
$5.00 Series	Over-the-Counter Bulletin Board

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

WGL Holdings, Inc.	Yes [X]  No [   ]
Washington Gas Light Company	Yes [   ]  No [X]

Indicate by check mark if each registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.  Yes [   ]  No [X]

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 registrants were required to file such reports) and (2) has been subject to such filing requirements for the past 90 days.  Yes [X]  No [   ]

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, 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).  Yes [X]  No [   ]

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§ 229.405 of this chapter) is not contained herein, and will not be contained, to the best of the 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.  [   ]

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

WGL Holdings, Inc.:

Large Accelerated Filer [X]	Accelerated Filer [   ]	Non-Accelerated Filer [   ]	Smaller Reporting Company [   ]
	(Do not check if a smaller reporting company)

Washington Gas Light Company:

Large Accelerated Filer [   ]	Accelerated Filer [   ]	Non-Accelerated Filer [X]	Smaller Reporting Company [   ]
	(Do not check if a smaller reporting company)

Indicate by check mark whether each registrant is a shell company (as defined in Rule 12b-2 of the Act):  Yes [   ]  No [X]

The aggregate market value of the voting common equity held by non-affiliates of the registrant, WGL Holdings, Inc., amounted to $2,064,823,797 as of March 31, 2014.

WGL Holdings, Inc. common stock, no par value outstanding as of October 31, 2014: 49,708,750 shares.

All of the outstanding shares of common stock ($1 par value) of Washington Gas Light Company were held by WGL Holdings, Inc. as of October 31, 2014.

DOCUMENTS INCORPORATED BY REFERENCE

Portions of WGL Holdings, Inc.’s definitive Proxy Statement and Washington Gas Light Company’s definitive Information Statement in connection with the 2015 Annual Meeting of Shareholders, to be filed with the Securities and Exchange Commission pursuant to Regulation 14A and 14C not later than 120 days after September 30, 2014, are incorporated in Part III of this report.

WGL Holdings, Inc.

Washington Gas Light Company

For the Fiscal Year Ended September 30, 2014

Table of Contents

PART I
Introduction
	Filing Format	1
	Safe Harbor for Forward-Looking Statements	1
Glossary of Key Terms and Definitions		3
Item 1.	Business	5
	Corporate Overview	5
	Industry Segments	5
	Environmental Matters	14
	Other Information	14
Item 1A.	Risk Factors	15
Item 1B.	Unresolved Staff Comments	19
Item 2.	Properties	20
Item 3.	Legal Proceedings	21
Item 4.	Mine Safety Disclosures	22
Executive Officers of the Registrants		23
PART II
Item 5.	Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	24
Item 6.	Selected Financial Data	25
Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	27
Item 7A.	Quantitative and Qualitative Disclosures about Market Risk	70
Item 8.	Financial Statements and Supplementary Data	70
	WGL Holdings, Inc.	71
	Washington Gas Light Company	77
	Notes to Consolidated Financial Statements	83
	Supplementary Financial Information—Quarterly Financial Data (Unaudited)	144
Item 9.	Changes In and Disagreements with Accountants on Accounting and Financial Disclosure	145
Item 9A.	Controls and Procedures	145
Item 9B.	Other Information	148
PART III
Item 10.	Directors, Executive Officers and Corporate Governance of the Registrants	149
Item 11.	Executive Compensation	149
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	149
Item 13.	Certain Relationships and Related Transactions, and Director Independence	149
Item 14.	Principal Accounting Fees and Services	149
PART IV
Item 15.	Exhibits and Financial Statement Schedules	150
Signatures		156

(i)

WGL Holdings, Inc.

Washington Gas Light Company

INTRODUCTION

FILING FORMAT

This annual report on Form 10-K is a combined report being filed by two separate registrants: WGL Holdings, Inc. (WGL) and Washington Gas Light Company (Washington Gas). Except where the content clearly indicates otherwise, any reference in the report to “WGL,” “we,” “us” or “our” is to the holding company or the consolidated entity of WGL Holdings and all of its subsidiaries, including Washington Gas which is a distinct registrant that is a wholly owned subsidiary of WGL.

The Management’s Discussion and Analysis of Financial Condition and Results of Operations (Management’s Discussion) included under Item 7 is divided into two major sections for WGL and Washington Gas. The Consolidated Financial Statements of WGL and the Financial Statements of Washington Gas are included under Item 8 as well as the Notes to Consolidated Financial Statements that are presented on a combined basis for both WGL and Washington Gas.

SAFE HARBOR FOR FORWARD-LOOKING STATEMENTS

Certain matters discussed in this report, excluding historical information, include forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995 with respect to the outlook for earnings, revenues and other future financial business performance or strategies and expectations. Forward-looking statements are typically identified by words such as, but not limited to, “estimates,” “expects,” “anticipates,” “intends,” “believes,” “plans,” and similar expressions, or future or conditional verbs such as “will,” “should,” “would” and “could.” Although the registrants, WGL and Washington Gas, believe such forward-looking statements are based on reasonable assumptions, they cannot give assurance that every objective will be achieved. Forward-looking statements speak only as of today, and the registrants assume no duty to update them. The following factors, among others, could cause actual results to differ materially from forward-looking statements or historical performance:

• the level and rate at which costs and expenses are incurred and the extent to which they are allowed to be recovered from customers through the regulatory process in connection with constructing, operating and maintaining Washington Gas’ distribution system;

• the availability of natural gas supply and interstate pipeline transportation and storage capacity;

• the ability of natural gas producers, pipeline gatherers and natural gas processors to deliver natural gas into interstate pipelines for delivery by those interstate pipelines to the entrance points of Washington Gas’ distribution system as a result of factors beyond our control;

• changes and developments in economic, competitive, political and regulatory conditions;

• changes in capital and energy commodity market conditions;

• changes in credit ratings of debt securities of WGL or Washington Gas that may affect access to capital or the cost of debt;

• changes in credit market conditions and creditworthiness of customers and suppliers;

• changes in relevant laws and regulations, including tax, environmental, pipeline integrity and employment laws and regulations;

• legislative, regulatory and judicial mandates or decisions affecting business operations or the timing of recovery of costs and expenses;

• the timing and success of business and product development efforts and technological improvements;

• the pace of deregulation efforts and the availability of other competitive alternatives to our products and services;

• changes in accounting principles;

• new commodity purchase and sales contracts or financial contracts and modifications in the terms of existing contracts that may materially affect fair value calculations under derivative accounting requirements;

• the ability to manage the outsourcing of several business processes;

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• acts of nature;

• terrorist activities and

• other uncertainties.

The outcome of negotiations and discussions that the registrants may hold with other parties from time to time regarding utility and energy-related investments and strategic transactions that are both recurring and non-recurring may also affect future performance. All such factors are difficult to predict accurately and are generally beyond the direct control of the registrants. Accordingly, while they believe that the assumptions are reasonable, the registrants cannot ensure that all expectations and objectives will be realized. Readers are urged to use care and consider the risks, uncertainties and other factors that could affect the registrants’ business as described in this annual report on Form 10-K. All forward-looking statements made in this report rely upon the safe harbor protections provided under the Private Securities Litigation Reform Act of 1995.

2

WGL Holdings, Inc.

Washington Gas Light Company

Part I

GLOSSARY OF KEY TERMS AND DEFINITIONS

Active Customer Meters: Natural gas meters that are physically connected to a building structure within the Washington Gas distribution system and that receive active service.   Accelerated Pipe Replacement Programs: Programs focused on replacement activities, targeting specific piping materials, installed years and/or locations which are undertaken on an expedited basis in an effort to improve safety, system reliability and to reduce potential greenhouse gas emissions.    Asset Optimization Program: A program to optimize the value of Washington Gas’ long-term natural gas transportation and storage capacity resources during periods when these resources are not being used to physically serve customers.   Bundled Service: Service in which customers purchase both the natural gas commodity and the distribution or delivery of the commodity from the local regulated utility. When customers purchase bundled service from Washington Gas, no mark-up is applied to the cost of the natural gas commodity that is passed through to customers.   Business Process Outsourcing (BPO) Agreement: An agreement whereby a service provider performs certain functions that have historically been performed by Washington Gas employees and resources.   Conservation and Ratemaking Efficiency (CARE Plan): A decoupling rate mechanism designed to adjust the actual non-gas distribution revenues to the level of allowed distribution revenues authorized in the Company’s most recent rate case proceeding and provides cost effective conservation and energy efficient programs.   City Gate: A point or measuring station at which a gas distribution company such as Washington Gas receives natural gas from an unaffiliated pipeline or transmission system.   Cooling Degree Day (CDD): A measure of the variation in weather based on the extent to which the daily average temperature is above 65 degrees Fahrenheit.   CARE Ratemaking Adjustment (CRA): A billing mechanism in the state of Virginia that is designed to minimize the effect of factors such as conservation on utility net revenues.   Commercial Energy Systems: Formerly known as the “design-build energy systems” segment, the commercial energy systems segment includes the operations of Washington Gas Energy Systems, Inc. and WGSW, Inc.   Delivery Service: The regulated distribution or delivery of natural gas to retail customers. Washington Gas provides delivery service to retail customers in Washington, D.C. and parts of Maryland and Virginia.   Design Day: Washington Gas’ design day represents the maximum anticipated demand on Washington Gas’ distribution system during a 24-hour period assuming a five-degree Fahrenheit average temperature and 17 miles per hour average wind, considered to be the coldest conditions expected to be experienced in the Washington, D.C. region.   Distributed Generation Assets: Assets that use renewable energy sources including Solar Photovoltaic (Solar PV) systems, combined heat and power plants, and natural gas fuel cells to generate electricity near the point of consumption.   Federal Energy Regulatory Commission (FERC): An independent agency of the federal government that regulates the interstate transmission of electricity, natural gas, and oil. The FERC also reviews proposals to build liquefied natural gas terminals and interstate natural gas pipelines. Financial Contract: A contract in which no commodity is transferred between parties and only cash payments are exchanged in amounts equal to the financial benefit of holding the contract.   Firm Customers: Customers whose gas supply will not be disrupted to meet the needs of other customers. Typically, this class of customer comprises residential customers and most commercial customers.   Generally Accepted Accounting Principles (GAAP): A standard framework of accounting rules used to prepare, present and report financial statements in the United States of America.   Gross Margin: A non-GAAP measure calculated as operating revenues, less the associated cost of natural gas or electricity and revenue taxes. Used to measure the success of the retail energy-marketing segment’s core strategy for the sale of natural gas and electricity.   Heating Degree Day (HDD): A measure of the variation in weather based on the extent to which the daily average temperature falls below 65 degrees Fahrenheit.   Heavy Hydrocarbons (HHCs): Compounds, such as hexane, that Washington Gas is injecting into its distribution system to treat vaporized liquefied natural gas or domestic sources of gas that have had such HHCs removed as a result of liquids processing.   Interruptible Customers: Large commercial customers whose service can be temporarily interrupted in order for the regulated utility to meet the needs of firm customers. These customers pay a lower delivery rate than firm customers and they must be able to readily substitute an alternate fuel for natural gas.   Liquefied Natural Gas (LNG): The liquid form of natural gas.   Lower of Cost or Market: The process of adjusting the value of inventory to reflect the lesser of its original cost or its current market value.   Mark-to-Market: The process of adjusting the carrying value of a position held in a physical or financial derivative to reflect its current fair value.   Midstream Energy Services: Formerly known as the wholesale energy solutions segment, the midstream energy services segment includes the operations of WGL Midstream, Inc.   New Customer Meters Added: Natural gas meters that are newly connected to a building structure within the Washington Gas distribution system. Service may or may not have been activated.   Normal Weather: A forecast of expected HDDs or CDDs based on the previous 30 years of historical HDD or CDD data.

3

WGL Holdings, Inc.

Washington Gas Light Company

Part I

PSC of DC: The Public Service Commission of the District of Columbia is a three-member board that regulates Washington Gas’ distribution operations in the District of Columbia.   PSC of MD: The Maryland Public Service Commission is a five-member board that regulates Washington Gas’ distribution operations in Maryland.   Purchased Gas Charge (PGC): The purchased gas charge represents the cost of gas, gas transportation, gas storage services purchased and other gas related costs. The purchased gas charge is collected from customers through tariffs established by the regulatory commissions that have jurisdiction over Washington Gas.   Regulated Utility Segment: Includes the operations of Washington Gas that are regulated by regulatory commissions located in the District of Columbia, Maryland and Virginia, and the operations of Hampshire Gas Company that are regulated by the Federal Energy Regulatory Commission.   Retail Energy-Marketing Segment: Unregulated sales of natural gas and electricity to end users by our subsidiary, Washington Gas Energy Services, Inc.   Return on Average Common Equity: Net income divided by average common shareholders’ equity.   Revenue Normalization Adjustment (RNA): A regulatory billing mechanism in the state of Maryland designed to stabilize the level of net revenues collected from customers by eliminating the effect of deviations in customer usage caused by variations in weather from normal levels, and other factors such as conservation.   Steps to Advance Virginia’s Energy Plan (SAVE Plan): A plan that provides for accelerated recovery mechanisms for costs of eligible infrastructure replacement programs in the state of Virginia.   SCC of VA: The Commonwealth of Virginia State Corporation Commission is a three-member board that regulates Washington Gas’ distribution operations in Virginia.   Service Area: The region in which Washington Gas operates. The service area includes the District of Columbia, and the surrounding metropolitan areas in Maryland and Virginia.   Solar Renewable Energy Credits (SREC): a certificate representing the “green attributes” of one megawatt-hour (MWh) of electricity generated from solar energy.   Sendout: The total gas that is produced, purchased, or withdrawn from storage within a certain interval of time. Gas sendout is comprised of natural gas sales, exchanges, deliveries, natural gas used by the company and unaccounted-for gas.   Strategic Infrastructure Development and Enhancement Plan (STRIDE Plan): A plan to recover the reasonable and prudent costs associated with infrastructure replacements through monthly surcharges in the state of Maryland.   Tariffs: Documents approved by the regulatory commission in each jurisdiction that set the prices Washington Gas may charge and the practices it must follow when providing utility service to its customers.   Third Party Marketer: Unregulated companies that sell natural gas and electricity directly to retail customers. Washington Gas Energy Services, Inc., an affiliate of Washington Gas and a wholly owned subsidiary company of Washington Gas Resources Corporation, is a third-party marketer. Therm: A natural gas unit of measurement that includes a standard measure for heating value. We report our natural gas sales and deliveries in therms. A therm of gas contains 100,000 British thermal units of heat, or the energy equivalent of burning approximately 100 cubic feet of natural gas under normal conditions. Ten million therms equal approximately one billion cubic feet of natural gas.   Unbundling: The separation of the delivery of natural gas or electricity from the sale of these commodities and related services that, in the past, were provided only by a regulated utility.   Utility Net Revenues: A non-GAAP measure calculated as operating revenues less the associated cost of energy and applicable revenue taxes. Used to analyze the profitability of the regulated utility segment, as the cost of gas associated with sales to customers and revenue taxes are generally pass through amounts.   Value-At-Risk: A risk measurement that estimates the largest expected loss over a specified period of time under normal market conditions within a specified probabilistic confidence interval.   Washington Gas: Washington Gas Light Company is a subsidiary of WGL Holdings, Inc. that sells and delivers natural gas primarily to retail customers in accordance with tariffs approved by the PSC of DC, the PSC of MD and the SCC of VA.   Washington Gas Resources: Washington Gas Resources Corporation is a subsidiary of WGL Holdings, Inc. that owns the majority of the non-utility subsidiaries.   Weather Derivative: A financial instrument that provides financial protection from the effects of variations from normal weather.   Weather Normalization Adjustment (WNA): A billing adjustment mechanism that is designed to minimize the effect of variations from normal weather on utility net revenues.   WGESystems: Washington Gas Energy Systems, Inc. is a subsidiary of Washington Gas Resources Corporation, which provides commercial energy efficient and sustainable solutions to government and commercial clients.   WGL: WGL Holdings, Inc. is a holding company that is the parent company of Washington Gas Light Company and other subsidiaries.   WGL Midstream: WGL Midstream, Inc. is a subsidiary of Washington Gas Resources that engages in acquiring and optimizing natural gas storage and transportation assets.   WGEServices: Washington Gas Energy Services, Inc. is a subsidiary of Washington Gas Resources Corporation that sells natural gas and electricity to retail customers on an unregulated basis.   WGSW: WGSW, Inc. is a subsidiary of Washington Gas Resources Corporation that was formed to invest in certain renewable energy projects.

4

WGL Holdings, Inc.

Washington Gas Light Company

Part I

Item 1. Business

ITEM 1.  BUSINESS

CORPORATE OVERVIEW

WGL HOLDINGS, INC.

WGL Holdings, Inc. (WGL) was established on November 1, 2000 as a Virginia corporation. Through our wholly owned subsidiaries, we sell and deliver natural gas and provide energy-related products and services to customers primarily in the District of Columbia and the surrounding metropolitan areas in Maryland and Virginia, though our non-utility segments provide various energy services in 31 states and the District of Columbia. WGL promotes the efficient use of clean natural gas and renewable energy to improve the environment for the benefit of customers, investors, employees, and the communities it serves. WGL owns all of the shares of common stock of Washington Gas Light Company (Washington Gas), Washington Gas Resources, Hampshire Gas Company (Hampshire) and Crab Run Gas Company (Crab Run). Washington Gas Resources owns four unregulated subsidiaries that include Washington Gas Energy Services, Inc. (WGEServices), Washington Gas Energy Systems, Inc. (WGESystems), WGL Midstream, Inc. (WGL Midstream) and WGSW, Inc. (WGSW).

*Holding company whose stand alone results are reported in “other activities”.

Industry Segments

Our segments include Regulated Utility, Retail Energy-Marketing, Commercial Energy Systems and Midstream Energy Services. Transactions and activities not specifically identified in one of these four segments are reported as “Other Activities.” The four segments are described below.

5

WGL Holdings, Inc.

Washington Gas Light Company

Part I

Item 1. Business (continued)

REGULATED UTILITY SEGMENT

Washington Gas Light Company

The regulated utility segment consists of Washington Gas and Hampshire and represents approximately 82% of WGL’s total assets. Washington Gas is a regulated public utility that sells and delivers natural gas to retail customers in accordance with tariffs approved by regulatory commissions in the District of Columbia and adjoining areas in Maryland, Virginia and several cities and towns in the northern Shenandoah Valley of Virginia. Washington Gas has been engaged in the natural gas distribution business since its incorporation by an Act of Congress in 1848. Washington Gas has been a Virginia corporation since 1953 and a corporation of the District of Columbia since 1957.

Washington Gas sells natural gas to customers who have elected not to purchase natural gas from unregulated third party marketers (refer to the section entitled “Natural Gas Unbundling”). Washington Gas recovers the cost of the natural gas

purchased to serve firm customers through recovery mechanisms as approved in jurisdictional tariffs. Any difference between gas costs incurred on behalf of firm customers and the gas costs recovered from those customers is deferred on the balance sheet as an amount to be collected from or refunded to customers in future periods. Therefore, increases or decreases in the cost of gas associated with sales made to firm customers have no direct effect on Washington Gas’ net revenues and net income.

Washington Gas, under its asset optimization program, makes use of storage and transportation capacity resources when those assets are not required to serve utility customers. The objective of this program is to derive a profit to be shared with its utility customers by entering into commodity-related physical and financial contracts with third parties (refer to the section entitled “Asset Optimization” for further discussion of the asset optimization program). Unless otherwise noted, therm deliveries reported for the regulated utility segment do not include those related to the asset optimization program.

At September 30, 2014, Washington Gas’ service area had a population estimated at 5.8 million and included almost 2.2 million households and commercial structures. Washington Gas operations are such that the loss of any one customer or group of customers would not have a significant adverse effect on its business. The following table lists the number of active customer meters and therms delivered by jurisdiction as of and for the year ended September 30, 2014 and 2013, respectively.

Active Customer Meters and Therms Delivered by Jurisdiction
Jurisdiction	Active Customer Meters as of   September 30, 2014		Millions of Therms Delivered Fiscal Year Ended   September  30, 2014		Active Customer Meters as of   September 30, 2013		Millions of Therms Delivered Fiscal Year Ended    September  30, 2013
District of Columbia		155,993		317.8		154,982		300.4
Maryland		454,273		891.7		448,916		865.7
Virginia		506,777		679.4		501,225		614.8
Total		1,117,043		1,888.9		1,105,123		1,780.9

For additional information about gas deliveries and meter statistics, refer to the section entitled “Results of Operations” in Management’s Discussion and Analysis for Washington Gas.

Hampshire Gas Company

Hampshire owns full and partial interests in underground natural gas storage facilities, including pipeline delivery facilities located in and around Hampshire County, West Virginia, and operates those facilities to serve Washington Gas, which purchases all of the storage services of Hampshire. Washington Gas includes the cost of these services in the bills sent to its customers. Hampshire operates under a “pass-through” cost of service-based tariff approved by the FERC, and adjusts its billing rates to Washington Gas on a periodic basis to account for changes in its investment in utility plant and associated expenses.

Factors critical to the success of the regulated utility segment include: (i) operating a safe and reliable natural gas distribution system; (ii) having sufficient natural gas supplies to meet customer demands; (iii) being competitive with other sources of energy such as electricity, fuel oil and propane; (iv) having access to sources of liquidity; (v) recovering the costs and expenses of this business in the rates charged to customers and (vi) earning a just and reasonable rate of return on invested capital. The regulated utility segment reported total operating revenues related to gas sales and deliveries to external customers of approximately $1.4 billion, $1.2 billion, and $1.1 billion in fiscal years ended September 30, 2014, 2013 and 2012, respectively.

Regulatory Environment

Washington Gas is regulated by the PSC of DC, the PSC of MD and the SCC of VA which approve its terms of service and the billing rates that it charges to its customers. Hampshire is regulated by the FERC. The rates charged to utility customers are designed to recover Washington Gas’ operating expenses and natural gas commodity costs and to provide a return on its investment in the net assets used in its firm gas sales and delivery service. For a discussion of current rates and regulatory matters, refer to the section entitled “Rates and Regulatory Matters” in Management’s Discussion and Analysis for Washington Gas.

6

WGL Holdings, Inc.

Washington Gas Light Company

Part I

Item 1. Business (continued)

District of Columbia Jurisdiction

The PSC of DC consists of three full-time members who are appointed by the Mayor with the advice and consent of the District of Columbia City Council. The term of each commissioner is four years with no limitations on the number of terms that can be served. The PSC of DC has no time limitation in which it must make decisions regarding modifications to base rates charged by Washington Gas to its customers; however it targets resolving pending rate cases within nine months from the date a rate case is filed.

Maryland Jurisdiction

The PSC of MD consists of five full-time members who are appointed by the Governor with the advice and consent of the Senate of Maryland. Each commissioner is appointed to a five-year term, with no limit on the number of terms that can be served.

When Washington Gas files for a rate increase, the PSC of MD may initially suspend the proposed increase for 180 days, and then has the option to extend the suspension for an additional 30 days. If action has not been taken after 210 days, the requested rates become effective subject to refund.

Virginia Jurisdiction

The SCC of VA consists of three full-time members who are elected by the General Assembly of Virginia. Each commissioner has a six-year term with no limitation on the number of terms that can be served.

Either of two methods may be used to request a modification of existing rates. Washington Gas may file an application for a general rate increase in which it may propose new adjustments to the cost of service that are different from those previously approved for Washington Gas by the SCC of VA, as well as a revised return on equity. The proposed rates under this process may take effect 150 days after the filing, subject to refund pending the outcome of the SCC of VA’s action on the application.

Alternatively, an expedited rate case procedure allows proposed rate increases to be effective 30 days after the filing date, also subject to refund. Under this procedure, Washington Gas may not propose new adjustments for issues not approved in its last general rate case, or request a change in its authorized return on common equity. Once filed, other parties may propose new adjustments or a change in the cost of capital from the level authorized in its last general rate case. The expedited rate case procedure may not be available if the SCC of VA decides that there has been a substantial change in circumstances since the last general rate case filed by Washington Gas.

Seasonality of Business Operations

Washington Gas’ business is weather-sensitive and seasonal because the majority of its business is derived from residential and small commercial customers who use natural gas for space heating. Excluding deliveries for electric generation, in fiscal year 2014 and 2013, approximately 79% and 77%, respectively, of the total therms delivered in Washington Gas’ service area occurred during its first and second fiscal quarters. Washington Gas’ earnings are typically generated during these two quarters, and Washington Gas historically incurs net losses in the third and fourth fiscal quarters. The seasonal nature of the business creates large variations in short-term cash requirements, primarily due to the fluctuations in the level of customer accounts receivable, unbilled revenues and storage gas inventories. Washington Gas finances these seasonal requirements primarily through the sale of commercial paper and unsecured short-term bank loans. For information on our management of weather risk, refer to the section entitled “Weather Risk” in Management’s Discussion and Analysis. For information about management of cash requirements, refer to the section entitled “Liquidity and Capital Resources” in Management’s Discussion and Analysis.

Natural Gas Supply and Capacity

Capacity and Supply Requirements

Washington Gas is responsible for acquiring sufficient natural gas supplies, interstate pipeline capacity and storage capacity to meet customer demand. As such, Washington Gas has adopted a diversified portfolio approach designed to address constraints on supply by using multiple supply receipt points, dependable interstate pipeline transportation and storage arrangements, and its own substantial storage and peak shaving capabilities. Washington Gas’ supply and pipeline capacity plan is based on forecasted system requirements, and takes into account estimated load growth, attrition, conservation, geographic location, interstate pipeline and storage capacity and contractual limitations and the forecasted movement of customers between bundled service and delivery service. Under reduced supply conditions, Washington Gas may implement contingency plans in order to maximize the number of customers served. Contingency plans include requests to the general population to conserve and target curtailments to specific sections of the system, consistent with curtailment tariffs approved by regulators in each of Washington Gas’ three jurisdictions.

7

WGL Holdings, Inc.

Washington Gas Light Company

Part I

Item 1. Business (continued)

Washington Gas obtains natural gas supplies that originate from multiple regions throughout the United States and Canada. At September 30, 2014 and 2013, Washington Gas had service agreements with four pipeline companies that provided firm transportation and/or storage services directly to Washington Gas’ city gate. For fiscal years 2014 and 2013, these contracts have expiration dates ranging from fiscal years 2015 to 2032 and 2014 to 2029, respectively.

Transportation and Storage Additions

Washington Gas has contracted with various interstate pipeline and storage companies to add to its storage and transportation capacity. The following projects are in progress to increase Washington Gas’ transportation and/or storage capacity.

Transportation and Storage Capacity Additions (in therms)
Pipeline Service Provider	Daily Capacity	Annual Capacity	In-Service Date     (Fiscal Year)
Dominion Transmission Inc. Alleghany Storage	1 million	60 million	2015
Transcontinental Gas Pipe Line Company	0.75 million	11 million	2015
Transcontinental Gas Pipe Line Company, LLC Leidy Southeast	1.65 million	60 million	2016

Washington Gas will continue to monitor other opportunities to acquire or participate in obtaining additional pipeline and storage capacity that will support customer growth and improve or maintain the high level of service expected by its customer base.

Asset Optimization Derivative Contracts

Under the asset optimization program, Washington Gas utilizes its storage and transportation capacity resources when they are not being used to serve its utility customers. Washington Gas executes commodity-related physical and financial contracts in the form of forwards, futures and options as part of an asset optimization program that is managed by its internal staff. These transactions are accounted for as derivatives. The objective of this program is to derive a profit to be shared with its utility customers. Washington Gas enters into these derivative transaction contracts to secure operating margins that will ultimately be shared between Washington Gas customers and shareholders. Because these sharing mechanisms are approved by our regulators in all three jurisdictions, any changes in fair value of the derivatives are recorded through earnings or as regulatory assets or liabilities if realized gains and losses will be included in the rates charged to customers.

The derivatives used under this program are subject to fair value accounting treatment which may cause significant period-to-period volatility in earnings from unrealized gains and losses associated with changes in fair value for the portion of net profits attributed to shareholders. However, this volatility does not change the secured operating margins that Washington Gas expects to realize from these transactions. All physically and financially settled contracts under our asset optimization program are reported on a net basis in the statements of income in “Utility cost of gas.” Total net margins including unrealized gains and losses recorded to “Utility cost of gas” after sharing and management fees associated with all asset optimization transactions for the year ended September 30, 2014 and the prior two fiscal years were net losses of $35.4 million and $33.2 million and a net gain of $28.3 million, respectively.

Refer to the sections entitled “Results of Operations — Regulated Utility” and “Market Risk” in Management’s Discussion and Analysis for further discussion of the asset optimization program and its effect on earnings.

Annual Sendout

As reflected in the table below, Washington Gas received natural gas from multiple sources in fiscal year 2014 and expects to use those same sources to satisfy customer demand in fiscal year 2015. Firm transportation denotes gas transported directly to the entry point of Washington Gas’ distribution system in contractual volumes. Transportation storage denotes volumes stored by a pipeline during the spring, summer and fall for withdrawal and delivery to the Washington Gas distribution system during the winter heating season to meet load requirements. Peak load requirements are met by: (i) underground natural gas storage at the Hampshire storage field; (ii) the local production of propane air plants located at Washington Gas-owned facilities in Rockville, Maryland (Rockville Station) and in Springfield, Virginia (Ravensworth Station) and (iii) other peak-shaving resources. Unregulated third party marketers acquire interstate pipeline and storage capacity and the natural gas commodity on behalf of Washington Gas’ delivery service customers under customer choice programs. Washington Gas also provides transportation, storage and peaking resources to unregulated third party marketers (refer to the section entitled “Natural Gas Unbundling”). These retail marketers have natural gas delivered to the entry point of Washington Gas’ distribution system on behalf of those utility customers that have decided to acquire their natural gas commodity on an unbundled basis, as discussed below.

8

WGL Holdings, Inc.

Washington Gas Light Company

Part I

Item 1. Business (continued)

Excluding the sendout of sales and deliveries of natural gas used for electric generation, the following table outlines total sendout of the system. The sources of delivery and related volumes that were used to satisfy the requirements of fiscal year 2014 and those projected for pipeline year 2015 are shown in the following table.

Sources of Delivery for Annual Sendout
(In millions of therms)	Fiscal Year
Sources of Delivery	Actual 2013		Actual 2014 (a)		Projected   2015 (b)
Firm Transportation		613		622		604
Transportation Storage		261		269		252
Hampshire Storage, Company-Owned Propane-Air Plants, and other Peak-Shaving Resources		18		20		19
Unregulated Third Party Marketers		759		851		775
Total		1,651		1,762		1,650

^(a) Higher 2014 sendouts is the result of colder weather than 2013.

^(b) Based on normal weather.

Design Day Sendout

The effectiveness of Washington Gas’ capacity resource plan is largely dependent on the sources used to satisfy forecasted and actual customer demand requirements for its design day. For planning purposes, Washington Gas assumes that all interruptible customers will be curtailed on the design day. Washington Gas’ forecasted design day demand for the 2014-2015 winter season is 19.0 million therms and Washington Gas’ projected sources of delivery for design day sendout is 20.0 million therms. This provides a reserve margin of approximately 5.2%. Washington Gas plans for the optimal utilization of its storage and peaking capacity to reduce its dependency on firm transportation and to lower pipeline capacity costs. The following table reflects the sources of delivery that are projected to be used to satisfy the forecasted design day sendout estimate for fiscal year 2015.

Projected Sources of Delivery for Design Day Sendout
(In millions of therms)	Fiscal Year 2015
Sources of Delivery	Volumes		Percent
Firm Transportation		5.2		26	%
Transportation Storage		8.5		43	%
Hampshire Storage, Company-Owned Propane-Air Plants and other Peak-Shaving Resources		6.1		30	%
Unregulated Third Party Marketers		0.2		1	%
Total		20.0		100	%

Natural Gas Unbundling

At September 30, 2014, customer choice programs for natural gas customers were available to all of Washington Gas’ regulated utility customers in the District of Columbia, Maryland and Virginia. These programs allow customers to purchase their natural gas from unregulated third party marketers, rather than purchasing this commodity as part of a bundled service from the local utility. Of Washington Gas’ 1.1 million active customers at September 30, 2014, approximately 182,000 customers purchased their natural gas commodity from unregulated third party marketers.

9

WGL Holdings, Inc.

Washington Gas Light Company

Part I

Item 1. Business (continued)

The following table provides the status of customer choice programs in Washington Gas’ jurisdictions at September 30, 2014.

Participation in Customer Choice Programs
At September 30, 2014
Jurisdiction	Customer Class	Eligible Customers
		Total		% Participating
District of Columbia	Firm:
	Residential		143,268		12	%
	Commercial		12,539		33	%
	Interruptible		186		94	%
Maryland	Firm:
	Residential		424,152		22	%
	Commercial		29,906		43	%
	Interruptible		213		99	%
	Electric Generation		2		100	%
Virginia	Firm:
	Residential		477,873		10	%
	Commercial		28,660		32	%
	Interruptible		244		80	%
Total			1,117,043

When customers choose to purchase the natural gas commodity from unregulated third party marketers, Washington Gas’ net income is not affected because Washington Gas charges its customers the cost of gas without any mark-up. When customers select an unregulated third party marketer as their gas supplier, Washington Gas continues to charge these customers to deliver natural gas through its distribution system at rates identical to the delivery portion of the bundled sales service customers.

Competition

The Natural Gas Delivery Function

The natural gas delivery function, the core business of Washington Gas, continues to be regulated by local and state regulatory commissions. In developing this core business, Washington Gas has invested $ 4.3 billion as of September 30, 2014 to construct and operate a safe and reliable distribution system. Because of the high fixed costs and significant safety and environmental considerations associated with building and operating a distribution system, Washington Gas expects to continue being the only owner and operator of a distribution system in its current franchise area for the foreseeable future. The nature of Washington Gas’ customer base and the distance of most customers from interstate pipelines mitigate the threat of bypass of its facilities by other potential delivery service providers.

Competition with Other Energy Products

Washington Gas faces competition based on customers’ preference for other energy products and the prices of those products compared to natural gas. In the residential market, which generates a significant portion of Washington Gas’ net income, the most significant product competition occurs between natural gas and electricity. Because the cost of electricity is affected by the cost of fuel used to generate electricity, such as natural gas, Washington Gas generally maintains a price advantage over competitive electricity supply in its service area for traditional residential uses of energy such as heating, water heating and cooking. Washington Gas continues to attract the majority of the new residential construction market in its service territory, and consumers’ continuing preference for natural gas allows Washington Gas to maintain a strong market presence. The following table lists the new customer meters added by jurisdiction and major rate class for the year ended September 30, 2014.

New Customer Meters by Area
	Residential		Commercial and Interruptible		Group Meter Apartments		Total
Maryland		5,490		296		8		5,794
Virginia		5,600		404		4		6,008
District of Columbia		1,371		130		24		1,525
Total		12,461		830		36		13,327

In the interruptible market, fuel oil is the prevalent energy alternative to natural gas. Washington Gas’ success in this market depends largely on the relationship between natural gas and oil prices. The supply of natural gas primarily is derived from domestic sources, and the relationship between supply and demand generally has the greatest impact on natural gas prices. Since the source of a large portion of oil comes from foreign countries, political events and foreign currency conversion rates can influence oil supplies and prices to domestic consumers.

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WGL Holdings, Inc.

Washington Gas Light Company

Part I

Item 1. Business (continued)

RETAIL ENERGY-MARKETING SEGMENT

Description

The retail energy-marketing segment consists of the operations of WGEServices, which competes with regulated utilities and other unregulated third party marketers to sell natural gas and/or electricity directly to residential, commercial and industrial customers in Maryland, Virginia, Delaware, Pennsylvania and the District of Columbia. WGEServices buys natural gas and electricity with the objective of earning a profit through competitively priced sales contracts with end-users. These commodities are delivered to retail customers through the distribution systems owned by regulated utilities. Washington Gas is one of several utilities that delivers gas to/on behalf of WGEServices and unaffiliated electric utilities deliver all of the electricity sold. Additionally, WGEServices bills its customers either independently or through the billing services of the regulated utilities that deliver its commodities. Refer to Note 18—Related Party Transactions of the Notes to Consolidated Financial Statements for further discussion of our purchase of receivables program.

WGEServices also sells wind and other renewable energy credits and carbon offsets to retail customers. WGEServices does not own or operate any other natural gas, production, transmission or distribution assets.

At September 30, 2014, WGEServices served approximately 157,000 residential, commercial and industrial natural gas customer accounts and approximately 162,000 residential, commercial and industrial electricity customer accounts located in Maryland, Virginia, Delaware, Pennsylvania and the District of Columbia. Its customer concentration is such that the loss of any one customer or group of customers would not have a significant adverse effect on its business.

Factors critical to managing the retail energy-marketing segment include:

• managing the market risk of the difference between the price committed to customers under sales contracts and the cost of natural gas and electricity needed to satisfy these commitments, including capacity and transmission costs and costs to meet renewable portfolio standards;

• managing credit risks associated with customers and suppliers;

• having sufficient deliverability of natural gas and electric supplies and transportation to serve the demand of its customers which can be affected by the ability of natural gas producers, pipeline gatherers, natural gas processors, interstate pipelines, electricity generators and regional electric transmission operators to deliver the respective commodities;

• access to sources of financial liquidity;

• controlling the level of selling, general and administrative expenses, including customer acquisition expenses and

• the ability to access markets through customer choice programs or other forms of deregulation.

The retail energy-marketing segment’s total operating revenues from external customers were $1.3 billion for the fiscal years ended September 30, 2014, 2013, and 2012.

Seasonality of Business Operations

The operations of WGEServices are seasonal, with larger amounts of electricity being sold in the summer months and larger amounts of natural gas being sold in the winter months. Working capital requirements can vary significantly during the year and these variations are financed through internally generated funds and WGL’s issuance of commercial paper and unsecured short-term bank loans. WGEServices accesses these funds through the WGL money pool. For a discussion of the WGL money pool, refer to the section entitled “Money Pool” in Management’s Discussion and Analysis.

Natural Gas and Electricity Supply

On February 20, 2013, WGEServices entered into a five-year secured supply arrangement with Shell Energy North America (US), LP (Shell Energy). Under this arrangement, WGEServices has the ability to purchase the majority of its power, natural gas and related products from Shell Energy in a structure that reduces WGEServices’ cash flow risk from collateral posting requirements. While Shell is intended to be the majority provider of natural gas and electricity, WGEServices retains the right to purchase supply from other providers.

Natural gas supplies are delivered to WGEServices’ market territories through several interstate natural gas pipelines. To supplement WGEServices’ natural gas supplies during periods of high customer demand, WGEServices maintains gas storage inventory in storage facilities that are assigned by natural gas utilities such as Washington Gas. This storage inventory enables WGEServices to meet daily and monthly fluctuations in demand and to minimize the effect of market price volatility.

11

WGL Holdings, Inc.

Washington Gas Light Company

Part I

Item 1. Business (continued)

The PJM Interconnection (PJM) is a regional transmission organization that regulates and coordinates generation supply and the wholesale delivery of electricity in the states and jurisdictions where WGEServices operates. WGEServices buys wholesale and sells retail electricity in the PJM market territory, subject to its rules and regulations. PJM requires that its market participants have sufficient load capacity to serve their customers’ load requirements.

Competition

Natural Gas

WGEServices competes with regulated gas utilities and other third party marketers to sell natural gas to customers both inside and outside of the Washington Gas service area. Marketers of natural gas compete largely on price; therefore, gross margins are relatively small. To provide competitive pricing to its retail customers and in adherence to its risk management policies and procedures, WGEServices manages its natural gas contract portfolio by closely matching the commitments for gas deliveries from wholesale suppliers with requirements to serve retail sales customers. For a discussion of WGEServices’ exposure to and management of price risk, refer to the section entitled “Market Risk—Price Risk Related to the Retail Energy-Marketing Segment” in Management’s Discussion and Analysis.

Electricity

WGEServices competes with regulated electric utilities and other third party marketers to sell electricity to customers. Marketers of electric supply compete largely on price; therefore, gross margins are relatively small. To provide competitive pricing to its retail customers and in adherence to its risk management policies and procedures, WGEServices manages its electricity contract portfolio by closely matching the commitment for electricity deliveries from suppliers with requirements to serve sales customers. For a discussion of WGEServices’ exposure to and management of price risk, refer to the section entitled “Market Risk—Price Risk Related to the Retail Energy-Marketing Segment” in Management’s Discussion and Analysis.

WGEServices’ residential and small commercial electric customer growth opportunities are significantly affected by the price for Standard Offer Service (SOS) offered by electric utilities. These rates are periodically reset for each customer class based on the regulatory requirements in each jurisdiction. Customer growth opportunities either expand or contract due to the relationship of these SOS rates to current market prices.

COMMERCIAL ENERGY SYSTEMS SEGMENT

Description

The commercial energy systems segment consists of the operations of WGESystems, WGSW and the results of operations of affiliate owned commercial distributed energy projects. This segment focuses on clean and energy efficient solutions for its customers, driving earnings through (i) owning and operating distributed generation assets such as Solar Photovoltaic (solar PV) systems, combined heat and power plants, and natural gas fuel cells (ii) upgrading the mechanical, electrical, water and energy-related infrastructure of large governmental and commercial facilities by implementing both traditional and alternative energy technologies; and (iii) passive investments in residential and commercial retail solar PV companies. This segment has assets and activities in 15 different states and the District of Columbia.

12

WGL Holdings, Inc.

Washington Gas Light Company

Part I

Item 1. Business (continued)

As of September 30, 2014 and 2013, this segment owned $242.7 million and $87.8 million, respectively, of operating distributed generation assets, generating a total of 85,141 megawatts in fiscal year 2014 and 33,526 megawatts in fiscal year 2013, respectively. Additionally, as of September 30, 2014, there was $107.9 million of signed projects under construction. These assets drive revenue through individual purchased power agreements and the sale of renewable energy credits. As of September 30, 2014, the assets in service have generated $66.4 million in investment tax credits and clean energy grants. These credits and grants are recognized as reductions in expense by amortizing them over the useful life of the underlying assets, typically 30 years.

The commercial energy systems segment made up 36% of the total WGL expenditures for capital investments for the year ended September 30, 2014 as shown in the chart below:

Competition

There are many competitors in this business segment. Within the government sector, competitors primarily include companies contracting with customers under Energy Savings Performance Contracting (ESPC) as well as utilities providing services under Utility Energy Saving Contracts (UESC). In the renewable energy and distributed generation market, competitors primarily include other developers, tax equity investors, distributed generation asset owner firms and lending institutions. WGESystems competes on the basis of strong customer relationships developed over many years of implementing successful projects, developing and maintaining strong supplier relationships, and focusing in areas where it can bring relevant expertise.

Critical Factors

Factors critical to the success of the commercial energy systems segment include: (i) generating adequate sales commitments from the government and private sectors in the facility construction and retrofit markets; (ii) generating adequate sales commitments from distributed generation channel partners and customers; (iii) building a stable base of customer relationships; (iv) estimating and managing fixed-price contracts with contractors; (v) managing selling, general and administrative expenses; (vi) managing price and operational risk associated with distributed energy projects and (vii) successful operation and optimization of all commercial assets.

MIDSTREAM ENERGY SERVICES SEGMENT

Description

The Midstream Energy Services segment, which consists of the operations of WGL Midstream, engages in developing, acquiring, managing and optimizing natural gas storage and transportation assets. WGL Midstream enters into both physical and financial derivative transactions to mitigate risks while maximizing potential profits from the optimization of assets under its management. These derivatives may cause significant period-to-period volatility in earnings as recorded under GAAP; however, this volatility will not change the operating margins that WGL Midstream will ultimately realize from sales to customers or counterparties. WGL Midstream’s risk management policy requires it to closely match its forward physical and financial positions with its asset base, thereby minimizing its price risk exposure. For a discussion of WGL Midstream’s exposure to and management of price risk, refer to the section entitled “Market Risk—Price Risk Related to the Other Non-Utility Segment” in Management’s Discussion and Analysis.

WGL Midstream provides customized energy solutions to its customers and counterparties including producers, utilities, local distribution companies, power generators, wholesale energy suppliers, pipelines and storage facilities. In May 2013, WGL Midstream entered into an equity investment in Constitution Pipeline Company, LLC for an estimated $72.0 million. The pipeline is designed to transport at least 650,000 dekatherms of natural gas per day from the Marcellus region in northern Pennsylvania to major northeastern markets. In February 2014, WGL Midstream entered into an equity investment in a regulated pipeline project called Central Penn Pipeline (Central Penn) for an estimated $410.0 million. Central Penn will be an approximately 177-mile pipeline originating in Susquehanna County, Pennsylvania and extending to Lancaster County, Pennsylvania that will have the capacity to transport and deliver up to approximately 1.7 million dekatherms per day of natural gas. See Note 17—Other Investments for further details regarding these projects.

13

WGL Holdings, Inc.

Washington Gas Light Company

Part I

Item 1. Business (concluded)

Competition

WGL Midstream competes with other midstream infrastructure and energy services companies, wholesale energy suppliers, producers and other non-utility affiliates of regulated utilities for the acquisition of natural gas storage and transportation assets.

Critical Factors

Factors critical to the success of WGL Midstream’s operations include: (i) adhering to strong internal risk management policies; (ii) winning business in a competitive marketplace; (iii) managing credit risks associated with customers and counterparties; (iv) expertise in managing commodity markets; (v) accessing sources of financial liquidity and (vi) managing the level of general and administrative expenses.

OTHER ACTIVITIES

Activities and transactions that are not significant enough on a stand-alone basis to warrant treatment as an operating segment, and that do not fit into one of our other operating segments, are aggregated as “Other activities” and are included as part of non-utility operations in the operating segment financial information. Administrative and business development activity costs associated with WGL and Washington Gas Resources are included in this segment.

ENVIRONMENTAL MATTERS

We are subject to federal, state and local laws and regulations related to environmental matters. These laws and regulations may require expenditures over a long timeframe to control environmental effects. Almost all of the environmental liabilities we have recorded are for costs expected to be incurred to remediate sites where we or a predecessor affiliate operated manufactured gas plants (MGPs). Estimates of liabilities for environmental response costs are difficult to determine with precision because of the various factors that can affect their ultimate level. These factors include, but are not limited to, the following:

• the complexity of the site;

• changes in environmental laws and regulations at the federal, state and local levels;

• the number of regulatory agencies or other parties involved;

• new technology that renders previous technology obsolete or experience with existing technology that proves ineffective;

• the level of remediation required and

• variations between the estimated and actual period of time that must be dedicated to respond to an environmentally-contaminated site.

Washington Gas has identified up to ten sites where it or its predecessors may have operated MGPs. Washington Gas’ last use of an MGP was in 1984. In connection with these operations, we are aware that coal tar and certain other by-products of the gas manufacturing process are present at or near some former sites, and may be present at others. Based on the information available to us, we have concluded that none of the sites are likely to present an unacceptable risk to human health or the environment, and either the appropriate remediation is being undertaken, or Washington Gas believes no remediation is necessary. The impact of these matters is not expected to have a material effect on Washington Gas’ financial position, cash flows, capital expenditures, earnings or competitive position. See Note 12—Environmental Matters of the Notes to Consolidated Financial Statements for further discussion of environmental response costs.

OTHER INFORMATION

At September 30, 2014, we had 1,444 employees comprising 1,332 utility and 112 non-utility employees.

Our code of conduct, corporate governance guidelines, and charters for the governance, audit and human resources committees of the Board of Directors are available on the corporate Web site www.wglholdings.com under the “Corporate Governance” link, and any changes or amendments to these documents will also be posted to this section of our Web site. Copies may be obtained by request to the Corporate Secretary at WGL Holdings, Inc., 101 Constitution Ave., N.W., Washington, D.C. 20080. Also on the corporate web site is additional information about WGL Holdings and free access to our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and any amendments filed with or furnished to the Securities and Exchange Commission.

Our Chairman and Chief Executive Officer certified to the New York Stock Exchange (NYSE) on March 31, 2014 that, as of that date, he was unaware of any violation by WGL of the NYSE’s corporate governance listing standards.

Our research and development costs during fiscal years 2014, 2013 and 2012 were not material.

14

WGL Holdings, Inc.

Washington Gas Light Company

Part I

Item 1A. Risk Factors

ITEM 1A. RISK FACTORS

The risk factors described below should be read in conjunction with other information included or incorporated by reference in this annual report on Form 10-K, including an in-depth discussion of these risks in the section entitled “Management’s Discussion and Analysis of Financial Condition and Results of Operations.” The risks and uncertainties described below are not the only risks and uncertainties facing us that could adversely affect our results of operations, cash flows and financial condition.

WGL HOLDINGS, INC.

Our business may be adversely affected if we are unable to pay dividends on our common stock and principal and interest on our outstanding debt.

WGL is a holding company whose assets consist primarily of investments in subsidiaries. Accordingly, we conduct all of our operations through our subsidiaries. Our ability to pay dividends on our common stock and to pay principal and accrued interest on our outstanding debt depends on the payment of dividends to us by certain of our subsidiaries or the repayment of funds to us by our principal subsidiaries. The extent to which our subsidiaries do not pay dividends or repay funds to us may adversely affect our ability to pay dividends to holders of our common stock and principal and interest to holders of our debt.

If we are unable to access sources of liquidity or capital, or the cost of funds increases significantly, our subsidiaries’ businesses may be adversely affected.

Our ability to obtain adequate and cost effective financing depends on our credit ratings as well as the liquidity of financial markets. Our credit ratings depend largely on the financial performance of our subsidiaries, and a material downgrade in our current credit ratings to below investment grade could adversely affect our access to sources of liquidity and capital, as well as our borrowing costs.

We have credit risk that could adversely affect our results of operations, cash flows and financial condition.

We extend credit to counterparties. While we have prudent risk management policies in place, including credit policies, netting arrangements and margining provisions incorporated in contractual agreements, the risk exists that we may not be able to collect amounts owed to us.

Derivatives legislation and implementing rules could have an adverse impact on our ability to hedge risks associated with our business.

The Dodd-Frank Act regulates derivative transactions, which include certain instruments used in our risk management activities. The Dodd-Frank Act requires that most swaps be cleared through a registered clearing facility and traded on a designated exchange or swap execution facility with certain exceptions for entities that use swaps to hedge or mitigate commercial risk. Although the Dodd-Frank Act includes significant new provisions regarding the regulation of derivatives, the impact of those requirements have not been fully implemented by both the SEC and the Commodities Futures Trading Commission. The law and any new regulations could increase the operational and transactional cost of derivatives contracts and affect the number and/or creditworthiness of available counterparties.

Cyber attacks, including cyber-terrorism or other information technology security breaches, could disrupt our business operations and/or result in the loss or exposure of confidential or sensitive information.

Security breaches of our information technology infrastructure, including cyber attacks and cyber-terrorism, could lead to disruptions of our distribution or otherwise adversely impact our ability to safely operate our pipeline systems and serve our customers effectively. An attack on or failure of information technology systems could result in the unauthorized release of customer, employee or other confidential or sensitive data. The foregoing events could adversely affect our business reputation, diminish customer confidence, subject us to financial liability or increased regulation, increase our costs and expose us to material legal claims and liability and adversely affect our operations and financial results. WGL closely monitors both preventive and detective measures to manage these risks and maintains cyber risk insurance to mitigate a significant portion, but not all, of these risks and losses. To the extent that the occurrence of any of these cyber events is not fully covered by insurance, it could adversely affect WGL’s financial condition and results of operations.

Natural disasters and catastrophic events, including terrorist acts, may adversely affect our business.

Catastrophic events such as fires, earthquakes, explosions, floods, tornados, terrorist acts, or other similar occurrences could adversely affect Washington Gas’ facilities and operations. Washington Gas has emergency planning and training programs in place to respond to events that could cause business interruptions. However, unanticipated events or a combination of events, failure in resources needed to respond to events, or a slow or an inadequate response to events

15

WGL Holdings, Inc.

Washington Gas Light Company

Part I

Item 1A. Risk Factors (continued)

may have an adverse impact on the operations, financial condition, and results of operations of Washington Gas. The availability of insurance covering catastrophic events may be limited or may result in higher deductibles, higher premiums, and more restrictive policy terms.

WGEServices’ business, earnings and cash requirements are highly weather sensitive and seasonal.

The operations of WGEServices, our retail energy-marketing subsidiary, are weather sensitive and seasonal, with a significant portion of revenues derived from the sale of natural gas to retail customers for space heating during the winter months, and from the sale of electricity to customers for cooling during the summer months. Weather conditions directly influence the volume of natural gas and electricity delivered to customers. Weather conditions can also affect the short-term pricing of energy supplies that WGEServices may need to procure to meet the needs of its customers. Deviations in weather from normal levels and the seasonal nature of WGEServices’ business can create large variations in earnings and short-term cash requirements.

The ability of WGEServices to meet customers’ natural gas and electricity requirements may be impaired if contracted supply is not available or delivered in a timely manner.

Sufficient capability to deliver natural gas and electric supplies to serve the demand of WGEServices’ customers is dependent upon the ability of natural gas producers, pipeline gatherers, natural gas processors, interstate pipelines, suppliers of electricity and regional electric transmission operators to meet these requirements. If WGEServices is unable to secure adequate supplies in a timely manner, either due to the failure of its suppliers to deliver the contracted commodity or the inability to secure additional quantities during significant abnormal weather conditions, it may be unable to meet its customer requirements. Such inability to meet its delivery obligations to customers could result in WGEServices experiencing defaults on contractual terms with its customers, penalties and financial damage payments, the loss of certain licenses and operating authorities, and/or a need to return customers to the regulated utility companies, such as Washington Gas.

The risk management strategies and related hedging activities of WGEServices and WGL Midstream may not be effective in managing risks and may cause increased volatility in its earnings.

WGEServices and WGL Midstream are exposed to commodity price risk to the extent their natural gas and electricity commodity purchases and obligations are not closely matched to their sales commitments in terms of volume and pricing. In addition, WGEServices is exposed to pricing of certain ancillary services provided or required by the power pool in which it operates. WGEServices and WGL Midstream attempt to manage their exposure to commodity price risk, as well as their exposure to weather and delivery risks by hedging, setting risk limits, customer pricing terms and employing other risk management tools and procedures. These risk management activities may not be as effective as planned, and cannot eliminate all of WGEServices’ and WGL Midstream’s risks.

WGEServices and WGL Midstream rely on guarantees and access to cash collateral from WGL.

The ability of WGEServices to purchase natural gas and electricity from suppliers is partly dependent upon guarantees issued on its behalf by WGL, and upon access to cash collateral through the issuance of commercial paper and unsecured short-term bank loans by WGL. Likewise, the ability of WGL Midstream to purchase natural gas from suppliers is dependent upon guarantees issues on its behalf by WGL, and upon access to cash collateral through the issuance of commercial paper and unsecured short-term bank loans by WGL. Should WGL not renew such guarantees, provide access to cash collateral, or if WGL’s credit ratings are downgraded, the ability of WGEServices and WGL Midstream to make commodity purchases at reasonable prices may be impaired.

Regulatory developments may negatively affect WGEServices and WGL Midstream.

The regulations that govern the conduct of competitive energy marketers are subject to change as the result of legislation or regulatory proceedings. Changes in these regulatory rules could reduce customer growth opportunities for WGEServices, or could reduce the profit opportunities associated with certain groups of existing or potential new customers. In addition, WGL Midstream’s pipeline investments are subject to Federal Energy Regulatory Commission (FERC) regulation and approval. Should FERC deny or delay approval for the midstream projects or enact additional regulations related to these activities, Midstream is at risk of loss for those investments.

Competition may negatively affect WGEServices and WGL Midstream.

WGEServices competes with other non-regulated retail suppliers of natural gas and electricity, as well as with the commodity rate offerings of electric and gas utilities. Increases in competition including utility commodity rate offers that are below prevailing market rates may result in a loss of sales volumes or a reduction in growth opportunities. WGL Midstream competes with other midstream infrastructure and energy services companies, wholesale energy suppliers and other non-utility affiliates of regulated utilities for the acquisition of natural gas storage and transportation assets.

Investing in certain non-controlling interests in investments may limit our ability to manage risks associated with these investments.

We have, and may acquire additional, non-controlling interests in investments. We may not have the right or power to direct the management of these interests in investments. In addition, other participants may become bankrupt or have other economic or business objectives that could negatively impact our investments.

16

WGL Holdings, Inc.

Washington Gas Light Company

Part I

Item 1A. Risk Factors (continued)

Investments in renewable energy projects are subject to substantial risks and uncertainty.

Returns on investments in renewable energy projects depend upon current regulatory and tax incentives, which are subject to uncertainty with respect to their extent and future availability. As a result, investments in renewable energy projects face the risk that the current incentives will expire or become modified in the future thereby adversely affecting existing projects, economic performance and future potential for growth in this area.

Delays in the Federal Government budget appropriations may negatively impact WGESystems earnings.

The operations of WGESystems are sensitive to federal government agencies’ receipt of funding in a timely manner. A significant portion of revenues is derived from implementing projects related to energy efficiency and energy conservation measures for federal government agencies in the Washington DC metro area. Lack of timely funding of these federal agencies directly impacts completion of ongoing projects and the ability of WGESystems to obtain new contracts, and as a result will negatively impact earnings.

WGESystems’ earnings may be negatively impacted by the Solar Renewable Energy Credit (SREC) markets.

A significant portion of revenues of WGESystems is derived from the sale of SRECs produced as a result of owning and operating commercial distributed energy systems. SREC pricing is determined by the market in each of the states where the distributed energy systems are installed. Oversupply of the SRECs in any state as a result of overbuilding of distributed energy systems in the state will result in higher supply of SRECs than demand requires, which will negatively impact the price of SRECs. Any legislative change in a state that reduces renewable portfolio standards or alternative compliance payment requirements for renewable energy may negatively impact the price of SRECs.

Changes to the Federal Investment Tax Credit (ITC) Policies may negatively affect WGESystems’ and WGSW’s earnings.

Part of WGESystems and WGSW’s investment strategy for owning and operating energy assets and selling energy to customers is based on the current ITC provision in the tax code that allow WGL to reduce its tax burden by investing in renewable and alternative energy assets like distributed energy, ductless heat pumps and fuel cells. The current ITC provisions allow WGL to reduce its tax burden by the equivalent of up to 30% for every dollar invested in renewable energy assets. A reduction or elimination of the ITC tax provisions for renewable and alternative energy assets may have a negative impact on WGESystems’ and WGSW’s continued growth.

WASHINGTON GAS LIGHT COMPANY

Changes in the regulatory environment or unfavorable rate regulation, which can be affected by new laws or political considerations, may restrict or delay Washington Gas’ ability to earn a reasonable rate of return on its capital invested to provide utility service and to recover fully its operating costs.

Washington Gas is regulated by several regulatory commissions and agencies. These regulatory commissions generally have authority over many of the activities of Washington Gas’ business including, but not limited to, the rates it charges to its customers, the amount and type of securities it can issue, the nature of investments it can make, the nature and quality of services it provides, safety standards, collection practices and other matters. These regulators also may modify Washington Gas’ rates to change the level, type and methods that it utilizes to recover its costs, including the costs to acquire, store, transport and deliver natural gas. The actions of regulatory commissions may restrict or delay Washington Gas’ ability to earn a reasonable rate of return on invested capital and/or fully recover operating costs.

Washington Gas’ ability to meet customers’ natural gas requirements may be impaired if its contracted gas supplies and interstate pipeline and storage services are not available or delivered in a timely manner.

Washington Gas is responsible for acquiring sufficient natural gas supplies, interstate pipeline capacity and storage capacity to meet current and future customers’ annual and seasonal natural gas requirements. If Washington Gas is not able to maintain a reliable and adequate natural gas supply and sufficient pipeline capacity to deliver that supply, it may be unable to meet its customers’ requirements.

Washington Gas needs to acquire additional capacity to deliver natural gas on the coldest days of the year and it may not receive the necessary authorizations to do so in a timely manner.

Washington Gas needs to acquire additional interstate pipeline transportation or storage capacity and construct transmission and distribution pipe to deliver additional capacity into growth areas on our system. The availability of these options may be limited by market supply and demand, the timing of Washington Gas’ participation in new interstate pipeline construction projects and local permitting requirements as well as the acquisition of rights of way. This could cause an interruption in Washington Gas’ ability to satisfy the needs of some of its customers.

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Washington Gas Light Company

Part I

Item 1A. Risk Factors (continued)

Operating issues could affect public safety and the reliability of Washington Gas’ distribution system, which could materially affect Washington Gas’ results of operations, financial condition and cash flows.

Washington Gas’ business is exposed to operating issues that could affect the public safety and reliability of its distribution system. Operating issues such as leaks, mechanical problems and accidents could result in significant costs to Washington Gas’ business and loss of customer confidence. Washington Gas may be unable to recover from customers through the regulatory process all or some of these costs and earn its authorized rate of return on these costs.

The receipt of low HHC gas into Washington Gas’ distribution system may result in higher operating expenses and capital expenditures that may have a material effect on its financial condition, results of operations and cash flows, and may impact system safety.

An increase in the volume of natural gas that contains a low concentration of HHCs is likely to result in increased leaks in Washington Gas’ distribution system. Additional operating expenses and capital expenditures may be necessary to contend with the receipt of increased volumes of low HHC gas into Washington Gas’ distribution system if the current preventative and remedial measures to mitigate leaks in affected portions of Washington Gas’ distribution system are unsuccessful. These additional expenditures may not be recoverable or may not be recoverable on a timely basis from customers. Additionally, such operating expenses and capital expenditures may not be timely enough to mitigate the challenges posed by increased volumes of low HHC gas and could result in leakage in couplings at a rate that would compromise our ability to respond to these leaks in a timely manner, possibly affecting safety in portions of our distribution system.

Changes in the relative prices of alternative forms of energy may strengthen or weaken the competitive position of Washington Gas’ delivery service. If the competitive position of natural gas service weakens, it may reduce the number of or growth in natural gas customers in the future and negatively affect Washington Gas’ future cash flows and net income.

The price of natural gas delivery service that Washington Gas provides competes with the price of other forms of energy such as electricity, oil and propane. Changing prices of natural gas versus other sources of energy can cause the competitive position of our natural gas delivery service to improve or decline. A decline in the competitive position of natural gas service in relation to alternative energy sources can lead to fewer natural gas customers, lower volumes of natural gas delivered, lower cash flows and lower net income.

A decline in the economy may reduce net revenue growth and reduce future net income and cash flows.

A decline in the economy of the region in which Washington Gas operates might adversely affect Washington Gas’ ability to grow its customer base and collect revenues from existing customers, which may negatively affect net revenue growth and increase costs.

If Washington Gas is unable to access sources of liquidity or capital, or the cost of funds increases significantly, Washington Gas’ business may be adversely affected.

Washington Gas’ ability to obtain adequate and cost effective financing depends on its credit ratings as well as the liquidity of financial markets. Washington Gas’ credit ratings depend largely on its financial performance, and a downgrade in current credit ratings could adversely affect its access to sources of liquidity and capital, as well as its borrowing costs and ability to earn its authorized rate of return.

As a wholly owned subsidiary of WGL, Washington Gas depends solely on WGL to raise new common equity capital and contribute that common equity to Washington Gas. If WGL is unable to raise common equity capital, this also could adversely affect Washington Gas’ credit ratings and its ability to earn its authorized rate of return. An increase in the interest rates Washington Gas pays without the recognition of the higher cost of debt in rates charged to its customers would materially affect future net income and cash flows.

Washington Gas’ risk management strategies and related hedging activities may not be effective in managing its risks, and may result in additional liability for which rate recovery may be disallowed and cause increased volatility in its earnings.

Washington Gas’ business requirements expose it to commodity price, weather, credit and interest-rate risks. Washington Gas attempts to manage its risk exposure through regulatory recovery mechanisms, hedging, the use of risk limits and by employing other risk management tools and procedures. Risk management activities may not be as effective as planned, and cannot eliminate all risks. Washington Gas also may be exposed to additional liability should the anticipated revenue recovery of costs or losses incurred with certain of these risk management activities be subsequently excluded from the determination of revenues by a regulator.

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Washington Gas Light Company

Part I

Item 1A. Risk Factors (concluded)

Washington Gas’ facilities and operations may be impaired by cyber-attacks or acts of terrorism.

Washington Gas’ distribution, storage facilities and information technology infrastructure may be targeted by terrorist activities. Resulting damage could cause disruption of the ability to meet customer requirements. A security breach of Washington Gas’ information systems could impact the reliability of the distribution system or result in the theft of sensitive customer or employee information. Washington Gas closely monitors both preventive and detective measures to manage these risks and maintains cyber risk insurance to mitigate a significant portion, but not all, of these risks and losses. To the extent that the occurrence of any of these cyber events is not fully covered by insurance, it could adversely affect Washington Gas’ financial condition and results of operations.

Terrorist attacks may also disrupt capital markets and Washington Gas’ ability to raise capital. A terrorist attack on Washington Gas’ facilities or those of its natural gas suppliers or customers could result in a significant decrease in revenues or a significant increase in response costs. Washington Gas closely monitors both preventive and detective measures to manage these risks and maintains sabotage and terrorism insurance to mitigate a significant portion, but not all, of these risks and losses. To the extent that the occurrence of any of these terrorist events is not fully covered by insurance, it could adversely affect Washington Gas’ financial condition and results of operations.

Washington Gas may face certain regulatory and financial risks related to climate change legislation.

Future proposals to limit greenhouse gas (GHG) emissions, measured in carbon dioxide equivalent units, could adversely affect our operating and service costs and demand for our product. In the past, the United States Congress has considered legislative proposals to limit GHG emissions. Should future proposals become law, the adoption could increase utility costs and prices charged to utility customers.

Washington Gas may face certain regulatory and financial risks related to pipeline safety legislation.

A number of proposals to implement increased oversight over pipeline operations and increased investment in facilities to inspect pipeline facilities, upgrade pipeline facilities, or control the impact of a breach of such facilities are pending at the federal level. Additional operating expenses and capital expenditures may be necessary to remain in compliance with the increased federal oversight resulting from such proposals. While we cannot predict with certainty the extent of these expenses and expenditures or when they will become effective, the adoption of such proposals could result in significant additional costs to Washington Gas’ business. Washington Gas may be unable to recover from customers through the regulatory process all or some of these costs and its authorized rate of return on these costs.

ITEM 1B. UNRESOLVED STAFF COMMENTS

None.

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Washington Gas Light Company

Part I

Item 2. Properties

ITEM 2. PROPERTIES

At September 30, 2014, Washington Gas provided services in various areas of the District of Columbia, Maryland and Virginia, and held certificates of convenience and necessity, licenses and permits necessary to maintain and operate its properties and businesses. The regulated utility segment is the only segment where property, plant and equipment are significant assets.

Property, plant and equipment are stated at original cost, including labor, materials, taxes and overhead costs incurred during the construction period. Washington Gas calculates depreciation applicable to its utility gas plant in service primarily using a straight-line method over the estimated remaining life of the plant. The composite depreciation and amortization rate of the regulated utility was 2.77%, 2.86% and 2.87% during fiscal years 2014, 2013 and 2012, respectively, which included an allowance for estimated accrued non-legal asset removal costs (see Note 1 —Accounting Policies of the Notes to Consolidated Financial Statements).

At September 30, 2014, Washington Gas had approximately 565 miles of transmission mains, 12,713 miles of distribution mains and 12,761 miles of distribution services.

Washington Gas owns approximately 40 acres of land and three buildings (two completed in 2012 and one in 1970, respectively) at 6801, 6803 and 6805 Industrial Road in Springfield, Virginia. The Springfield site houses both operating and certain administrative functions of the utility. The old operations center is unused and is being marketed for sale. Washington Gas also holds title to land and buildings used as substations for its utility operations.

Washington Gas also has peak shaving facilities to enhance deliverability in periods of peak demand in the winter that consist of propane air plants in Springfield, Virginia (Ravensworth Plant) and Rockville, Maryland (Rockville Plant). At September 30, 2014, Washington Gas has the storage capacity for approximately 15.0 million gallons of propane for peak-shaving. Hampshire owns full and partial interests in, and operates underground natural gas storage facilities in Hampshire County, West Virginia. Hampshire accesses the storage field through 12 storage wells that are connected to an 18-mile transmission pipeline system. Concurrent with acquiring and protecting its storage rights, Hampshire has historically acquired certain exploration and development rights in West Virginia principally in the Oriskany Sandstone, the Marcellus Shale and other shale formations. These rights are predominately owned by lease and they are applicable to approximately 26,000 gross acres for the storage facilities of which 12,200 acres may be subject to exploration in addition to its storage function. Hampshire also operates a compressor station utilized to increase line pressure for injection of gas into storage. For fiscal year 2015, we estimate that the Hampshire storage facility has the capacity to supply approximately 4.2 billion cubic feet of natural gas to Washington Gas’ system for meeting winter season demands.

Washington Gas owns a 12-acre parcel of land located in Southeast Washington, D.C. Washington Gas entered into an agreement with a national developer to develop this land in phases. Washington Gas selected the developer to design, execute and manage the various phases of the development. The development, Maritime Plaza, is intended to be a mixed-use commercial project that will be implemented in five phases. The first two phases have been developed, with Washington Gas retaining a 99-year ground lease on each phase. See the section entitled “Environmental Matters” under Item 1 of this report for additional information regarding this development.

In addition, WGESystems owns 63.25 megawatts of installed solar capacity in 15 different states and the District of Columbia at September 30, 2014.

Facilities utilized by our corporate headquarters, as well as by the retail energy-marketing and commercial energy systems segments, are located in the Washington, D.C. and Baltimore metropolitan area and are leased.

The Mortgage of Washington Gas dated January 1, 1933 (Mortgage), as supplemented and amended, securing any First Mortgage Bonds (FMBs) it issues, constitutes a direct lien on substantially all property and franchises owned by Washington Gas other than a small amount of property that is expressly excluded. At September 30, 2014 and 2013, there was no debt outstanding under the Mortgage.

Washington Gas executed a supplemental indenture to its unsecured Medium-Term Note (MTN) indenture on September 1, 1993, providing that Washington Gas will not issue any FMBs under its Mortgage without also securing all MTNs with all other debt secured by the Mortgage.

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WGL Holdings, Inc.

Washington Gas Light Company

Part I

Item 3. Legal Proceedings

ITEM 3. LEGAL PROCEEDINGS

The nature of our business ordinarily results in periodic regulatory proceedings before various state and federal authorities. For information regarding pending federal and state regulatory matters, see Note 13—Commitments and Contingencies of the Notes to Consolidated Financial Statements for further discussion.

As previously disclosed, WGL has been cooperating with a Department of Justice (“the Department”) investigation of some of the federal contracting activities of one of its non-utility subsidiaries, WGESystems. The Department’s investigation concerned certain American Recovery and Reinvestment Act projects bid out by the General Services Administration in 2010, in which WGESystems participated as a subcontractor to an 8(a) prime contractor under the Small Business Administration’s 8(a) Business Development Program. On November 18, 2014, WGESystems entered into a deferred prosecution agreement with the Department, which will resolve the investigation. The agreement is for a two-year period, and the Department will not pursue the prosecution of WGESystems if WGESystems discharges its obligations under the agreement during the two-year term of the agreement. Pursuant to the agreement, WGESystems will pay fines and monetary penalties totaling $2,587,261 to the Department and implement and maintain certain remedial measures specified in the agreement.

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Washington Gas Light Company

Part I

Item 4. Mine Safety

ITEM 4. MINE SAFETY DISCLOSURES

Not Applicable.

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Washington Gas Light Company

Part I

EXECUTIVE OFFICERS OF THE REGISTRANTS

The names, ages and positions of the executive officers of the registrants at October 31, 2014, are listed below along with their business experience during the past five years. The age of each officer listed is as of the date of filing of this report. There is no family relationship among the officers.

Unless otherwise indicated, all officers have served continuously since the dates indicated, and all positions are executive officers listed with Washington Gas Light Company.

Executive Officers
Name, Age and Position with the registrants	Date Elected or Appointed
Vincent L. Ammann, Jr., Age 55 (1)
Senior Vice President and Chief Financial Officer	October 1, 2013
Vice President and Chief Financial Officer	September 30, 2006
Gautam Chandra, Age 48 (1)
Senior Vice President—Strategy, Business Development and Non-Utility Operations	October 1, 2014
Vice President—Business Development, Strategy and Non-Utility Operations	October 1, 2011
Vice President—Business Development, Strategy and Business Process Outsourcing and Non-Utility Operations	October 1, 2009
Adrian P. Chapman, Age 57 (1)
President and Chief Operating Officer	October 1, 2009
William R. Ford, Age 59 (1)
Vice President and Chief Accounting Officer	October 1, 2013
Controller	October 1, 2010
Division Head—Assistant Controller	January 26, 2009
Marcellous P. Frye, Jr., Age 46
Vice President—Support Services	March 21, 2008
Luanne S. Gutermuth, Age 52
Senior Vice President—Shared Services and Chief Human Resource Officer	October 1, 2014
Vice President—Human Resources and Organization Development	October 1, 2010
Division Head—Consumer Services	July 31, 2008
Louis J. Hutchinson, III, Age 49 (3)
Vice President and Chief Revenue Officer	October 1, 2014
Mark A. Lowe, Age 51
Vice President—Gas Supply and Engineering	October 1, 2014
Division Head—Gas Supply	March 10, 2008
Terry D. McCallister, Age 58 (1)
Chairman of the Board and Chief Executive Officer	October 1, 2009
Anthony M. Nee, Age 58 (1)
Vice President and Treasurer	October 1, 2013
Treasurer	February 14, 2009
Roberta W. Sims, Age 60
Vice President—Rates and Regulatory Affairs	October 1, 2014
Vice President—Regulatory Affairs and Energy Acquisition	October 1, 2009
Douglas A. Staebler, Age 54
Senior Vice President—Utility Operations	October 1, 2014
Vice President—Operations, Engineering, Construction and Safety	October 31, 2006
Leslie T. Thornton, Age 56 (1,2)
Senior Vice President—General Counsel and Corporate Secretary	October 1, 2014
Vice President and General Counsel	January 1, 2012
Counsel to the Chairman	November 28, 2011
Tracy L. Townsend, Age 48
Vice President—Construction, Compliance and Safety	October 1, 2014
Division Head—Safety, Compliance, Construction Operations Support and Technology	October 1, 2010
Division Head—Construction and Field Operations	October 1, 2009

⁽¹⁾ At September 30, 2014, Executive Officer of both WGL Holdings, Inc. and Washington Gas Light Company.

⁽²⁾ Ms. Thornton was previously a partner at Dickstein Shapiro, LLP where she managed sensitive internal corporate, federal government and state attorney general investigations.

⁽³⁾ Mr. Hutchinson was previously a Senior Vice President at Constellation Energy where he led sales and marketing for the public sector and energy efficiency business lines.

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WGL Holdings, Inc.

Part II

Item 5. Market for Registrant’s Common Equity, Related

Stockholder Matters and Issuer Purchases of Equity Securities

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

At October 31, 2014, WGL had 9,980 common shareholders of record. During fiscal years 2014 and 2013, WGL’s common stock was listed for trading on the New York Stock Exchange and was shown under the ticker symbol “WGL.” We did purchase some of our outstanding common stock during fiscal year 2014. We had no restrictions on dividends during fiscal years 2014 or 2013. The table below shows quarterly price ranges and quarterly dividends paid for the fiscal years ended September 30, 2014 and 2013.

Common Stock Price Range and Dividends Paid
	High		Low		Dividends Paid    Per Share		Dividend Payment Date
Fiscal Year 2014
Fourth quarter	$	44.71	$	37.77	$	0.4400	8/1/2014
Third quarter		43.12		37.94		0.4400	5/1/2014
Second quarter		40.72		35.35		0.4200	2/1/2014
First quarter		45.65		37.96		0.4200	11/1/2013
Fiscal Year 2013
Fourth quarter	$	46.96	$	40.00	$	0.4200	8/1/2013
Third quarter		46.22		41.16		0.4200	5/1/2013
Second quarter		44.30		38.30		0.4000	2/1/2013
First quarter		40.33		35.96		0.4000	11/1/2012

The following table provides information about purchases of our equity securities during the quarter ended September 30, 2014.

Issuer Purchases of Equity Securities
Period	Total number of   shares purchased		Average price paid per share		Total number of shares purchased as part of publicly announced plans or programs		Maximum number of shares (or approximate dollar value) that may yet be purchased under the plans or programs  (a)
07/01/14 - 07/31/14		-	$	-		-	$	-
08/01/14 - 08/31/14		403,199	$	42.54		403,199	$	150,000,000
09/01/14 - 09/30/14		901,305	$	43.34		901,305	$	150,000,000
Total		1,304,504	$	43.12		1,304,504	$	150,000,000

^(a) The share repurchase program was approved by the Board of Directors and announced on August 7, 2014 to repurchase WGL’s common stock up to an amount of $150 million. The shares may be repurchased in the open market or in privately negotiated transactions. The repurchase program is authorized for a two year period. During the quarter ended September 30, 2014, we repurchased 1.3 million shares of common stock at a total cost of approximately $56.1 million. This amount reflects the total since the program’s inception.

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Part II

Item 6. Selected Financial Data

ITEM 6. SELECTED FINANCIAL DATA

The following table presents selected financial data for WGL derived from our financial statements as of and for the last five fiscal years. The information should be read in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and the audited Consolidated Financial Statements and the Notes to the Consolidated Financial Statements.

(In thousands, except per share data)
Years Ended September 30,	2014		2013		2012		2011		2010
SUMMARY OF EARNINGS
Operating Revenues
Utility	$	1,416,951	$	1,174,724	$	1,109,355	$	1,264,580	$	1,297,786
Non-utility		1,363,996		1,291,414		1,315,955		1,486,921		1,411,090
Total operating revenues	$	2,780,947	$	2,466,138	$	2,425,310	$	2,751,501	$	2,708,876
Income from continuing operations	$	105,940	$	80,253	$	139,818	$	117,050	$	109,885
COMMON STOCK DATA
Earnings per average share:
Basic	$	2.05	$	1.55	$	2.71	$	2.29	$	2.17
Diluted	$	2.05	$	1.55	$	2.71	$	2.28	$	2.16
Dividends declared per share	$	1.7400	$	1.6600	$	1.5875	$	1.5400	$	1.5000
Shares outstanding—year end (thousands)		50,657		51,774		51,612		51,365		50,975
CAPITALIZATION-YEAR END
Common shareholders’ equity	$	1,246,576	$	1,274,545	$	1,269,556	$	1,202,715	$	1,153,395
Washington Gas Light Company preferred stock		28,173		28,173		28,173		28,173		28,173
Long-term debt, excluding current maturities		679,228		524,067		589,202		587,213		592,875
Total capitalization	$	1,953,977	$	1,826,785	$	1,886,931	$	1,818,101	$	1,774,443
OTHER FINANCIAL DATA
Property, plant and equipment-net—year-end	$	3,314,445	$	2,907,463	$	2,667,413	$	2,489,901	$	2,346,208
Total assets—year-end	$	4,856,499	$	4,260,060	$	4,110,947	$	3,809,034	$	3,643,894

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Washington Gas Light Company

Part II

Item 6. Selected Financial Data

ITEM 6. SELECTED FINANCIAL DATA

The following table presents selected financial data for Washington Gas derived from the financial statements as of and for the last five fiscal years. The information should be read in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and the audited Consolidated Financial Statements and the Notes to the Consolidated Financial Statements.

(In thousands, except per share data)
Years Ended September 30,	2014			2013			2012			2011			2010
SUMMARY OF EARNINGS
Operating Revenues
Utility	$	1,443,800		$	1,200,357		$	1,137,666		$	1,288,539		$	1,321,446
Non-utility		-			-			-			-			75
Total operating revenues	$	1,443,800		$	1,200,357		$	1,137,666		$	1,288,539		$	1,321,521
Income from continuing operations	$	97,004		$	71,002		$	108,726		$	68,270		$	101,029
CAPITALIZATION-YEAR END
Common shareholder’s equity	$	1,050,166		$	1,024,583		$	1,025,743		$	990,135		$	994,876
Preferred stock		28,173			28,173			28,173			28,173			28,173
Long-term debt, excluding current maturities		679,228			524,067			589,202			587,213			592,875
Total capitalization	$	1,757,567		$	1,576,823		$	1,643,118		$	1,605,521		$	1,615,924
OTHER FINANCIAL DATA
Property, plant and equipment-net—year-end	$	3,022,064		$	2,724,882		$	2,574,396		$	2,448,574		$	2,329,528
Total assets—year-end	$	3,965,078		$	3,474,389		$	3,503,265		$	3,379,048		$	3,270,276
UTILITY GAS SALES AND DELIVERIES (thousands of therms)
Gas sold and delivered
Residential firm		738,963			660,424			540,206			677,558			662,357
Commercial and industrial
Firm		200,153			180,942			149,515			179,207			170,534
Interruptible		2,193			2,897			2,042			2,573			3,649
Total gas sold and delivered		941,309			844,263			691,763			859,338			836,540
Gas delivered for others
Firm		535,503			488,182			436,698			501,187			481,099
Interruptible		267,705			270,884			243,031			271,421			267,823
Electric generation		144,403			177,533			343,315			140,557			172,995
Total gas delivered for others		947,611			936,599			1,023,044			913,165			921,917
Total utility gas sales and deliveries		1,888,920			1,780,862			1,714,807			1,772,503			1,758,457
OTHER STATISTICS
Active customer meters—year-end		1,117,043			1,105,123			1,094,109			1,082,983			1,073,722
New customer meters added		13,327			12,468			11,250			9,868			10,563
Heating degree days—actual		4,111			3,769			3,036			3,999			3,825
Weather percent colder (warmer) than normal		9.6	%		(0.2	)%		(20.1	)%		6.1	%		1.6	%

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Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations

ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

INTRODUCTION

This Management’s Discussion and Analysis of Financial Condition and Results of Operations (Management’s Discussion) analyzes the financial condition, results of operations and cash flows of WGL and its subsidiaries. It also includes management’s analysis of past financial results and potential factors that may affect future results, potential future risks and approaches that may be used to manage them. Except where the content clearly indicates otherwise, “WGL,” “we,” “us” or “our” refers to the holding company or the consolidated entity of WGL Holdings, Inc. and all of its subsidiaries.

Management’s Discussion is divided into the following two major sections:

• WGL—This section describes the financial condition and results of operations of WGL Holdings, Inc. and its subsidiaries on a consolidated basis. It includes discussions of our regulated operations, including Washington Gas and Hampshire Gas Company (Hampshire), and our non-utility operations.

• Washington Gas—This section describes the financial condition and results of operations of Washington Gas, a subsidiary of WGL, which comprises the majority of the regulated utility segment.

Both sections of Management’s Discussion—WGL and Washington Gas—are designed to provide an understanding of our operations and financial performance and should be read in conjunction with the respective company’s financial statements and the combined Notes to Consolidated Financial Statements in this annual report.

Unless otherwise noted, earnings per share amounts are presented on a diluted basis, and are based on weighted average common and common equivalent shares outstanding.

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Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

Management’s Discussion Table of Contents

	Page
Executive Overview		28
Primary Factors Affecting WGL Holdings and Washington Gas		29
Critical Accounting Policies		34
WGL Holdings, Inc.
Results of Operations		38
Liquidity and Capital Resources		45
Contractual Obligations, Off-Balance Sheet Arrangements and Other Commercial Commitments		53
Credit Risk		56
Market Risk		58
Washington Gas Light Company
Results of Operations		64
Liquidity and Capital Resources		66
Rates and Regulatory Matters		67

EXECUTIVE OVERVIEW

Introduction

WGL, through its subsidiaries, sells and delivers natural gas and provides a variety of energy-related products and services to customers primarily in the District of Columbia and the surrounding metropolitan areas in Maryland and Virginia. In addition to our primary markets, WGL’s non-utility subsidiaries provide customized energy solutions across a much wider footprint, with business activities in 31 states and the District of Columbia.

WGL has four operating segments:

• regulated utility;

• retail energy-marketing;

• commercial energy systems; and

• midstream energy services.

Regulated Utility Operating Segment

The regulated utility operating segment is composed of our core subsidiary, Washington Gas. Washington Gas engages in the delivery and sale of natural gas that is regulated by regulatory commissions in the District of Columbia, Maryland and Virginia. Over the past fiscal year, our utility customer base continued to grow as we added approximately 12,000 active customer meters, representing a 1.1% growth rate. During the winter heating season, Washington Gas’ territory experienced record cold spikes, resulting in nine of the top 25 days of send out. The company’s distribution operated safely and continuously during these extreme conditions. The extreme weather also created significant opportunities for asset optimization activities, driving additional returns shared both with customers and shareholders. Finally, we now have implemented accelerated replacement plans in all three of our utility jurisdictions and we are successfully executing on these plans to invest in the safety and reliability of our utility system.

Through the wholly owned unregulated subsidiaries of Washington Gas Resources, we offer energy-related products and services through three different operating segments.

Retail Energy-Marketing Operating Segment

We offer competitively priced natural gas, electricity and energy from renewable sources to customers through WGEServices, our non-utility retail energy-marketing subsidiary. Our retail electric business has been a challenge for us this fiscal year, as electricity prices on the PJM Interconnection unexpectedly increased due to the extremely cold winter of 2014 coupled with higher capacity and ancillary charges. While our gas margins improved, the lower electricity margins more than offset these gains. We project the retail business will return to historical levels of profitability in coming years as cost structures stabilize and are fully reflected in market pricing.

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WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

Commercial Energy Systems Operating Segment

We offer efficient and sustainable commercial energy solutions focused on owning and operating distributed generation assets such as Solar Photovoltaic (Solar PV) systems through WGESystems and WGSW and upgrading energy related systems of large government and commercial facilities. This segment had a particularly strong fiscal year, with earnings growth driven by the investments we have made in distributed generation assets now in place across the country. One noteworthy installation is the 2.6 megawatt Bloom Energy natural gas fuel cell project in Santa Clara, California. This project, designed to provide earnings through a 20-year power purchase agreement, underscores WGESystems commitment to creating long-term earnings through distributed generation. As of September 30, 2014, we have over 60 megawatts in installed solar capacity and 3.4 megawatts of installed fuel cell capacity.

Midstream Energy Services Operating Segment

WGL Midstream engages in acquiring and optimizing natural gas storage and transportation assets. This was a successful fiscal year as extremely cold weather led to increased natural gas flow volumes and higher market prices such that the Midstream business was able to generate attractive margins from its portfolio of low-cost storage and transportation assets. In addition, the 2014 winter demonstrated the need for additional infrastructure to transport natural gas from the supply areas to market areas in the Northeast and Mid-Atlantic. During the fiscal year, WGL Midstream began to address this need and continued to execute its long-term strategy of investing in pipeline assets through its ownership interest in the Central Penn pipeline project.

Other Activities

Activities and transactions that are not significant enough on a stand-alone basis to warrant treatment as an operating segment, and that do not fit into one of our four operating segments, are aggregated as “Other Activities” and are included as part of non-utility operations. Administrative and business development costs associated with WGL and Washington Gas Resources are also included in “Other activities.” Fiscal years 2013 and 2014 results also included significant non-recurring legal expenses.

Overall, we remain confident about future earnings growth. This growth is primarily due to strong performance at our utility driven by disciplined cost control, asset optimization opportunities, higher infrastructure investment, and a lower effective tax rate. We also continue to see encouraging signs of economic growth and success on our marketing strategies.

Refer to the Business section under Item 1 of this report for further discussion of our regulated utility and non-utility business segments. For further discussion of our financial performance by operating segment, refer to Note 16 —Operating Segment Reporting of the Notes to Consolidated Financial Statements.

PRIMARY FACTORS AFFECTING WGL AND WASHINGTON GAS

The following is a summary of the primary factors that affect the operations and/or financial performance of our regulated and unregulated businesses. Refer to the sections entitled “Business” and “Risk Factors” under Item 1 and Item 1A, respectively, of this report for additional discussion of these and other factors that affect the operations and/or financial performance of WGL and Washington Gas.

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WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

Weather Conditions and Weather Patterns

Washington Gas.  Washington Gas’ operations are seasonal, with a significant portion of its revenues derived from the delivery of natural gas to residential and commercial heating customers during the winter heating season. Weather conditions directly influence the volume of natural gas delivered by Washington Gas. Weather patterns tend to be more volatile during “shoulder” months within our fiscal year in which Washington Gas is going into or coming out of the primary portion of its winter heating season. During the shoulder months within quarters ending December 31 (particularly in October and November) and June 30 (particularly in April and May), customer heating usage may not highly correlate with historical levels or with the level of heating degree days (HDDs) that occur, particularly when weather patterns experienced are not consistently cold or warm.

Washington Gas’ rates are determined on the basis of expected normal weather conditions. Washington Gas has weather protection strategies that are designed to minimize the estimated financial effects of variations from normal weather. Refer to the section entitled “Market Risk—Weather Risk” for a further discussion of Washington Gas’ weather protection strategies.

WGEServices.  The financial results of our retail energy-marketing subsidiary, WGEServices, are also affected by deviations in weather from normal levels and abnormal customer usage during the shoulder months described above. Because WGEServices sells natural gas and electricity, its financial results may fluctuate due to unpredictable deviations in weather during the winter heating and summer cooling seasons. WGEServices purchases weather-related instruments to help manage this risk. Refer to the section entitled “Market Risk—Weather Risk” for further discussion of WGEServices’ weather-related instruments.

WGL Midstream.  Variations from normal weather may also affect the financial results of our wholesale energy business, WGL Midstream, primarily with regards to storage injections, withdrawals and associated futures transactions as well as the pricing of point to point transportation transactions throughout the fiscal year. WGL Midstream manages these weather risks with, among other things, physical and financial hedging. Refer to the section entitled “Market Risk—Weather Risk” for further discussion of WGL Midstream’s weather-related instruments.

Regulatory Environment, Regulatory Decisions and Changes in Legislation

Washington Gas is regulated by the PSC of DC, the PSC of MD and the SCC of VA.

WGEServices is subject to regulation by the public service regulatory commissions of the states in which the company is authorized as a competitive service provider. These regulatory commissions: (i) authorize WGEServices to provide service, review certain terms and conditions of service and (ii) establish the regulatory rules for interactions between the utility and the competitive service provider. In addition, these regulatory commissions issue orders and promulgate rules that establish the broad structure and conduct of retail energy markets. Changes to the rules, rates and orders by the regulatory commissions may affect Washington Gas’ and WGEServices’ financial performance.

WGL has completed an internal assessment in preparation for the Dodd-Frank Act (the Act) and its requirements. WGL’s determination is that none of its entities, either separately or in the aggregate, will be classified as swap dealers or major swap participants under the Act.

Availability of Natural Gas Supply and Pipeline Transportation and Storage Capacity

Washington Gas.  Washington Gas must contract for reliable and adequate supplies as well as delivery capacity to its distribution system, while considering: (i) the dynamics of the commodity supply and interstate pipeline and storage capacity markets; (ii) its own on-system natural gas peaking facilities and (iii) the characteristics of its customer base. Energy-marketing companies that sell natural gas to customers located within Washington Gas’ service territory are responsible for acquiring natural gas for their customers; however, Washington Gas allocates certain storage and pipeline capacity related to these customers in accordance with regulatory requirements.

The increase in demand for pipeline and storage capacity compared to the available capacity is a business issue for local distribution companies, such as Washington Gas. To help maintain the adequacy of pipeline and storage capacity

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WGL Holdings, Inc.

Washington Gas Light Company

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Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

for its growing customer base, Washington Gas has contracted with various interstate pipeline and storage companies for expanded transportation and storage capacity services. The last of these capacity expansion projects is expected to be placed into service during fiscal year 2016. Washington Gas will continue to monitor other opportunities to acquire or participate in additional pipeline and storage capacity that will support customer growth and improve or maintain the high level of service expected by its customer base.

WGEServices.  WGEServices contracts for storage and pipeline capacity to meet its customers’ needs primarily through transportation releases and storage services allocated from the utility companies in the various service territories in which it provides retail energy commodity.

WGL Midstream.  WGL Midstream contracts for storage and pipeline capacity in its asset optimization activities through both long term contracts and short term transportation releases. WGL Midstream also contracts for physical natural gas supply on both a long term and short term basis.

Diversity of Natural Gas Supply

Washington Gas.  An objective of Washington Gas’ supply sourcing strategy is to diversify receipts from multiple production areas to meet all firm customers’ natural gas supply requirements. This strategy is designed to protect Washington Gas’ receipt of supply from being curtailed by possible financial difficulties of a single supplier, natural disasters and other unforeseen events, and to take advantage of competitive commodity prices associated with natural gas supplies.

WGEServices.  WGEServices has the ability to purchase the majority of its natural gas from Shell Energy under a five-year secured supply arrangement but maintains the right to purchase supply from other providers to meet demand. To supplement WGEServices’ natural gas supplies during periods of high customer demand, WGEServices maintains gas inventories in storage facilities that are allocated by natural gas utilities such as Washington Gas.

WGL Midstream.  WGL Midstream buys and sells wholesale natural gas across a diversified base of counterparties. WGL Midstream’s activities are also diversified across many liquid regional markets across the United States.

Volatility of Natural Gas and Electricity Prices

Volatility of natural gas and electricity prices impacts the regulated utility segment and the non-utility segments as described below.

Washington Gas.  Under its regulated gas cost recovery mechanisms, Washington Gas records cost of gas expense equal to revenue from customers associated with this cost for each period reported. Consequently, an increase in the cost of gas due to an increase in the purchase price of the natural gas commodity generally has no short-term direct effect on Washington Gas’ net income.

However, to the extent Washington Gas does not have regulatory mechanisms in place to mitigate the indirect effects of higher gas prices, its net income may decrease for factors such as: (i) lower natural gas consumption caused by customer conservation; (ii) increased short-term interest expense to finance a higher natural gas storage and accounts receivables balances and (iii) higher expenses for uncollectible accounts.

WGEServices.  WGEServices may be positively or negatively affected indirectly by significant changes in the wholesale price of natural gas and electricity. WGEServices’ risk management policies and procedures are designed to minimize the risk that WGEServices’ purchase commitments and the related sales commitments do not closely match (refer to the section entitled “Market Risk” for further discussion of WGEServices’ mitigation of commodity price risk). Additionally, in the short-term, volatile energy prices may change the costs associated with uncollectible accounts, borrowing costs, certain fees paid to public service commissions and other costs. To the extent that cost increases cannot be recovered from retail customers due to competitive factors, WGEServices’ operating results would be negatively affected.

WGL Midstream.  WGL Midstream can be positively or negatively affected by significant volatility in the wholesale price of natural gas. WGL Midstream risk management policies and procedures are designed to minimize the risk that purchase commitments and the related sale commitments do not closely match. In general, opportunities for asset optimization activities are increased for WGL Midstream with increased volatility in natural gas prices. These opportunities are primarily in short term transportation and storage spreads, seasonal storage spreads and long term supply or basis transactions.

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WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

Non-Weather Related Changes in Natural Gas Consumption Patterns

Natural gas supply requirements for the utility are affected by changes in the natural gas consumption patterns of our customers that are driven by factors other than weather. Natural gas usage per customer may decline as customers change their consumption patterns in response to: (i) more volatile and higher natural gas prices, as discussed above; (ii) customer upgrades to more energy efficient appliances and (iii) a decline in the economy in the region in which we operate.

For each jurisdiction in which Washington Gas operates, changes in customer usage profiles are reflected in rate case proceedings and rates are adjusted accordingly. Changes in customer usage by existing customers that occur subsequent to rate case proceedings in the Maryland jurisdiction generally will not change revenues because the RNA mechanism stabilizes the level of delivery charge revenues received from customers.

In Virginia, decoupling rate mechanisms for residential, small commercial and industrial and group metered apartment customers permit Washington Gas to adjust revenues for non-weather related changes in customer usage. The WNA and the CRA are billing mechanisms that eliminate the effects of both weather and other factors such as conservation.

In the District of Columbia, decreases in existing customer usage that occur subsequent to Washington Gas’ most recent rate case proceeding will have the effect of reducing revenues, which may be offset by additions of new customers.

Maintaining the Safety and Reliability of the Natural Gas Distribution System

Maintaining and improving the public safety and reliability of Washington Gas’ distribution system is our highest priority providing benefits to both customers and investors through improved customer service. Washington Gas continually monitors and reviews changes in requirements of the codes and regulations that govern the operation of the distribution system and refines its safety practices, with a particular focus on design, construction, maintenance, operation, replacement, inspection and monitoring practices to meet or exceed these requirements. Significant changes in regulations can impact the cost of operating and maintaining the system. Operational issues that affect public safety and the reliability of Washington distribution system that are not addressed within a timely and adequate manner could adversely affect our future earnings and cash flows, as well as result in a loss of customer confidence.

Competitive Environment

Washington Gas.  Washington Gas faces competition based on customers’ preference for natural gas compared to other energy products, and the comparative prices of those products. The most significant product competition occurs between natural gas and electricity in the residential market. Changes in the competitive position of natural gas relative to electricity and other energy products have the potential of causing a decline in the number of future natural gas customers. At present, Washington Gas has seen no significant evidence that changes in the competitive position of natural gas has contributed to such a decline.

The residential market generates a significant portion of Washington Gas’ net income. In its service territory, Washington Gas continues to attract the majority of the new residential construction market. Consumers’ continuing preference for natural gas allows Washington Gas to maintain a strong market presence.

In each of the jurisdictions served by Washington Gas, regulators and utilities have implemented customer choice programs to purchase natural gas. These programs allow customers the choice of purchasing their natural gas from unregulated third party marketers, rather than from the local utility. There is no direct effect on Washington Gas’ net income when customers purchase their natural gas commodity from unregulated third party marketers because Washington Gas charges its customers the cost of gas without any mark-up. The transfer of sales customers to third party marketers does reduce the level of investment in storage inventory, thereby lowering our recovery of carrying charges.

WGEServices.  WGEServices competes with regulated utilities and other unregulated third party marketers to sell the natural gas and electric commodity to customers. Marketers of these commodities compete largely on price; therefore, gross margins are relatively small. WGEServices is exposed to certain credit and market risks associated with both its natural gas and electric supply (refer to the sections entitled “Credit Risk” and “Market Risk” for further discussion of these risk exposures and how WGEServices manages them).

WGEServices’ electric sales growth opportunities are significantly affected by the price for Standard Offer Service (SOS) offered by electric utilities. These rates, often identified by customer class, are periodically reset based on the regulatory requirements in each jurisdiction. Future opportunities to add new electric customers will be dependent on the competitiveness of WGEServices’ rates relative to SOS rates offered by local electric utilities as well as the prices offered by other energy marketers.

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WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

WGL Midstream.  WGL Midstream competes in the wholesale natural gas markets with other third party wholesale marketers to buy and sell natural gas as well as storage and pipeline capacity. Marketers of these commodities compete largely on price; therefore, gross margins are relatively small. WGL Midstream is exposed to certain credit and market risks associated with its asset optimization activities (refer to the sections entitled “Credit Risk” and “Market Risk” for further discussion of these risk exposures and how WGL Midstream manages them).

Environmental Matters

We are subject to federal, state and local laws and regulations related to environmental matters. These evolving laws and regulations may require expenditures over a long timeframe. It is our position that, at this time, the appropriate remediation is being undertaken at all the relevant sites. Refer to Note 12 —Environmental Matters of the Notes to Consolidated Financial Statements for further discussion of these matters.

Industry Consolidation

In recent years, the energy industry has seen a number of consolidations, combinations, disaggregation and strategic alliances. Consolidation will present combining entities with the challenges of remaining focused on the customer and integrating different organizations. Others in the energy industry are discontinuing operations in certain portions of the energy industry or divesting portions of their business and facilities.

From time to time, we perform studies and, in some cases, hold discussions regarding utility and energy-related investments and strategic transactions with other companies. The ultimate effect on us of any such investments and transactions that may occur cannot be determined at this time.

Economic Conditions and Interest Rates

We operate in the nation’s fourth largest regional economy, including several of the nation’s wealthiest counties. Our service territory’s economic strength, high median household income, and low unemployment rate have allowed long-term stable expansion of Washington Gas’ regulated customer base and have provided active markets for our subsidiaries’ energy-related products and services.

The national economy has shown its strongest growth since the 2008 financial crisis during fiscal year 2014, with noteworthy increases in industrial production, manufacturing, and jobs. Shale oil and gas production continue to play a major role, and consumer spending has risen despite a lack of wage growth.

Even as the economic outlook has improved, WGL and Washington Gas may be affected by continued levels of customer conservation and year-over-year changes in uncollectible accounts expense. Refer to “Non-Weather Related Changes in Natural Gas Consumption Patterns”, above, for a discussion of regulatory mechanisms in place to mitigate the effects of customer conservation at Washington Gas.

Treasury interest rates were mixed during fiscal year 2014, with short-term rates rising slightly and longer term rates flat to slightly down. The Federal Reserve has begun cutting back on its quantitative easing activities which could have the impact of raising interest rates, however, other market conditions have acted to suppress this impact.

Year-over-year, national inflation was 1.7% as measured by the consumer price index for urban consumers (CPI-U), but inflation remains a concern longer term. Refer to “Inflation” below for a discussion of the regulatory impacts of inflation and the section entitled “General Factors Affecting Liquidity” for a discussion of our access to capital markets.

We require short-term debt financing to manage our working capital needs and long-term debt financing to support the capital expenditures of Washington Gas and the investments of WGESystems and WGL Midstream. A rise in interest expense without the timely recognition of the higher cost of debt in our utility rates could adversely affect future earnings. A continued rise in short-term interest rates, without the higher cost of debt being reflected in the prices charged to customers, could also negatively affect the results of operations of our retail energy-marketing segment.

Inflation

From time to time, Washington Gas seeks approval for rate increases from regulatory commissions to help it manage the effects of inflation on its operating costs, capital investment, and returns. Inflation has a significant effect on Washington Gas’ replacement cost of plant and equipment. While the regulatory commissions having jurisdiction over Washington Gas’ retail rates allow only historical cost depreciation to be recovered in rates, we anticipate that Washington Gas should be allowed to recover the increased costs of its investment and earn a return thereon after replacement of facilities occurs.

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WGL Holdings, Inc.

Washington Gas Light Company

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Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

Use of Business Process Outsourcing

Washington Gas outsources certain of its business processes related to human resources, information technology, consumer services, construction, integrated supplier and finance operations. While Washington Gas expects the agreement to continue to benefit customers and shareholders during the term of the contract, the continued management of service levels provided is critical to the success of these outsourcing arrangements.

Washington Gas has implemented a BPO Governance organization and a comprehensive set of processes to monitor and control the cost effectiveness and quality of services provided through the BPO.

Labor Contracts, Including Labor and Benefit Costs

Washington Gas has four labor contracts with bargaining units represented by three labor unions. In January 2012, Washington Gas completed negotiations on a three-year labor contract with the Teamsters Local Union No. 96 (Local 96), an affiliate of the International Brotherhood of Teamsters. The contract covers approximately 500 employees and is effective June 1, 2012 through May 31, 2015. Local 96 also represents union-eligible employees in the Shenandoah Gas division of Washington Gas and has a three-year labor contract with Washington Gas that became effective on August 1, 2012 and expires on July 31, 2015. This contract covers approximately 22 employees. On April 1, 2013, Washington Gas entered into a three year labor contract with The Office and Professional Employees International Union Local No. 2 (A.F.L.-C.I.O.). The contract covers approximately 117 employees and is effective beginning April 1, 2013 through March 31, 2016. Additionally, on August 1, 2014, Washington Gas entered into a new three-year labor contract with the International Brotherhood of Electrical Workers Local 1900 that covers approximately 21 employees and will expire on July 31, 2017. Washington Gas is subject to the terms of its labor contracts with respect to operating practices and compensation matters dealing with employees represented by the various bargaining units described above.

CRITICAL ACCOUNTING POLICIES

Preparation of financial statements and related disclosures in compliance with Generally Accepted Accounting Principles in the United States of America requires the selection and the application of appropriate technical accounting guidance to the relevant facts and circumstances of our operations, as well as our use of estimates to compile the consolidated financial statements. The application of these accounting policies involves judgment regarding estimates and projected outcomes of future events, including the likelihood of success of particular regulatory initiatives, the likelihood of realizing estimates for legal and environmental contingencies, and the probability of recovering costs and investments in both the regulated utility and non-regulated business segments.

We have identified the following critical accounting policies discussed below that require our judgment and estimation, where the resulting estimates have a material effect on the consolidated financial statements.

Accounting for Unbilled Revenue

For regulated deliveries of natural gas, Washington Gas reads meters and bills customers on a monthly cycle basis. The billing cycles for customers do not coincide with the accounting periods used for financial reporting purposes. Washington Gas accrues unbilled revenues for gas that has been delivered but not yet billed at the end of an accounting period. In connection with this accrual, Washington Gas must estimate the amount of gas that has not been accounted for on its delivery system and must estimate the amount of the unbilled revenue by jurisdiction and customer class. A similar computation is made for WGEServices to accrue unbilled revenues for both gas and electricity.

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WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

Accounting for Regulatory Operations—Regulatory Assets and Liabilities

A significant portion of our business is subject to regulation by independent government entities. As the regulated utility industry continues to address competitive market issues, the cost-of-service regulation used to compensate Washington Gas for the cost of its regulated operations will continue to evolve. Non-traditional ratemaking initiatives and market-based pricing of products and services could have additional long-term financial implications for us. The carrying cost of Washington Gas’ investment in fixed assets assumes continued regulatory oversight of our operations.

Washington Gas’ jurisdictional tariffs contain mechanisms that provide for the recovery of the cost of gas applicable to firm customers. Under these mechanisms, Washington Gas periodically adjusts its firm customers’ rates to reflect increases and decreases in the cost of gas. Annually, Washington Gas reconciles the difference between the gas costs collected from firm customers and the cost of gas incurred, defers any difference and either recovers deficiencies from, or refunds excess costs to, customers over a subsequent twelve-month period.

Washington Gas accounts for its regulated operations in accordance with FASB Accounting Standards Codification (ASC) Topic 980, Regulated Operations (ASC Topic 980), which results in differences in the application of GAAP between regulated and unregulated businesses. ASC Topic 980 requires recording regulatory assets and liabilities for certain transactions that would have been treated as expense or revenue in unregulated businesses. Future regulatory changes or changes in the competitive environment could result in WGL Holdings and Washington Gas discontinuing the application of ASC Topic 980 for some of its business and require the write-off of the portion of any regulatory asset or liability for which recovery or refund is no longer probable. If Washington Gas were required to discontinue the application of ASC Topic 980 for any of its operations, it would record a non-cash charge or credit to income for the net book value of its regulatory assets and liabilities. Other adjustments might also be required.

The current regulatory environment and Washington Gas’ specific facts and circumstances support both the continued application of ASC Topic 980 for our regulatory activities and the conclusion that all of our regulatory assets and liabilities as of September 30, 2014 are recoverable or refundable through rates charged to customers. See Note 2—Regulated Operations of the Notes to Consolidated Financial Statements for further discussion of our regulated operations.

Accounting for Income Taxes

We recognize deferred income tax assets and liabilities for all temporary differences between the financial statement basis and the tax basis of assets and liabilities, including those where regulators prohibit deferred income tax treatment for ratemaking purposes of Washington Gas. Regulatory assets or liabilities, corresponding to such additional deferred tax assets or liabilities, may be recorded to the extent recoverable from or payable to customers through the ratemaking process. Amounts applicable to income taxes due from and due to customers primarily represent differences between the book and tax basis of net utility plant in service. See Note 9—Income Taxes of the Notes to Consolidated Financial Statements for further discussion of income taxes.

Accounting for Contingencies

We account for contingent liabilities utilizing ASC Topic 450, Contingencies. By their nature, the amount of the contingency and the timing of a contingent event are subject to our judgment of such events and our estimates of the amounts. Actual results related to contingencies may be difficult to predict and could differ significantly from the estimates included in reported earnings. For a discussion of contingencies, see Note 13—Commitments and Contingencies of the Notes to Consolidated Financial Statements.

Accounting for Derivatives

We enter into both physical and financial contracts for the purchase and sale of natural gas and electricity. We designate a portion of our physical contracts related to the purchase of natural gas and electricity to serve our customers as “normal purchases and normal sales” and therefore, they are not subject to the fair value accounting requirements of ASC Topic 815, Derivatives and Hedging. The financial contracts and the portion of the physical contracts that qualify as derivative instruments and are subject to the mark-to-market accounting requirements are recorded on the balance sheet at fair value. Changes in the fair value of derivative instruments recoverable or refundable to customers and therefore subject to ASC Topic 980 are recorded as regulatory assets or liabilities, while changes in the fair value of derivative instruments not affected by rate regulation are reflected in income. WGL and Washington Gas also utilize derivative instruments that are designed to minimize the risk of interest-rate volatility associated with planned issuances of debt securities.

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WGL Holdings, Inc.

Washington Gas Light Company

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Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

Our judgment is required in determining the appropriate accounting treatment for our derivative instruments. This judgment involves various factors, including our ability to: (i) evaluate contracts and other activities as derivative instruments subject to the accounting guidelines of ASC Topic 815; (ii) determine whether or not our derivative instruments are recoverable from or refundable to customers in future periods and (iii) derive the estimated fair value of our derivative instruments. See Note 14— Derivative and Weather-Related Instruments of the Notes to Consolidated Financial Statements for a discussion of our derivatives.

Accounting for Fair Value Instruments

Fair value is based on actively quoted market prices when they are available. In the absence of actively quoted market prices, we seek indicative price information from external sources, including broker quotes and industry publications. If pricing information from external sources is not available, we must estimate prices based on available historical and near-term future price information and/or the use of statistical methods. These inputs are used with industry standard valuation methodologies. See Note 15— Fair Value Measurements of the Notes to Consolidated Financial Statements for a discussion of our valuation methodologies.

Accounting for Pension and Other Post-Retirement Benefit Plans

Washington Gas maintains a qualified, trusteed, employee-non-contributory defined benefit pension plan (qualified pension plan) covering most active and vested former employees of Washington Gas and a separate non-funded defined benefit supplemental retirement plan (DB SERP) covering most executive officers. In addition, on January 1, 2010, Washington Gas established a non-funded defined benefit restoration plan (DB Restoration) for the purpose of providing supplemental pension and pension-related benefits to a select group of management employees. Washington Gas accrues the estimated benefit obligation for all of our defined benefit plans as earned by the covered employees. For the unfunded DB SERP and DB Restoration, Washington Gas pays, from internal funds, the individual benefits as they are due. Beginning in 2009, the Company began closing these plans to new entrants. As of January 1, 2010, all new employees were entitled to defined contribution plans, and certain management employees receive benefits under a non-funded defined benefit restoration plan. Washington Gas also provides certain healthcare and life insurance benefits for retired employees which are accrued and funded in a trust on an actuarial basis over the work life of the retirees. The qualified pension plan, DB SERP, DB Restoration and health and post-retirement plans are collectively referred to as the “Plans.”

The measurement of the Plans’ obligations and costs is dependent on a variety of factors, such as employee demographics, the level of contributions made to the Plans, earnings on the Plans’ assets and mortality rates. The following assumptions are also critical to this measurement. These assumptions are derived on an annual basis with the assistance of a third party actuarial firm:

• Discount rate,

• Expected long-term return on plan assets,

• Rate of compensation increase, and

• Healthcare cost trend rate.

We determine the discount rate based on a bond portfolio analysis of high quality bonds (AA- as assigned by Standard & Poor’s or Aa3 as assigned by Moody’s or better) whose maturities match or exceed our expected benefit payments. We determine the expected long-term rate of return by averaging the expected earnings for the target asset portfolio. In developing the expected rate of return assumption, we evaluate an analysis of historical actual performance and long-term return projections, which gives consideration to the asset mix and anticipated length of obligation of the Plans. Historically, the expected long-term return on plan assets has been lower for the health and life benefit plan than for the qualified pension plan due to differences in the allocation of the assets in the plan trusts and the taxable status of one of the trusts. We calculate the rate of compensation increase based on salary expectations, expected inflation levels and promotional expectations. The healthcare cost trend rate is determined by working with insurance carriers, reviewing historical claims data for the health and life benefit plan, and analyzing market expectations.

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WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

The following table illustrates the effect of changing these actuarial assumptions, while holding all other assumptions constant:

Effect of Changing Critical Actuarial Assumptions
(In millions)	Pension Benefits			Health and Life Benefits
Actuarial Assumptions	Percentage-Point Change in Assumption	Increase (Decrease) in Ending Obligation	Increase (Decrease) in Annual Cost	Increase (Decrease) in Ending Obligation	Increase   (Decrease) in Annual Cost
Expected long-term return on plan assets	+/– 1.00 pt.	n/a	$(6.3) / $6.3	n/a	$(3.5) / $3.5
Discount rate	+/– 0.25 pt.	$(28.1) / $29.6	$(1.9) / $2.0	$(10.4) / $11.0	$(1.2) / $0.9
Rate of compensation increase	+/– 0.25 pt.	$5.0 / $(4.9)	$0.9 / $(0.9)	n/a	n/a
Healthcare cost trend rate	+/– 1.00 pt.	n/a	n/a	$10.5 / $(9.2)	$5.9 / $(5.0)

Differences between actuarial assumptions and actual plan results are deferred and amortized into cost when the accumulated differences exceed ten percent of the greater of the projected benefit obligation or the market-related value of the plan assets. If necessary, the excess is amortized over the average remaining service period of active employees. At September 30, 2014, the discount rate for the pension, DB SERP and DB Restoration plans decreased to 4.4%, 4.0% and 4.0%, from 5.0%, 4.5% and 4.5%, respectively, for the comparable period in the prior year. The health and post-retirement plans discount rate also decreased to 4.4% from 5.1% during the same period. The lower discount rates reflect the change in long-term interest rates primarily due to current market conditions. Refer to Note 10 —Pension and Other Post-Retirement Benefit Plans of the Notes to Consolidated Financial Statements for a listing of the actuarial assumptions used and for further discussion of the accounting for the Plans.

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WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

WGL HOLDINGS, INC.

RESULTS OF OPERATIONS

We analyze the operating results using utility net revenues for the regulated utility segment and gross margins for the retail energy-marketing segment. Both utility net revenues and gross margins are calculated as revenues less the associated cost of energy and applicable revenue taxes. We believe utility net revenues is a better measure to analyze profitability than gross operating revenues because the cost of the natural gas commodity and revenue taxes are generally included in the rates that Washington Gas charges to customers, as reflected in operating revenues. Accordingly, changes in the cost of gas and revenue taxes associated with sales made to customers generally have no direct effect on utility net revenues, operating income or net income. We consider gross margins to be a better reflection of profitability than gross revenues or gross energy costs for our retail energy-marketing segment because gross margins are a direct measure of the success of our core strategy for the sale of natural gas and electricity.

Neither utility net revenues nor gross margins should be considered as an alternative to, or a more meaningful indicator of our operating performance, than net income. Our measures of utility net revenues and retail energy-marketing gross margins may not be comparable to similarly titled measures of other companies. Refer to the sections entitled “Results of Operations—Regulated Utility Operating Results” and “Results of Operations—Non-Utility Operating Results” for the calculation of utility net revenues and gross margins, respectively, as well as a reconciliation to operating income and net income for both segments.

Summary Results

WGL reported net income of $105.9 million, $80.3 million and $139.8 million for the fiscal years ended September 30, 2014, 2013 and 2012, respectively. We earned a return on average common equity of 8.4%, 6.3% and 11.3%, respectively, during each of these three fiscal years.

The following table summarizes our net income (loss) by operating segment for fiscal years ended September 30, 2014, 2013 and 2012.

Net Income (Loss) by Operating Segment
	Years Ended September 30,									Increase (Decrease)
(In millions)	2014			2013			2012			2014 vs. 2013			2013 vs. 2012
Regulated utility	$	98.0		$	71.8		$	109.7		$	26.2		$	(37.9	)
Non-utility operations:
Retail energy-marketing		8.2			33.0			39.3			(24.8	)		(6.3	)
Commercial energy systems		5.4			3.0			2.4			2.4			0.6
Midstream energy services		6.2			(18.8	)		(9.1	)		25.0			(9.7	)
Other activities		(12.2	)		(7.9	)		(2.5	)		(4.3	)		(5.4	)
Total non-utility	$	7.6		$	9.3		$	30.1		$	(1.7	)	$	(20.8	)
Intersegment Eliminations	$	0.3		$	(0.8	)	$	-		$	1.1		$	(0.8	)
Net income	$	105.9		$	80.3		$	139.8		$	25.6		$	(59.5	)
Earnings per average common share
Basic	$	2.05		$	1.55		$	2.71		$	0.50		$	(1.16	)
Diluted	$	2.05		$	1.55		$	2.71		$	0.50		$	(1.16	)

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WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

Regulated Utility Operating Results

The following table summarizes the regulated utility segment’s operating results for fiscal years ended September 30, 2014, 2013 and 2012.

Regulated Utility Operating Results
	Years Ended September 30,							Increase (Decrease)
(In millions)	2014			2013		2012		2014 vs. 2013			2013 vs. 2012
Utility net revenues:
Operating revenues	$	1,443.8		$	1,200.4	$	1,137.7	$	243.4		$	62.7
Less: Cost of gas		726.9			521.5		421.5		205.4			100.0
Revenue taxes		84.3			81.4		74.2		2.9			7.2
Total utility net revenues		632.6			597.5		642.0		35.1			(44.5	)
Operation and maintenance		291.4			292.6		279.9		(1.2	)		12.7
Depreciation and amortization		104.1			100.4		95.0		3.7			5.4
General taxes and other assessments		53.4			52.3		50.8		1.1			1.5
Operating income		183.7			152.2		216.3		31.5			(64.1	)
Other income (expenses)-net, including preferred stock dividends		(0.4	)		0.1		1.8		(0.5	)		(1.7	)
Interest expense		37.1			35.6		36.1		1.5			(0.5	)
Income Tax Expense		48.2			44.9		72.3		3.3			(27.4	)
Net income	$	98.0		$	71.8	$	109.7	$	26.2		$	(37.9	)

Fiscal Year 2014 vs. Fiscal Year 2013.  The $26.2 million increase in net income primarily reflects:

• higher net revenues attributed to the colder weather impacts of 2014 that were in excess of our weather protection provisions;

• higher revenues due to new base rates in Maryland and the District of Columbia;

• increase in revenues related to the growth of more than 12,200 average active customer meters;

• favorable effects of changes in natural gas consumption patterns in the District of Columbia;

• surcharge-based rate recovery related to the accelerated pipeline replacement programs;

• higher realized margins associated with our asset optimization program;

• lower expenses related to operations and maintenance activities; and a

• decrease in the effective tax rate primarily due to the reinstatement of regulatory assets related to the tax effect of Med D and tax sharing among the consolidated affiliates.

Partially offsetting these favorable variances were:

• higher unrealized losses associated with our asset optimization program; and

• higher depreciation expense due to the growth in our investment in utility plant.

Fiscal Year 2013 vs. Fiscal Year 2012.  The $37.9 million decrease in net income primarily reflects:

• decrease in unrealized margins associated with our asset optimization program;

• higher employee incentives and benefits primarily due to a decrease in the discount rate;

• higher recoveries in 2012 (adjusted by recoveries in 2013) associated with a loss previously recognized in 2011 for refunds to customers ordered by the PSC of MD related to a cash settlement of gas imbalance with competitive service providers; and

• higher depreciation expense due to the growth in investment in utility plant.

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WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

Partially offsetting these unfavorable variances were:

• higher net revenues attributed to the warm weather impacts of 2012 that were in excess of our weather protection provisions;

• higher revenues due to the timing of rate relief in Maryland and the District of Columbia;

• increase in revenues related to the growth in average active customer meters;

• favorable effects of changes in natural gas consumption patterns in the District of Columbia;

• lower environmental expense primarily due to net insurance proceeds;

• lower bad debt expense due to a reduction in customer delinquencies and charge-offs; and

• lower income taxes due to a decrease in the effective tax rate.

Utility Net Revenues. The following table provides the key factors contributing to the changes in the utility net revenues of the regulated utility segment between years.

Composition of Changes in Utility Net Revenues
	Increase (Decrease)
(In millions)	2014     vs. 2013			2013     vs. 2012
Customer growth	$	8.1		$	3.4
Estimated weather effects		5.3			9.5
Natural gas consumption patterns		1.8			2.6
Impact of rate cases		12.2			3.5
Accelerated pipe replacement programs		3.9			3.5
Interruptible margins		1.4			-
Asset optimization:
Realized margins		18.9			(0.5)
Unrealized mark-to-market valuations		(20.8	)		(61.3)
Lower-of-cost or market adjustment		(0.3	)		0.3
Storage carrying costs		1.1			(2.3)
Competitive service provider imbalance cash settlement		-			(5.3)
Late fees and miscellaneous service charges		1.7			-
Other		1.8			2.1
Total	$	35.1		$	(44.5)

Customer growth — Average active customer meters increased by more than 12,200 from fiscal year 2013 to 2014. Average active customer meters increased by more than 10,900 from fiscal year 2012 to 2013.

Estimated weather effects — Weather, when measured by HDDs in the District of Columbia, was 9.6% colder than normal during the year ended September 30, 2014 and 0.2% warmer than normal during the year ended September 30, 2013, and 20.1% warmer than normal during the year ended September 30, 2012 (refer to the section entitled “Weather Risk” for further discussion of our weather protection strategy).

Natural Gas consumption patterns — The variance in net revenues reflects the changes in natural gas consumption patterns in the District of Columbia. These changes may be affected by shifts in weather patterns in which customer heating usage may not correlate highly with average historical levels of usage per HDD. Natural gas consumption patterns may also be affected by non-weather related factors such as customer conservation.

Impact of rate cases — The year over year variance for 2014 and 2013 reflects new base rates that were approved in the District of Columbia and Maryland, effective June 4, 2013 and November 23, 2013, respectively. The year over year variance for 2013 and 2012 reflects new base rates that were approved in the District of Columbia, effective June 4, 2013.

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WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

Accelerated pipe replacement programs — Revenues increased related to the return on investment and recovery of costs associated with accelerated pipeline replacement programs in Maryland and Virginia and a targeted mechanically coupled pipe replacement and encapsulation program in the District of Columbia.

Interruptible margins — The year over year variance for 2014 and 2013 is a result of a decrease in margin sharing with firm customers which is a direct result of the Maryland margin sharing target based on the rate case which was approved in November 2013. This consequently resulted in an increase in utility net revenues.

Asset optimization — We recorded an unrealized loss associated with our energy-related derivatives of $66.2 million for the fiscal year ended September 30, 2014, an unrealized loss of $45.4 million for the fiscal year ended September 30, 2013 and an unrealized gain of $15.9 million for the year ended September 30, 2012. When these derivatives settle, any unrealized amounts will ultimately reverse and Washington Gas will realize margins in combination with related transactions that these derivatives economically hedge. The losses recorded in 2014 are primarily due to unfavorable movements in the unobservable inputs used in the valuation of long-dated forward contracts. We believe that this value is not reflective of our ultimate cash flows as these purchases are utilized in the optimization of our long-term natural gas transportation and storage capacity resources, the value of which is not reflected at fair value. Unfavorably affecting asset optimization results were $0.2 million of lower-of-cost or market adjustments related to storage gas inventory for the year ended September 30, 2014. Washington Gas recorded no lower-of-cost or market adjustments related to its storage gas inventory during the fiscal year ended September 30, 2013. For the fiscal year ended September 30, 2012, Washington Gas recorded lower-of-cost or market adjustments, after the effects of regulatory sharing, of $1.5 million. Refer to the section entitled “Market Risk—Price Risk Related to the Regulated Utility Segment” for further discussion of our asset optimization program.

Storage Carrying Costs — Each jurisdiction provides for the recovery of carrying costs based on the pre-tax cost of capital, multiplied by the monthly average balance of storage gas inventory. The year over year comparisons for 2014 and 2013 reflect increased incremental carrying cost per therm and additional storage capacity in the current period compared to the same period of the prior fiscal year. For fiscal year 2013 compared to 2012, the comparison reflects lower average storage gas inventory investment balances primarily due to lower weighted average cost of gas in inventory.

Competitive Service Provider imbalance cash settlement — The PSC of MD ordered Washington Gas to refund to customers an amount associated with a cash settlement of gas imbalances with competitive service providers. The order remanded the matter to a hearing examiner to determine the amount of the refund as the difference between charges made to customers and the charges that would have been incurred had the imbalances been made up through volumetric adjustments. In 2012, based on Washington Gas’ decision to seek recovery from third party marketers, $4.8 million was recognized as a receivable, resulting in a favorable year-over-year variance of $10.7 million. For 2013, there is no cost associated with this settlement, resulting in an unfavorable year-over-year variance of $5.3 million.

Operation and Maintenance Expenses. The following table provides the key factors contributing to the changes in operation and maintenance expenses of the regulated utility segment between years.

Composition of Changes in Operation and Maintenance Expenses
	Increase/(Decrease)
(In millions)	2014 vs. 2013		2013 vs. 2012
Employee benefits	$	(18.1)	$	9.3
Impairment loss		(0.4)		(1.5)
Weather-related instruments:
Benefit		0.3		6.1
Premium costs and fair value effects		0.5		1.1
Labor and incentive plans		3.0		5.0
Net insurance proceeds		2.2		(2.4)
Uncollectible accounts		4.7		(2.3)
Operations, engineering, compliance and safety		7.7		(0.8)
Other		(1.1)		(1.8)
Total	$	(1.2)	$	12.7

Employee benefits — The decrease in employee benefits expense for 2014 to 2013 year over year comparison primarily relates to an amendment to the post-retirement benefits plan resulting in a re-measurement of the benefit obligation and a reduction in the net periodic expense for the current period compared to the same period in the prior year. The increase in employee benefits expense for 2013 to 2012 year over year comparison primarily reflects higher pension and other post-retirement benefits due to changes in the discount rate and other plan assumptions used to measure the benefit obligation.

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WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

Impairment loss — On July 7, 2014, the SCC of VA disallowed recovery of carrying costs on certain deferred costs related to an abandoned liquefied natural gas facility, therefore, $1.9 million of the associated regulatory asset was impaired. During fiscal year 2013, Washington Gas recorded a $2.6 million impairment loss on a previous operations facility by reducing the carrying amount of $24.9 million down to its fair value of $22.3 million and a $0.5 million impairment loss for the unrecoverable portion of the LNG storage facility. In 2012, Washington Gas incurred a $5.0 million impairment loss on the previous operations facility by reducing the carrying amount of $29.9 million down to its fair value of $24.9 million.

Weather-related instrument benefits/losses — There were no derivative instruments hedging variations from normal weather in the District of Columbia for fiscal year 2014. The effects of hedging variations from normal weather in the District of Columbia for fiscal years 2013, and 2012 were recorded to operation and maintenance expense. During fiscal year 2013, Washington Gas recorded gains of $0.3 million (pre-tax) related to its weather-related instruments as a result of warmer-than-normal weather and received a benefit of $0.7 million for premiums on its weather-related instruments. During fiscal year 2012, Washington Gas recorded gains of $6.3 million (pre-tax) related to its weather-related instruments as a result of warmer-than-normal weather and received a benefit of $0.8 million for premiums on its weather-related instruments. The benefits or losses of the weather-related instruments are offset by the effect of weather on utility net revenues.

Labor and incentive plans — The increase in expense for year over year comparisons is primarily due to higher direct labor costs driven by general wage increases, increase in the number of employees and in overtime work driven primarily by cold weather.

Net insurance proceeds — In 2013, Washington Gas received proceeds from an environmental insurance policy for past and future claims, partially offset by costs associated with environmental claims and regulatory sharing.

Uncollectible accounts — The increase in expense for year over year comparisons for fiscal year 2014 to 2013 is due to increased volumes of gas deliveries. In addition, Washington Gas provided an increased number of structured and deferred payment plans to customers in Maryland due to the extremely cold winter. The decrease in expense in fiscal year 2013 compared to 2012 reflects a reduction in customer delinquencies and charge-offs.

Operations, engineering, compliance and safety — The increase in expense in fiscal year 2014 compared to 2013 year-over year comparison reflects increased maintenance costs driven primarily by cold weather. The decrease in expense in fiscal year 2013 compared to 2012 year-over-year comparison reflects a reduction in paving costs.

Depreciation and Amortization.  The following table provides the key factors contributing to the changes in depreciation and amortization of the regulated utility segment between years.

Composition of Changes in Depreciation and Amortization
	Increase (Decrease)
(In millions)	2014 vs. 2013		2013 vs. 2012
Property, plant and equipment	$	3.6	$	4.7
Amortization reversal		(0.7)		(1.3)
New depreciation rates—District of Columbia		-		(0.3)
Accelerated pipe replacement programs		0.8		-
Retroactive depreciation adjustment—Virginia		-		2.3
Total	$	3.7	$	5.4

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WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

Non-Utility Operating Results

Retail Energy-Marketing

The following table depicts the retail energy-marketing segment’s operating results along with selected statistical data.

Retail-Energy Marketing Financial and Statistical Data
	Years Ended September 30,								Increase (Decrease)
	2014			2013			2012		2014   vs. 2013			2013           vs. 2012
Operating Results (In millions)
Gross margins:
Operating revenues	$	1,310.3		$	1,279.3		$	1,267.1	$	31.0		$	12.2
Less: Cost of energy		1,239.0			1,164.8			1,139.2		74.2			25.6
Revenue taxes		8.3			6.8			5.8		1.5			1.0
Total gross margins		63.0			107.7			122.1		(44.7	)		(14.4)
Operation expenses		43.8			49.6			52.2		(5.8	)		(2.6)
Depreciation and amortization		0.7			0.7			0.7		-			-
General taxes and other assessments—other		4.6			4.4			4.0		0.2			0.4
Operating income		13.9			53.0			65.2		(39.1	)		(12.2)
Other income (expenses)-net		0.1			0.2			-		(0.1	)		0.2
Income tax expense		5.8			20.2			25.9		(14.4	)		(5.7)
Net income	$	8.2		$	33.0		$	39.3	$	(24.8	)	$	(6.3)
Analysis of gross margins (In millions)
Natural gas
Realized margins	$	59.0		$	44.1		$	34.9	$	14.9		$	9.2
Unrealized mark-to-market gains (losses)		5.2			(1.7	)		6.9		6.9			(8.6)
Total gross margins—natural gas		64.2			42.4			41.8		21.8			0.6
Electricity
Realized margins	$	0.7		$	58.6		$	78.8	$	(57.9	)	$	(20.2)
Unrealized mark-to-market gains (losses)		(1.9	)		6.7			1.5		(8.6	)		5.2
Total gross margins—electricity		(1.2	)		65.3			80.3		(66.5	)		(15.0)
Total gross margins	$	63.0		$	107.7		$	122.1	$	(44.7	)	$	(14.4)
Other Retail-Energy Marketing Statistics
Natural gas
Therm sales (millions of therms)		718.1			702.5			610.4		15.6			92.1
Number of customers (end of period)		156,600			167,900			177,500		(11,300	)		-9,600
Electricity
Electricity sales (millions of kWhs)		11,692.0			12,133.0			11,794.9		(441.0	)		338.1
Number of accounts (end of period)		162,100			179,900			194,300		(17,800	)		-14,400

Fiscal Year 2014 vs. Fiscal Year 2013.  The retail energy-marketing segment reported net income of $8.2 million for the fiscal year 2014 compared to net income of $33.0 million reported for fiscal year 2013. This reduction primarily reflects lower gross margins from the sale of electricity.

Gross margins from natural gas sales increased $21.8 million in fiscal year 2014 from the prior year. This increase reflects higher spot sales to interruptible customers, hedge settlements and portfolio optimization activity as well as an increase in unrealized mark-to-market valuations due to fluctuating market prices.

Gross margins from electric sales decreased $66.5 million in fiscal year 2014 from the prior year due to higher capacity and ancillary service charges from the regional power grid operator (PJM) and a decrease in unrealized mark-to-market valuations due to fluctuating market prices.

Operating expenses were lower due to lower customer acquisition, billing and customer service costs.

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WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

Fiscal Year 2013 vs. Fiscal Year 2012.  The retail energy-marketing segment reported net income of $33.0 million for the fiscal year 2013 compared to net income of $39.3 million reported for fiscal year 2012. This reduction primarily reflects lower gross margins from the sale of electricity.

Gross margins from natural gas sales increased $0.6 million in fiscal year 2013 from the prior year. This increase reflects $8.6 million in lower unrealized mark-to-market margins on energy-related derivatives resulting from fluctuating market prices and higher realized margins of $9.2 million due to higher retail sales volumes resulting from colder weather compared to fiscal year 2012 and increased margins on portfolio optimization activities.

Gross margins from electric sales decreased $15.0 million in fiscal year 2013 over the prior year. This decrease reflects $5.2 million in higher unrealized mark-to-market margins on energy-related derivatives from fluctuating market prices offset by a $20.2 million decrease in realized margins due to the timing differences in margin recognition as well as higher ancillary service charges associated with fixed price contracts.

Commercial Energy Systems

The tables below represent the financial results by division of the commercial energy systems segment for the fiscal years ended September 30, 2014, 2013, and 2012.

Commercial Energy Systems Segment Financial Information
	Years Ended September 30,									Increase (Decrease)
(In millions)	2014			2013			2012			2014 vs. 2013			2013 vs. 2012
Federal revenues	$	23.2		$	29.4		$	57.1		$	(6.2	)	$	(27.7	)
Distributed generation revenues		17.0			5.3			3.0			11.7			2.3
Total revenues	$	40.2		$	34.7		$	60.1		$	5.5		$	(25.4	)
Cost of goods sold		20.3			24.5			51.1			(4.2	)		(26.6	)
Operating expenses		10.7			7.2			5.7			3.5			1.5
Solar depreciation		6.2			2.4			1.2			3.8			1.2
Total expenses	$	37.2		$	34.1		$	58.0		$	3.1		$	(23.9	)
Operating income	$	3.0		$	0.6		$	2.1		$	2.4		$	(1.5	)
Equity earnings		2.0			1.1			0.9			0.9			0.2
Other income		1.8			1.2			0.4			0.6			0.8
Interest expense		0.4			0.2			0.1			0.2			0.1
Total other income	$	3.4		$	2.1		$	1.2		$	1.3		$	0.9
Earnings before income taxes	$	6.4		$	2.7		$	3.3		$	3.7		$	(0.6	)
Income tax expense		3.7			0.8			1.1			2.9			(0.3	)
Amortization of income tax credits & treasury grants		(2.7	)		(1.1	)		(0.2	)		(1.6	)		(0.9	)
Net income	$	5.4		$	3.0		$	2.4		$	2.4		$	0.6
Net income (loss) by division :
Federal division	$	(3.0	)	$	0.1		$	1.3		$	(3.1	)	$	(1.2	)
Distributed generation division		5.9			2.0			1.2			3.9			0.8
Investment solar division		2.5			0.9			(0.1	)		1.6			1.0
Total net income	$	5.4		$	3.0		$	2.4		$	2.4		$	0.6

44

WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

The commercial energy systems segment reported net income of $5.4 million, $3.0 million and $2.4 million in fiscal years 2014, 2013 and 2012, respectively. The year-over-year variances for all years are primarily due to higher solar renewable credits, solar generation revenue from commercial solar assets and higher solar investment income.

Midstream Energy Services

Midstream Energy Services reported net income of $6.2 million, in fiscal year 2014 and net losses of $18.8 million and $9.1 million in fiscal years 2013 and 2012, respectively. The variance between 2014 and 2013 is driven by higher realized margins on physical and financial transactions associated with higher gas prices and unrealized gains on derivative instruments. Both 2014 and 2013 reflect expenses of approximately $4.0 million associated with its investments in the Central Penn Line and Constitution pipeline projects. The variance between 2013 and 2012 is driven by organizational costs incurred for the Constitution Pipeline Project, unrealized losses from long-term purchase contracts, continued compression of storage spreads and higher operation and maintenance expense as a result of new storage and optimization arrangements. In addition, operation and maintenance expense was higher as a result of investments in new storage and optimization arrangements, as well as costs incurred for the Commonwealth Pipeline project.

Other Non-Utility Activities

As previously discussed, transactions that are not significant enough on a stand-alone basis to warrant treatment as an operating segment, and that do not fit into one of our four operating segments, are aggregated as “Other Activities” and included as part of non-utility operations. Results for our other non-utility activities reflect net losses of $12.2 million, $7.9 million and $2.5 million for fiscal years 2014, 2013, and 2012, respectively. The year-over-year comparisons reflect business development costs, legal expenses and our corporate branding initiative costs.

Intersegment Eliminations

Intersegment Eliminations represents a timing difference between Commercial Energy Systems’ recognition of revenue for the sale of SRECs to Retail Energy-Marketing and Retail Energy-Marketing’s recognition of the associated expense. Retail Energy-Marketing has accrued expenses relating to SREC’s that have been generated by Commercial Energy Systems but have not been transferred.

LIQUIDITY AND CAPITAL RESOURCES

General Factors Affecting Liquidity

Access to short-term debt markets is necessary for funding our short-term liquidity requirements, the most significant of which include buying natural gas, electricity, and pipeline capacity, and financing accounts receivable and storage gas inventory. Our need for access to long-term capital markets is driven primarily by capital expenditures, maturities of long-term debt, and the availability of government funding through deferred taxes.

During the fiscal year ended September 30, 2014, both WGL and Washington Gas met its liquidity and capital needs through retained earnings, the issuance of commercial paper and long-term debt.

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WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

Our ability to access capital markets depends on our credit ratings, general market liquidity, and investor demand for our securities. Our credit ratings depend largely on the financial performance of our subsidiaries, and a ratings downgrade could both increase our borrowing costs and trigger the need for posting additional collateral with our wholesale counterparties or other creditors. In support of our credit ratings, we have a goal to maintain our common equity ratio in the 50% range of total consolidated capital. As of September 30, 2014, total consolidated capitalization, including current maturities of long-term debt and excluding notes payable, comprised 63.2% common equity, 1.4% preferred stock and 35.4% long-term debt. The level of this ratio varies during the fiscal year due to the seasonal nature of our business. This seasonality also affects our short-term debt balances, which are typically higher in the fall and winter months and substantially lower in the spring when a significant portion of our current assets are converted into cash at the end of the heating season. Our cash flow requirements and our ability to provide satisfactory resources to meet those requirements are primarily influenced by the activities of all of WGL’s operating segments.

Our plans provide for sufficient liquidity to satisfy our financial obligations. At September 30, 2014, we had no restrictions on our cash balances or retained earnings that would affect the payment of common or preferred stock dividends by either WGL or Washington Gas.

Short-Term Cash Requirements and Related Financing

Washington Gas has seasonal short-term cash requirements to fund the purchase of storage gas inventory in advance of the winter heating season. At September 30, 2014 and September 30, 2013, Washington Gas had balances in gas storage of $156.1 million and $132.2 million, respectively. Washington Gas collects the cost of gas under cost recovery mechanisms approved by its regulators. Additionally, Washington Gas may be required to post cash collateral for certain purchases.

During the first six months of our fiscal year, Washington Gas’ large sales volumes cause its cash requirements to peak when combined storage inventory, accounts receivable, and unbilled revenues are at their highest levels. During the last six months of our fiscal year, after the heating season, Washington Gas will typically experience a seasonal net loss due to reduced demand for natural gas. During this period, large amounts of Washington Gas’ current assets are converted to cash, which Washington Gas generally uses to reduce and sometimes eliminate short-term debt and acquire storage gas for the next heating season.

Variations in the timing of collections under its gas cost recovery mechanisms can significantly affect Washington Gas’ short-term cash requirements. At September 30, 2014 and September 30, 2013, Washington Gas had $9.8 million and $0.6 million in net over-collections, respectively, of gas costs reflected in current assets/liabilities as gas costs due to customers. Amounts under-collected or over-collected that are generated during the current gas cost recovery cycle are deferred as a regulatory asset or liability on the balance sheet until September 1 of each year, at which time the accumulated amount is transferred to gas costs due from/to customers as appropriate. At September 30, 2014 and September 30, 2013, Washington Gas had a net regulatory liability of $11.7 million and a net regulatory asset of $13.8 million, respectively, related to the current gas recovery cycle.

WGL and Washington Gas use short-term debt in the form of commercial paper or unsecured short-term bank loans to fund seasonal cash requirements. Our policy is to maintain back-up bank credit facilities in an amount equal to or greater than our expected maximum commercial paper position. Bank credit balances available to WGL and Washington Gas net of commercial paper balances were $85.5 million and $261.0 million at September 30, 2014 and $201.4 million and $225.5 million at September 30, 2013, respectively. The credit facility for WGL permits it to borrow up to $450.0 million, and further permits, with the banks’ approval, additional borrowings of $100.0 million for a maximum potential total of $550.0 million. The credit facility for Washington Gas permits it to borrow up to $350.0 million, and further permits, with the banks’

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Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

approval, additional borrowings of $100.0 million for a maximum potential total of $450.0 million. The interest rate on loans made under each of the credit facilities will be a fluctuating rate per annum that will be set using certain parameters at the time each loan is made. WGL and Washington Gas incur credit facility fees, which in some cases are based on the long-term debt ratings of Washington Gas. In the event that the long-term debt of Washington Gas is downgraded below certain levels, WGL and Washington Gas would be required to pay higher fees. There are five different levels of fees. The credit facility for WGL defines its applicable fee level as one level below the level applicable to Washington Gas. Under the terms of the credit facilities, the lowest level facility fee is 0.06% and the highest is 0.175%. These credit agreements provide for a term of five years and expire on April 3, 2017. The credit agreements each have two one-year extension options. Refer to Note 3—Short-Term Debt of the Notes to the Consolidated Financial Statements for further information.

A share repurchase program was approved by the Board of Directors and announced on August 7, 2014 to repurchase WGL’s common stock up to an amount of $150 million. The shares may be repurchased in the open market or in privately negotiated transactions. The repurchase program is authorized for a two year period. During the quarter ended September 30, 2014, we repurchased 1.3 million shares of common stock at a total cost of approximately $56.1 million. This amount reflects the total since the program’s inception.

To manage credit risk, Washington Gas may require certain customers and suppliers to provide deposits, which are reported as current liabilities in “Customer deposits and advance payments,” in the accompanying balance sheets. At September 30, 2014 and September 30, 2013, “Customer deposits and advance payments” totaled $68.3 million and $67.2 million, respectively.

For Washington Gas, deposits from customers may be refunded at various times throughout the year based on the customer’s payment habits. At the same time, other customers make new deposits that cause the balance of customer deposits to remain relatively steady. There are no restrictions on Washington Gas’ use of these customer deposits. Washington Gas pays interest to its customers on these deposits in accordance with the requirements of its regulatory commissions.

For WGEServices and WGL Midstream, deposits would typically represent collateral for transactions with wholesale counterparties. These deposits may be reduced, repaid or increased at any time based on the current value of WGEServices’ or WGL Midstream’s net position with the counterparty. Currently, there are no restrictions on the use of deposited funds and interest is paid to the counterparty on these deposits in accordance with its contractual obligations. Refer to the section entitled “Credit Risk” for further discussion of our management of credit risk.

WGEServices and WGL Midstream have seasonal short-term cash requirements to fund the purchase of storage gas inventory in advance of the winter heating season. At September 30, 2014 and September 30, 2013, WGEServices had balances in gas storage of $50.5 million and $49.1 million, respectively. WGEServices collects revenues that are designed to reimburse commodity costs used to supply their retail customer and wholesale counterparty contracts. At September 30, 2014 and September 30, 2013, WGL Midstream had balances in gas storage of $127.0 million and $166.0 million, respectively. As market opportunities arise, WGL Midstream collects revenues in excess of its commodity costs through its wholesale counterparty contracts. WGEServices and WGL Midstream derive funding to finance these activities from short-term debt issued by WGL. Additionally, WGEServices and WGL Midstream may be required to post cash collateral for certain purchases. WGEServices and WGL Midstream may be required to provide parent guarantees from WGL for certain transactions.

In addition to storage gas, WGL Midstream also has short-term cash requirements to fund the construction of the Central Penn Line pipeline. At September 30, 2014, WGL Midstream had short-term cash obligations of $26.1 million related to the Central Penn Line pipeline. At September 30, 2013, WGL Midstream did not have any obligations related to the Central Penn Line pipeline. WGL Midstream derives funding to finance these activities from short-term debt issued by WGL.

WGESystems has cash requirements to fund the construction and purchase of residential and commercial distributed generating systems. WGESystems derives funding to finance these activities from short-term debt issued by WGL but may also utilize long-term debt issued by WGL in the future.

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WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

Money Pool

WGL has money pool arrangements with and among its subsidiaries to coordinate and provide for certain short term cash and working capital requirements. This money pool may also accumulate cash from the periodic issuance of WGL’s common stock from the company’s dividend reinvestment program and stock based compensation programs as well as the operations of certain subsidiaries. In return, the money pool provides short-term loans to its subsidiaries to meet various working capital needs. Washington Gas does not participate in the money pool.

Long-Term Cash Requirements and Related Financing

The primary drivers of our long-term cash requirements include capital expenditures, non-utility investments, long-term debt maturities and decisions to refinance long-term debt and our share repurchase program. Our capital expenditures primarily relate to adding new utility customers and system supply as well as maintaining the safety and reliability of Washington Gas’ distribution system (refer to the section entitled “Capital Expenditures” below).

WGL Debt Issuances

On August 18, 2014, WGL entered into an Indenture with The Bank of New York Mellon (the “Trustee”) to issue an unlimited amount of debt securities. Supplemental indentures will supplement the Indenture and establish the respective terms of the notes. The offering of the notes has been registered under a shelf registration statement on Form S-3.

On October 24, 2014, WGL issued $100.0 million of 2.25% notes due November 1, 2019 (“2019 Notes”) and $125.0 million of 4.60% notes due November 1, 2044 (“2044 Notes”). The notes were priced at 99.79% and 99.23% of par, respectively. The 2019 Notes have a make whole call provision that WGL may exercise at any time on or after October 24, 2014 and prior to October 1, 2019. At any time on or after October 1, 2019, the 2019 Notes may be called at 100% of the principal of such notes, plus accrued and unpaid interest. The 2044 Notes have a make whole call provision that WGL may exercise at any time on or after October 24, 2014 and prior to May 1, 2044. At any time on or after May 1, 2044, the 2044 Notes may be called at 100% of the principal of such notes, plus accrued and unpaid interest. These transactions were executed with Wells Fargo Securities, LLC, BB&T Capital Markets, TD Securities and CIBC World Markets as underwriters. Proceeds from the sale of these notes will be used by WGL to primarily fund the repurchase of outstanding securities of WGL and capital investments of its non-utility subsidiaries.

Proceeds from the sale of these notes will be used by WGL to primarily fund the repurchase of outstanding securities of WGL and capital investments of its non-utility subsidiaries.

Washington Gas Debt Issuances

At September 30, 2014, Washington Gas had the capacity under a shelf registration to issue up to $275.0 million of additional Medium Term Notes (MTNs). Washington Gas has authority from its regulators to issue other forms of debt, including private placements. The following describes long-term debt issuance activity during fiscal year 2014 and 2013.

Fiscal Year 2014 Activity.  On December 5, 2013, Washington Gas issued $75.0 million in 5.00% MTN’s due on December 15, 2043. On September 12, 2014, Washington Gas issued $100.0 million of 4.22% fixed MTNs due September 15, 2044. Proceeds from these notes were used by Washington Gas to retire short-term debt used to refund long-term debt that was retired on September 10, 2014 with a coupon rate of 5.17%, and for general corporate purposes. On November 7, 2013, Washington Gas retired $37.0 million of 4.88% MTN’s and September 10, 2014, retired $30.0 million in 5.17% MTN’s.

Fiscal Year 2013 Activity.  There were no MTN or private placement issuances or retirements for the year ended September 30, 2013.

We are exposed to interest-rate risk associated with our debt financing. Prior to issuing long-term debt, WGL and Washington Gas may utilize derivative instruments to minimize its exposure to the risk of interest-rate volatility. Refer to the section entitled “Interest-Rate Risk” for further discussion of our interest-rate risk management activity.

Security Ratings

Changes in credit ratings may affect WGL’s and Washington Gas’ cost of short-term and long-term debt and their access to the capital markets. A security rating is not a recommendation to buy, sell or hold securities.

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Washington Gas Light Company

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Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

The rating may be subject to revision or withdrawal at any time by the assigning rating organization and each rating should be evaluated independently of any other rating. On January 30, 2014, Moody’s upgraded Washington Gas’ senior unsecured rating to A1 from A2. The table below reflects the credit ratings for the outstanding debt instruments of WGL and Washington Gas for the year ended September 30, 2014.

	WGL		Washington Gas
Rating Service	Unsecured  Medium-Term Notes  (Indicative)(a)	Commercial Paper	Unsecured Medium-Term Notes	Commercial Paper
Fitch Ratings(b)	A+	F1	AA-	F1
Moody’s Investors Service(c)	Not Rated	P-2	A1	P-1
Standard & Poor’s Ratings Services(d)	A+	A-1	A+	A-1

^(a) Indicates the ratings that may be applicable if WGL were to issue unsecured MTNs.

^(b) The long-term debt ratings outlook issued by Fitch Ratings for WGL and Washington Gas is stable.

^(c) The long-term debt ratings outlook issued by Moody’s Investors Service for Washington Gas is stable.

^(d) The long-term debt ratings outlook issued by Standard & Poor’s Rating Services for WGL and Washington Gas is stable.

On October 15, 2014, Fitch Ratings downgraded WGL’s credit rating for its senior unsecured debt to “A” from “A+.” On October 22, 2014, Moody’s assigned an issue credit rating for WGL’s senior unsecured debt of “A3” and S&P assigned an issue credit rating for WGL’s senior unsecured debt of “A.”

Ratings Triggers and Certain Debt Covenants

WGL and Washington Gas pay credit facility fees, which in some cases are based on the long-term debt ratings of Washington Gas. Under the terms of WGL’s and Washington Gas’ credit agreements, the ratio of consolidated financial indebtedness to consolidated total capitalization cannot exceed 0.65 to 1.0 (65.0%). In addition, WGL and Washington Gas are required to inform lenders of changes in corporate existence, financial conditions, litigation and environmental warranties that might have a material effect on debt ratings. The failure to inform the lenders’ agent of material changes in these areas might constitute default under the agreements. Additionally, failure to pay principal or interest on any other indebtedness may be deemed a default under our credit agreements. A default, if not remedied, may lead to a suspension of further loans and/or acceleration in which obligations become immediately due and payable. At September 30, 2014, we were in compliance with all of the covenants under our revolving credit facilities.

For certain of Washington Gas’ natural gas purchase and pipeline capacity agreements, if the long-term debt of Washington Gas is downgraded to or below the lower of a BBB- rating by Standard & Poor’s or a Baa3 rating by Moody’s Investors Service, or if Washington Gas is deemed by a counterparty not to be creditworthy, then the counterparty may withhold service or deliveries, or may require additional credit support. For certain other agreements, if the counterparty’s credit exposure to Washington Gas exceeds a contractually defined threshold amount, or if Washington Gas’ credit rating declines by a certain rating level, then the counterparty may require additional credit support. At September 30, 2014, Washington Gas would not be required to provide additional credit support by these arrangements if its long-term credit rating was to be downgraded by one rating level.

WGL guarantees payments for certain purchases of natural gas and electricity on behalf of WGEServices and WGL Midstream (refer to “Contractual Obligations, Off-Balance Sheet Arrangements and Other Commercial Commitments” for a further discussion of these guarantees). If the credit rating of WGL declines, WGEServices and WGL Midstream may be required to provide additional credit support for these purchase contracts. At September 30, 2014, neither WGEServices nor WGL Midstream would be required to provide additional credit support for these arrangements if the long-term credit rating of WGL Holdings was to be downgraded by one rating level.

Historical Cash Flows

The following table summarizes WGL’s net cash provided by (used in) operating, investing and financing activities for the fiscal years ended September 30, 2014, 2013 and 2012:

	Fiscal Years Ended September 30,									Increase / (Decrease)			Increase / (Decrease)
(In millions)	2014			2013			2012			2014 vs. 2013			2013 vs. 2012
Cash provided by (used in):
Operating activities	$	382.2		$	318.0		$	217.6		$	64.2		$	100.4
Investing activities	$	(422.1	)	$	(371.1	)	$	(266.8	)	$	(51.0	)	$	(104.3	)
Financing activities	$	45.2		$	46.3		$	55.2		$	(1.1	)	$	(8.9	)

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Washington Gas Light Company

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Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

Cash Flows Provided by Operating Activities

The regulated utility’s cash flows from operating activities principally reflect gas sales and deliveries and the cost of operations. The volume of gas sales and deliveries is dependent primarily on factors external to the utility, such as growth of customer demand, weather, market prices for energy, economic conditions and measures that promote energy efficiency. Under revenue and weather normalization, ratemaking adjustments and decoupling mechanisms in place, changes in delivery volumes from levels assumed when rates were approved may affect the timing of cash flows but not net income. The price at which the utility provides energy to customers is determined in accordance with regulatory approved tariffs. In general, changes in the utility’s cost of purchased power, fuel and gas may affect the timing of cash flows but not net income because the costs are recovered in accordance with rate agreements. In addition, the regulated utility’s cash flow is impacted by the timing of derivative settlements.

The non-utility cash flows from operating activities primarily reflect the timing of receipts related to distributed generating and federal projects at commercial energy systems and the timing of receipts related to electric and gas bills for retail-energy marketing. The timing of gas purchases and sales resulting from asset optimization arrangements affect midstream energy services.

Net income is the result of cash and non-cash (or accrual) transactions. Only cash transactions affect WGL’s cash flows from operating activities. Principal non-cash charges include depreciation, accrued or deferred pension and other post-retirement benefit costs and deferred income tax expense. Non-cash charges or credits may also be accrued under the revenue decoupling and cost reconciliation mechanisms in the utilities’ rate plans.

Net cash provided by operating activities for the fiscal year ended September 30, 2014 increased by $64.2 million to $382.2 million from $318.0 million for fiscal year ended September 30, 2013. The change in net cash flows reflects increased sales volumes to customers due to our colder than normal weather winter heating season. Seasonal trends and timing are reflected within changes to accounts receivable, recoverable energy costs and accounts payable.

The change in regulatory assets principally reflects changes in deferred pension and post-retirement benefit costs in accordance with the accounting rules for retirement benefits.

Net cash provided by operating activities for fiscal year ended September 30, 2013 totaled $318.0 million compared to $217.6 million in fiscal year ended September 30, 2012. This change in net cash flows reflects an increase in storage gas due to higher inventory prices; increased inventory and a decrease in pension and post-retirement benefit contributions; and a decrease in the change in gas costs (current) and other regulatory assets/liabilities- net due to increase in mark-to-market adjustments along with an increase in price. Seasonal trends and timing are reflected within changes to accounts receivables, recoverable energy costs and accounts payable.

Cash Flows Provided By Financing Activities

Cash flows provided by financing activities totaled $45.2 million in fiscal year ended September 30, 2014 reflecting the issuance of $175.3 million in long-term debt; retirement of $67.0 million in MTNs; $80.4 million increase in notes payable used to finance gas purchase and storage inventory costs; $85.2 million of dividend payments on common and preferred stock and the repurchase of $56.1 million in common stock. Cash flows provided by financing activities totaled $46.3 million in fiscal year ended September 30, 2013 reflecting an increase in notes payable of $125.4 million used to finance gas purchase and storage inventory costs and $86.1 million of dividend payments on common and preferred stock. Cash flows provided by financing activities totaled $55.2 million in fiscal year ended September 30, 2012 reflecting a $208.3 million increase in notes payable used to finance gas purchase and storage inventory costs for planned non-utility growth and pension contributions; $77.2 million of dividend payments on common and preferred stock; and the retirement of $77.0 million in MTNs.

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Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

The following table reflects the issuances and retirements of long-term debt that occurred during the fiscal years 2014, 2013 and 2012 (also refer to Note 5 —Long Term Debt of Notes to Consolidated Financial Statements).

Long-Term Debt Activity
	2014						2013				2012
($ In millions)	Interest Rate			Amount			Interest Rate		Amount		Interest Rate			Amount
Medium-term notes
Issued		4.22 – 5.00	%	$	175.0			n/a	$	-		n/a		$	-
Retired		4.88 – 5.17	%		(67.0	)		n/a		-		5.90 – 6.05	%		(77.0)
Other financing
Issued (a)		2.52	%		0.3			n/a		-		2.77 – 3.38	%		6.2
Retired (b)		n/a			-			n/a		-		3.94	%		(4.2)
Other activity
Total				$	108.3				$	-				$	(75.0)

^(a) Includes the non-cash issuances of project debt financing of $0.3 million for fiscal year 2014 and $6.2 million for fiscal year 2012.

^(b) Includes the non-cash extinguishments of project debt financing of $4.2 million for fiscal year 2012.

Cash Flows Used in Investing Activities

Net cash flows used in investing activities totaled $422.1 million, $371.1 million and $266.8 million during fiscal years 2014, 2013 and 2012, respectively, which primarily consists of capital expenditures made on behalf of Washington Gas and investments in commercial Solar PV facilities. Additionally we invested $31.4 million and $62.9 million, respectively, in other non-utility projects.

Capital Investments

The following table depicts our actual capital investments for fiscal years 2012, 2013 and 2014, and projected capital investments for fiscal years 2015 through 2019. Our capital outlays include expenditures to extend service to new areas, and to ensure safe, reliable and improved service for our utility and to grow our non-utility investments.

		Actual							Projected
(In millions)		2012			2013		2014		2015		2016		2017		2018		2019		Total
New business(a)	$	53.5		$	71.3	$	97.0	$	85.6	$	137.4	$	142.1	$	162.5	$	171.2	$	698.8
Replacements:
Regulatory plans		33.4			40.2		51.7		91.1		94.7		95.7		96.2		96.6		474.3
Other		65.8			63.8		70.0		50.3		54.0		47.9		45.9		45.4		243.5
Customer information system		-			-		9.9		34.5		36.9		8.8		-		-		80.2
Other utility		56.8			52.5		82.2		41.6		49.8		60.9		54.9		46.8		254.0
Cash basis adjustments		(9.8	)		-		(24.5)		-		-		-		-				-
Total utility(b)		199.7			227.8		286.3		303.1		372.8		355.4		359.5		360.0		1,750.8
Pipeline investments		-			6.2		20.8		50.6		84.2		252.0		62.8		1.1		450.7
Distributed generation		41.8			83.7		108.2		123.0		100.0		100.0		100.0		100.0		523.0
Other non-utility		1.1			0.7		0.2		27.8		2.4		0.6		0.7		0.6		32.1
Total investments	$	242.6		$	318.4	$	415.5	$	504.5	$	559.4	$	708.0	$	523.0	$	461.7	$	2,756.6

(a) Includes certain projects that support the existing distribution system.

(b) Excludes Allowance for Funds Used During Construction. Includes capital expenditures accrued and capital expenditure adjustments recorded in the fiscal year.

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WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

The 2015 to 2019 projected periods include $ 698.8 million for continued growth to serve new customers and $717.8 million for the replacement and betterment of existing distribution facilities, including $474.3 million of expenditures for replacement projects intended to meet the requirements of the planned accelerated pipe replacement programs in all three jurisdictions served by Washington Gas.

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WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

CONTRACTUAL OBLIGATIONS, OFF-BALANCE SHEET ARRANGEMENTS AND OTHER COMMERCIAL COMMITMENTS

Contractual Obligations

WGL and Washington Gas have certain contractual obligations incurred in the normal course of business that require fixed and determinable payments in the future. These commitments include long-term debt, lease obligations, unconditional purchase obligations for pipeline capacity, transportation and storage services, certain natural gas and electricity commodity commitments and our commitments related to the business process outsourcing program.

The estimated obligations as of September 30, 2014 for future fiscal years are shown below.

Estimated Contractual Obligations and Commercial Commitments
	Years Ended September 30,
(In millions)	Total		2015		2016		2017		2018		2019		Thereafter
Pipeline and storage contracts(a)	$	2,626.2	$	213.2	$	244.8	$	236.0	$	238.2	$	226.5	$	1,467.5
Medium-term notes(b)		691.0		20.0		25.0		-		-		50.0		596.0
Interest expense(c)		624.5		38.9		37.2		36.8		36.8		33.7		441.1
Gas purchase commitments
—Washington Gas(d)		4,522.5		280.0		288.9		336.7		323.2		303.5		2,990.2
—WGEServices(e)		231.1		167.5		49.2		13.8		0.6		-		-
—WGL Midstream(d)		15,453.1		29.2		24.4		80.2		906.0		933.4		13,479.9
Electric purchase commitments(f)		599.7		359.4		171.7		65.0		3.6		-		-
Operating leases		34.8		7.8		6.3		4.9		4.3		1.0		10.5
Business process outsourcing(g)		90.0		32.3		33.4		24.3		-		-		-
Other long-term commitments(h)		21.9		10.1		5.0		4.2		2.2		-		0.4
Total	$	24,894.8	$	1,158.4	$	885.9	$	801.9	$	1,514.9	$	1,548.1	$	18,985.6

^(a)Represents minimum payments for natural gas transportation, storage and peaking contracts that have expiration dates through fiscal year 2044. Additionally, includes minimum payments for WGEServices and WGL Midstream pipeline contracts.

^(b)Represents scheduled repayment of principal. Excludes $8.3 million in debt that is anticipated to be a non-cash extinguishment of project debt financing (refer to the section entitled “Construction Project Financing”).

^(c)Represents the scheduled interest payments associated with MTNs.

^(d)Includes commitments to purchase fixed volumes of natural gas. All contracts are based on market prices, other than contracts for which there is a fixed price.

^(e)Represents commitments based on a combination of market prices at September 30, 2014 and fixed price as well as index priced contract commitments for natural gas delivered to various city gate stations, including the cost of transportation to that point, which is bundled in the purchase price.

^(f)Represents electric purchase commitments that are based on existing fixed price and fixed volume contracts. Also includes $15.3 million related to renewable energy credits.

^(g)Represents fixed costs to the service provider related to the 10-year contract for business process outsourcing. These payments do not reflect potential inflationary adjustments included in the contract. Including these inflationary adjustments, required payments to the service provider could total $107.4 million over the remaining contract term.

^(h)Includes secured supply agreements’ minimum program fees, certain information technology service contracts and committed payments related to certain environmental response costs and excludes uncertain tax positions.

The table above reflects fixed and variable obligations. Certain of these estimates reflect likely purchases under various contracts, and may differ from minimum future contractual commitments disclosed in Note 13 —Commitments of the Notes to Consolidated Financial Statements.

For commitments related to Washington Gas’ pension and post-retirement benefit plans, during fiscal year 2014, Washington Gas did not contribute to its qualified pension plan but did contribute $1.8 million to its non-funded DB SERP. In addition, Washington Gas contributed $16.0 million to its health and life insurance benefit plans during fiscal year 2014. During fiscal year 2015, Washington Gas does not expect to make a contribution to its qualified pension plan but does expect to make a payment totaling $4.1 million to its non-funded DB SERP. Washington Gas expects to make a contribution of $16.6 million to its health and life insurance benefit plans during fiscal year 2015. For a further discussion of our pension and post-retirement benefit plans, refer to Note 10—Pension and Other Post-Retirement Benefit Plans of the Notes to Consolidated Financial Statements.

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Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

Construction Project Financing

To fund certain of its construction projects, Washington Gas enters into financing arrangements with third party lenders. As part of these financing arrangements, Washington Gas’ customers agree to make principal and interest payments over a period of time, typically beginning after the projects are completed. Washington Gas assigns these customer payment streams to the lender. As the lender funds the construction project, Washington Gas establishes a receivable representing its customers’ obligations to remit principal and interest and a long-term payable to the lender. When these projects are formally “accepted” by the customer as completed, Washington Gas transfers the ownership of the receivable to the lender and removes both the receivable and the long-term financing from its financial statements. As of September 30, 2014 and 2013, work on these construction projects that was not completed or accepted by customers was valued at $8.3 million and $6.7 million, respectively, which are recorded on the balance sheet as a receivable in “Deferred Charges and Other Assets—Other” with the corresponding long-term obligation to the lender in “Long-term debt.” At any time before these contracts are accepted by the customer, should there be a contract default, such as, among other things, a delay in completing the project, the lender may call on Washington Gas to fund the unpaid principal in exchange for which Washington Gas would receive the right to the stream of payments from the customer. Construction projects are financed primarily for government agencies, which Washington Gas considers to have minimal credit risk. Based on this assessment and previous collection experience, Washington Gas did not record a corresponding reserve for bad debts related to these receivables at September 30, 2014 and September 30, 2013.

Financial Guarantees

WGL has guaranteed payments primarily for certain purchases of natural gas and electricity on behalf of WGEServices and for certain purchase commitments on behalf of WGL Midstream. At September 30, 2014, these guarantees totaled $227.3 million and $276.5 million for WGEServices and WGL Midstream, respectively. At September 30, 2014, the guarantees relating to WGESystems totaled $6.0 million. The amount of such guarantees is periodically adjusted to reflect changes in the level of financial exposure related to these purchase commitments. For all of our financial guarantees, WGL may cancel any or all future obligations upon written notice to the counterparty, but WGL would continue to be responsible for the obligations created under the guarantees prior to the effective date of the cancellation. WGL also has guaranteed payments for certain of our external partners. At September 30, 2014, these guarantees totaled $18.7 million. At September 30, 2014, WGL’s guarantees for all its subsidiaries and external partners totaled $528.5 million.

Chillum LNG Facility

To meet customer’s forecasted peak demand for natural gas, Washington Gas had incorporated in its plans the construction of a proposed one billion cubic foot LNG storage facility at the Chillum station on land owned by Washington Gas in Chillum, Maryland, where natural gas storage facilities previously existed. Following a legal decision that effectively prevents Washington Gas to utilize the intended site for an LNG storage facility, Washington Gas abandoned its plans to continue this project. The costs incurred under the project totaled $8.5 million. At March 31, 2013, these costs were reclassified from “Property, Plant and Equipment” to “Deferred Charges and Other Assets—Regulatory Assets, Other” in the accompanying balance sheets due to the recoverability of the regulatory asset.

The SCC of VA and the PSC of MD have approved recovery of the costs, but no return is allowed. As a result, Washington Gas has impaired $1.9 million and $0.5 million in fiscal years 2014 and 2013, respectively.

Washington Gas has contracted for sufficient natural gas supply resources to meet the growing forecasted seasonal and design demand. Washington Gas also has planned system infrastructure improvements to assure adequate capacity to fulfill its franchise obligation to provide safe, adequate and reasonably priced natural gas service to its customers.

54

WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

Operating Issues Related To Changes in Natural Gas Supply

In fiscal year 2005, Washington Gas began addressing a significant increase in the number of natural gas leaks on its distribution system in a portion of Prince George’s County, Maryland. Natural gas containing a low concentration of HHCs caused the seals in certain mechanical couplings in Washington Gas’ distribution system to shrink, increasing the propensity for the coupling to leak. Independent laboratory tests performed on behalf of Washington Gas showed that the injection of HHCs offset the effect of the low HHC gas on the seals in couplings, reducing their propensity to leak.

Washington Gas constructed three facilities to inject HHCs into the gas stream entering the Washington Gas distribution system. In addition to injecting HHCs, Washington Gas replaced gas service lines and replaced or rehabilitated gas mains that contained the affected mechanical couplings in Prince George’s County. Additionally, Washington Gas continues to mitigate the impact of low HHC gas from whatever source through accelerating the replacement of mechanically coupled pipeline and the operation of three HHC injection facilities.

The current forecast for replacement of higher risk mains and services, including vintage mechanically coupled mains and services, in Virginia includes expenditures of $204.6 million, over the current five-year period beginning in fiscal year 2015. This represents a part of Washington Gas’ SAVE Plan, which the SCC of VA initially approved on April 21, 2011, and for which the SCC of VA approved an amendment on November 15, 2012. For the District of Columbia, the forecast includes the continuation of the December 16, 2009 settlement in the District of Columbia that includes a targeted mechanically coupled pipe replacement and encapsulation program that is now estimated to cost $49.3 million and is expected to be completed in fiscal year 2016. The first $28.0 million is covered under the rate recovery mechanism approved in the 2009 settlement and the remaining forecasted expenditures are $23.6 million. Additionally, Washington Gas’ request for approval of $110.0 million for the funding of further pipe replacements, under an accelerated pipe replacement program was approved by Order issued by the PSC of DC on August 21, 2014. For Maryland, Washington Gas has budgeted approximately $204.4 million related to the first five years of the planned replacement of higher risk mains and services, including vintage mechanically coupled mains and services, which is part of Washington Gas’ approved STRIDE plan. Rate recovery of the expenditures has been approved by the SCC of VA, the PSC of MD, and the PSC of DC.

55

WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

Constitution Pipeline

In May 2013, WGL Midstream entered into an equity investment in Constitution Pipeline Company, LLC. The pipeline project is designed to transport at least 650,000 dekatherms of natural gas per day from the Marcellus region in northern Pennsylvania to major northeastern markets. Fully contracted with long-term commitments from established natural gas producers currently operating in Pennsylvania, the pipeline will originate from the Marcellus production areas in Susquehanna County, PA, and interconnect with the Iroquois Gas Transmission and Tennessee Gas Pipeline systems in Schoharie County, N.Y.

Constitution Pipeline LLC has extended the range for the pipeline’s target in-service date to late 2015 through 2016 as a result of a longer than expected regulatory and permitting process. An affiliate of Williams Partners will construct, operate and maintain the new 30-inch, 126-mile long transmission pipeline.

WGL Midstream will invest an estimated $72 million in the project for a 10% share in the pipeline venture. WGL Midstream joins Williams Partners L.P. (41% share), Cabot Oil and Gas Corporation (25% share) and Piedmont Natural Gas (24% share) in the project. In June 2013, Constitution Pipeline filed a formal certificate application with FERC.

Central Penn Line Pipeline

In February 2014, WGL Midstream entered into a limited liability company agreement and formed Meade, with COG Holdings LLC, Vega Midstream MPC LLC, and River Road Interests LLC.

Meade was formed to jointly develop and own, together with Transcontinental Gas Pipe Line Company, LLC (Transco), an approximately 177-mile pipeline originating in Susquehanna County, Pennsylvania and extending to Lancaster County, Pennsylvania (Central Penn Line) that will have the capacity to transport and deliver up to approximately 1.7 million dekatherms per day of natural gas. This pipeline will be an integral part of Transco’s recently announced “Atlantic Sunrise” project.

The Central Penn Line, as part of Atlantic Sunrise, is a natural gas pipeline designed to provide new firm transportation capacity from various supply points in northeast Pennsylvania to a delivery point into Transco’s mainline in southeast Pennsylvania. The Central Penn Line currently has a projected in-service date in the second half of 2017. WGL Midstream will invest an estimated $410 million for a 55% interest in Meade, and Meade will invest an estimated $746 million in the Central Penn Line for an approximate 39% interest in the Central Penn Line. Transco will have the remaining ownership interests.

Additionally, in February 2014, WGL Midstream entered into an agreement with Cabot Oil & Gas Corporation (Cabot) whereby WGL Midstream will purchase 500,000 dekatherms per day of natural gas from Cabot over a 15 year term. As part of this agreement, Cabot will acquire 500,000 dekatherms per day of firm gas transportation capacity on Transco’s Atlantic Sunrise project of which the Central Penn Line is a part. This capacity will be released to WGL Midstream.

CREDIT RISK

Wholesale Credit Risk

Certain wholesale suppliers that sell natural gas to any or all of Washington Gas, WGEServices, and WGL Midstream may have relatively low credit ratings or may not be rated by major credit rating agencies.

Washington Gas enters into transactions with wholesale counterparties for the purpose of meeting firm ratepayer commitments, to optimize the value of its long-term capacity assets, and for hedging natural gas costs. In the event of a counterparty’s failure to deliver contracted volumes of gas or fulfill its payment obligations, Washington Gas may incur losses that would typically be passed through to its sales customers under the purchased gas cost adjustment mechanisms. Washington Gas may be at risk for financial loss to the extent these losses are not passed through to its customers.

For WGEServices, any failure of wholesale counterparties to deliver natural gas or electricity under existing contracts could cause financial exposure for the difference between the price at which WGEServices has contracted to buy these commodities and their replacement cost from another supplier. To the extent that WGEServices sells natural gas to these wholesale counterparties, WGEServices may be exposed to payment risk if WGEServices is in a net receivable position. Additionally, WGEServices enters into contracts with counterparties to hedge the costs of natural gas and electricity. Depending on the ability of the counterparties to fulfill their commitments, WGEServices could be at risk for financial loss.

WGL Midstream enters into transactions with wholesale counterparties to hedge and optimize its portfolio of owned and managed natural gas assets. Any failure of wholesale counterparties to deliver natural gas under existing contracts could cause financial exposure for the difference between the price at which WGL Midstream has contracted to buy these commodities and their replacement cost. To the extent that WGL Midstream sells natural gas to these wholesale counterparties, WGL Midstream may be exposed to payment risk if it is in a net receivable position. In addition, WGL Midstream enters into contracts with counterparties to hedge the costs of natural gas. Depending on the ability of the counterparties to fulfill their commitments, WGL Midstream could be at risk for financial loss.

56

WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

Washington Gas, WGEServices, and WGL Midstream operate under an existing wholesale counterparty credit policy that is designed to mitigate credit risks through requirements for credit enhancements including, but not limited to, letters of credit, parent guarantees and cash collateral when deemed necessary. In accordance with this policy, Washington Gas, WGEServices, and WGL Midstream have each obtained credit enhancements from certain of their counterparties. If certain counterparties or their guarantors meet the policy’s creditworthiness criteria, Washington Gas, WGEServices, and WGL Midstream may grant unsecured credit to those counterparties or their guarantors. The creditworthiness of all counterparties is continuously monitored.

Washington Gas, WGEServices and WGL Midstream are also subject to the collateral requirements of their counterparties. At September 30, 2014, Washington Gas, WGEServices and WGL Midstream provided $8.2 million, $11.0 million and $11.4 million in cash collateral to counterparties, respectively.

The following table provides information on our credit exposure, net of collateral, to wholesale counterparties as of September 30, 2014 for Washington Gas, WGEServices and WGL Midstream, separately.

Credit Exposure to Wholesale Counterparties ($ In millions)
Rating(a)		Exposure Before Credit Collateral(b)			Offsetting Credit Collateral Held(c)		Net Exposure		Number of Counterparties Greater Than 10%(d)		Net Exposure of  Counterparties  Greater Than 10%
Washington Gas
Investment Grade	$		24.1	$		1.4	$	22.7	3	$		16.7
Non-Investment Grade			2.2			2.2		-	-			-
No External Ratings			1.0			-		1.0	-			-
WGEServices
Investment Grade	$		4.1	$		-	$	4.1	2	$		4.1
Non-Investment Grade			-			-		-	-			-
No External Ratings			-			-		-	-			-
WGL Midstream
Investment Grade	$		12.6	$		0.1	$	12.5	2	$		11.1
Non-Investment Grade			-			-		-	-			-
No External Ratings			2.7			-		2.7	1			2.5

^(a) Investment Grade is primarily determined using publicly available credit ratings of the counterparty. If the counter party has provided a guarantee by a higher-rated entity (e.g., its parent), it is determined based upon the rating of it guarantor. Included in “Investment Grade” are counterparties with a minimum Standard & Poor’s or Moody’s Investor Service rating of BBB- or Baa3, respectively.

^(b) Includes the net of all open positions on energy-related derivatives subject to mark-to-market accounting requirements, the net receivable/payable for realized transactions and net open positions for contracts designated as normal purchases and normal sales and not recorded on our balance sheet. Amounts due from counterparties are offset by liabilities payable to those counterparties to the extent that legally enforceable netting arrangements are in place.

^(c) Represents cash deposits and letters of credit received from counterparties, not adjusted for probability of default.

^(d) Using a percentage of the net exposure.

Retail Credit Risk

Washington Gas is exposed to the risk of non-payment of utility bills by certain of its customers. To manage this customer credit risk, Washington Gas may require cash deposits from its high risk customers to cover payment of their bills until the requirements for the deposit refunds are met. In addition, Washington Gas implemented a POR program as approved by the PSC of MD, whereby it purchases receivables from participating energy marketers at approved discount rates. Under the program, Washington Gas is exposed to the risk of non-payment by the retail customers for these receivables. This risk is factored into the approved discount rate at which Washington Gas purchases the receivables.

WGEServices is also exposed to the risk of non-payment by its retail customers. WGEServices manages this risk by evaluating the credit quality of certain new customers as well as by monitoring collections from existing customers. To the extent necessary, WGEServices can obtain collateral from, or terminate service to, its existing customers based on credit quality criteria. In addition, WGEServices participates in POR programs with certain Maryland, District of Columbia and Pennsylvania utilities, whereby it sells its receivables to various utilities at approved discount rates. Under the POR programs, WGEServices is exposed to the risk of non-payment by its retail customers for delivered commodities that have not yet been billed. Once the invoices are billed, however, the associated credit risk is assumed by the purchasing utilities that sponsor POR programs. While participation in POR programs reduce the risk of collection and fixes a discount rate on the receivables, there is a risk that the discount rate paid to participate in the POR program will exceed the actual bad debt expense and billing fees associated with these receivables.

57

WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

WGESystems is subject to retail credit risk associated with customers who purchase electricity under long term agreements from distributed generation assets owned by the company. The customers undergo credit evaluation prior to contract execution and are monitored periodically during the contract term for payment performance and credit quality. These steps mitigate credit risk associated with the distributed generation asset customers.

WGSW is indirectly subject to retail credit risk associated with non-payment by customers who lease distributed energy equipment or maintain energy service agreements through ASD Solar LP, Nextility (formerly known as Skyline Innovations, Inc.) and SunEdison. This credit risk is mitigated with minimum credit quality criteria established in each of WGSW’s agreements. These criteria must be satisfied for WGSW to participate in the project financing arrangement or partnership interest.

WGL Midstream is not subject to retail credit risk.

MARKET RISK

We are exposed to various forms of market risk including commodity price risk, weather risk and interest-rate risk. The following discussion describes these risks and our management of them.

Price Risk Related to the Regulated Utility Segment

Washington Gas faces price risk associated with the purchase and sale of natural gas. Washington Gas generally recovers the cost of the natural gas to serve customers through gas cost recovery mechanisms as approved in jurisdictional tariffs; therefore, a change in the price of natural gas generally has no direct effect on Washington Gas’ net income. However, Washington Gas is responsible for following competitive and reasonable practices in purchasing natural gas for its customers.

To manage price risk associated with its natural gas supply to its firm customers, Washington Gas: (i) actively manages its gas supply portfolio to balance sales and delivery obligations; (ii) injects natural gas into storage during the summer months when prices are historically lower, and withdraws that gas during the winter heating season when prices are historically higher and (iii) enters into hedging contracts and other contracts that qualify as derivative instruments related to the sale and purchase of natural gas.

Washington Gas executes commodity-related physical and financial contracts in the form of forward, futures and option contracts as part of an asset optimization program that is managed by its internal staff. These transactions are accounted for as derivatives. Under this program, Washington Gas realizes value from its long-term natural gas transportation and storage capacity resources when not being fully used to serve utility customers. Regulatory sharing mechanisms in all three jurisdictions allow the profit from these transactions to be shared between Washington Gas’ customers and shareholders.

The following two tables summarize the changes in the fair value of our net assets (liabilities) associated with the Regulated Utility segment’s energy-related derivatives during the fiscal year ended September 30, 2014.

Regulated Utility Segment
Changes in Fair Value of Energy-Related Derivatives
(In millions)
Net assets (liabilities) at September 30, 2013	$	(107.7	)
Net fair value of contracts entered into during the period		(19.1	)
Other changes in net fair value		(211.5	)
Realized net settlement of derivatives		56.1
Net assets (liabilities) at September 30, 2014	$	(282.2	)
Regulated Utility Segment
Roll Forward of Energy-Related Derivatives
(In millions)
Net assets (liabilities) at September 30, 2013	$	(107.7	)
Recorded to income		(87.3	)
Recorded to regulatory assets/liabilities		(143.3	)
Realized net settlement of derivatives		56.1
Net assets (liabilities) at September 30, 2014	$	(282.2	)

58

WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

The maturity dates of our net assets (liabilities) associated with the regulated utility segment’s energy-related derivatives recorded at fair value at September 30, 2014, is summarized in the following table based on the level of the fair value calculation under ASC Topic 820:

Regulated Utility Segment
Maturity of Net Assets (Liabilities) Associated with our Energy-Related Derivatives
	Years Ended September 30,
(In millions)	Total			2015			2016			2017			2018			2019			Thereafter
Level 1 — Quoted prices in active markets	$	-		$	-		$	-		$	-		$	-		$	-		$	-
Level 2 — Significant other observable inputs		(11.6	)		(6.8	)		(4.4	)		(0.2	)		(0.2	)		-			-
Level 3 — Significant unobservable inputs		(270.6	)		(23.9	)		(23.9	)		(32.2	)		(22.7	)		(21.1	)		(146.8)
Total net assets (liabilities) associated with our energy-related derivatives	$	(282.2	)	$	(30.7)		$	(28.3	)	$	(32.4	)	$	(22.9	)	$	(21.1	)	$	(146.8)

Fair value changed due primarily to unfavorable movements in the unobservable inputs used in the valuation of long-dated forwards. We believe that this value is not reflective of our ultimate cash flows as these purchases are utilized in the optimization of our long-term natural gas transportation and storage capacity resources, which are not reflected at fair value. Refer to Note 14, Derivative and Weather-Related Instruments and Note 15, Fair Value Measurements of the Notes to Consolidated Financial Statements for a further discussion of our derivative activities and fair value measurements.

Price Risk Related to the Non-Utility Segments

Retail Energy Marketing. Our retail energy-marketing subsidiary, WGEServices, sells natural gas and electricity to retail customers at both fixed and indexed prices. WGEServices must manage daily and seasonal demand fluctuations for these products with its suppliers. Price risk exists to the extent WGEServices does not closely match the timing and volume of natural gas and electricity it purchases with the related fixed price or indexed sales commitments. WGEServices’ risk management policies and procedures are designed to minimize this risk.

A portion of WGEServices’ annual natural gas sales volumes is subject to variations in customer demand associated with fluctuations in weather and other factors. Purchases of natural gas to fulfill retail sales commitments are generally made under fixed-volume contracts based on certain weather assumptions. If there is significant deviation from normal weather or from other factors that affect customer usage, purchase commitments may differ significantly from actual customer usage. To the extent that WGEServices cannot match its customer requirements and supply commitments, it may be exposed to commodity price and volume variances, which could negatively impact expected gross margins (refer to the section entitled “Weather Risk” for a further discussion of our management of weather risk). WGEServices manages these risks through the use of derivative instruments, including financial products.

WGEServices procures electricity supply under contract structures in which WGEServices assumes the responsibility of matching its customer requirements with its supply purchases. WGEServices assembles the various components of supply, including electric energy from various suppliers, and capacity, ancillary services and transmission service from the PJM Interconnection, a regional transmission organization, in matching its customer requirements obligations. While the capacity and transmission costs within PJM are generally stable and identifiable several years into the future, the cost of ancillary services which support the reliable operation of the transmission system, does fluctuate as changes occur in the balance between generation and the consumption mix within the electric system. WGEServices could be exposed to price risk associated with changes in ancillary costs due to lack of available forward market products to sufficiently hedge those risks.

To the extent WGEServices has not sufficiently matched its customer requirements with its supply commitments, it could be exposed to electricity commodity price risk. WGEServices may manage this risk through the use of derivative instruments, including financial products.

WGEServices’ electric business is also exposed to fluctuations in weather and varying customer usage. Purchases generally are made under fixed-price, fixed-volume contracts that are based on certain weather assumptions. If there are significant deviations in weather or usage from these assumptions, WGEServices may incur price and volume variances that could negatively impact expected gross margins (refer to the section entitled “Weather Risk” for a further discussion of our management of weather risk).

59

WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

The following two tables summarize the changes in the fair value of our net assets (liabilities) associated with the Retail Energy-Marketing segment’s energy-related derivatives during the fiscal year ended September 30, 2014.

Retail Energy-Marketing Segment Changes in Fair Value of Energy-Related Derivatives
(In millions)
Net assets (liabilities) at September 30, 2013	$	(10.4)
Net fair value of contracts entered into during the period		1.9
Other changes in net fair value		10.0
Realized net settlement of derivatives		(6.9)
Net assets (liabilities) at September 30, 2014	$	(5.4)
Retail Energy-Marketing Segment Roll Forward of Energy-Related Derivatives
(In millions)
Net assets (liabilities) at September 30, 2013	$	(10.4)
Recorded to income		10.3
Recorded to accounts payable		1.6
Realized net settlement of derivatives		(6.9)
Net assets (liabilities) at September 30, 2014	$	(5.4)

The maturity dates of our net assets (liabilities) associated with the retail energy-marketing segments’ energy-related derivatives recorded at fair value at September 30, 2014 is summarized in the following table based on the level of the fair value calculation under ASC Topic 820:

Retail Energy-Marketing Segment Maturity of Net Assets (Liabilities) Associated with our Energy-Related Derivatives
	Years Ended September 30,
(In millions)	Total			2015			2016			2017			2018		2019		Thereafter
Level 1 — Quoted prices in active markets	$	-		$	-		$	-		$	-		$	-	$	-	$	-
Level 2 — Significant other observable inputs		0.6			2.1			(1.5	)		-			-		-		-
Level 3 — Significant unobservable inputs		(6.0	)		(2.1	)		(3.4	)		(0.5	)		-		-		-
Total net assets (liabilities) associated with our energy-related derivatives	$	(5.4	)	$	-		$	(4.9	)	$	(0.5	)	$	-	$	-	$	-

Refer to Note 14, Derivative and Weather-Related Instruments and Note 15, Fair Value Measurements of the Notes to Consolidated Financial Statements for a further discussion of our derivative activities and fair value measurements.

Commercial Energy Systems. WGESystems sells electricity and SRECs from distributed generation assets. The sale of electricity is under long term power purchase agreements (PPAs) with a general duration of 20 years, while the sale of SRECs are usually under short term or immediate delivery contracts. Price risk exists through the components used to achieve the target rate of return because the electricity price is based on the cost of the distributed generation assets. Price risk also exists to the extent the sale of SRECs are at prices less than planned or expected prices included in the project design. WGESystems manages this price risk through the execution of PPAs for the sale of electricity and forward sales of SRECs when possible

        WGSW holds project financing arrangements and a limited partnership interest associated with distributed generating solar assets for a fair market value based on an independent appraisal. The project financing arrangements allow WGSW to lease back those solar assets to the counterparty with a fixed target rate of return over a period of 6-20 years. Price risk exists through the components used to achieve the target rate of return since the components are based on market leasing prices for retail customers and cost of solar panels. Similarly, in WGSW’s limited partnership interest, solar assets are purchased by and leased to retail customers through the partnership. The purchased solar assets are expected to achieve a target rate of return from the lease payments being collected from the retail customers, therefore the price risk exists between the leasing prices for solar assets and the purchase price of the solar assets. WGSW manages this price risk through its investment agreements and evaluation of the asset purchase in conjunction with the inception of the lease. Refer to Note 14, Derivative and Weather-Related Instruments and Note 15, Fair Value Measurements of the Notes to Consolidated Financial Statements for a further discussion of our derivative activities and fair value measurements.

Midstream Energy Services. WGL Midstream engages in wholesale commodity transactions to optimize its owned and managed natural gas assets. Price risk exists to the extent WGL Midstream does not closely match the volume of physical natural gas in storage with the related forward sales entered into as hedges. WGL Midstream mitigates this risk by actively managing and hedging these assets in accordance with corporate risk management policies and procedures. Depending upon the nature of its forward hedges, WGL Midstream may also be exposed to fluctuations in mark-to-market valuations based on changes in forward price curves. WGL Midstream pays fixed, fair market prices for its owned storage assets and is subject to variations in annual summer-winter spreads associated with weather and other market factors. To the extent there are significant variations in weather, WGL Midstream may incur price variances that negatively impact expected gross margins (refer to the section entitled “Weather Risk” for a further discussion of our management of weather risk). WGL Midstream manages this risk through the use of derivative instruments, including financial products.

60

WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

The following two tables summarize the changes in the fair value of our net assets (liabilities) associated with the Midstream Energy Services segments’ energy-related derivatives during the fiscal year ended September 30, 2014.

Midstream Energy Services Changes in Fair Value of Energy-Related Derivatives
(In millions)
Net assets (liabilities) at September 30, 2013	$	(10.5)
Net fair value of contracts entered into during the period		(2.5)
Other changes in net fair value		(19.5)
Realized net settlement of derivatives		3.5
Net assets (liabilities) at September 30, 2014	$	(29.0)
Midstream Energy Services Roll Forward of Energy-Related Derivatives
(In millions)
Net assets (liabilities) at September 30, 2013	$	(10.5)
Recorded to income		(22.0)
Realized net settlement of derivatives		3.5
Net assets (liabilities) at September 30, 2014	$	(29.0)

The maturity dates of our net assets (liabilities) associated with the Midstream Energy Services segments’ energy-related derivatives recorded at fair value at September 30, 2014 is summarized in the following table based on the level of the fair value calculation under ASC Topic 820:

Midstream Energy Services Maturity of Net Assets (Liabilities) Associated with our Energy-Related Derivatives
	Years Ended September 30,
(In millions)	Total			2015			2016			2017			2018			2019			Thereafter
Level 1 — Quoted prices in active markets	$	-		$	-		$	-		$	-		$	-		$	-		$	-
Level 2 — Significant other observable inputs		(5.9	)		(5.9	)		-			-			-			-			-
Level 3 — Significant unobservable inputs		(23.1	)		0.1			(6.4	)		(5.9	)		(3.4	)		(2.5	)		(5.0	)
Total net assets (liabilities) associated with our energy-related derivatives	$	(29.0	)	$	(5.8	)	$	(6.4	)	$	(5.9	)	$	(3.4	)	$	(2.5	)	$	(5.0	)

Fair value changed primarily due to movements in unobservable inputs used in the valuation of long-dated forward contracts. We believe that this value is not reflective of our ultimate cash flows as these purchases are utilized in the optimization of our long-term natural gas transportation and storage capacity resources, which are not reflected at fair value.

Value-at-Risk. WGEServices measures the market risk of its energy commodity portfolio by determining its value-at-risk. Value-at-risk is an estimate of the maximum loss that can be expected at some level of probability if a portfolio is held for a given time period. The value-at-risk calculation for natural gas and electric portfolios include assumptions for normal weather, new customers and renewing customers for which supply commitments have been secured. Based on a 95% confidence interval for a one-day holding period, WGEServices’ value-at-risk at September 30, 2014 was approximately $64,900 and $144,300, related to its natural gas and electric portfolios, respectively. At September 30, 2013, WGEServices’ value-at-risk was approximately $14,900 and $36,100, related to its natural gas and electric portfolios, respectively. The increases to WGEServices’ value-at-risk of its natural gas and electric portfolios were driven by increased market prices as a result of colder than normal weather. At September 30, 2014 and 2013, the high, low and average value-at risk for natural gas and electric portfolios are noted in the table below.

WGEServices

Value-at-Risk at September 30, 2014

(In thousands)	High		Low		Average
Natural Gas Portfolio	$	397,000	$	13,900	$	95,800
Electric Portfolio		284,700		10,100		72,400
Total	$	681,700	$	24,000	$	168,200

WGEServices

Value-at-Risk at September 30, 2013

(In thousands)	High		Low		Average
Natural Gas Portfolio	$	74,500	$	200	$	10,500
Electric Portfolio		64,500		7,700		20,200
Total	$	139,000	$	7,900	$	30,700

61

WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

Weather Risk

We are exposed to various forms of weather risk in both our regulated utility and non-utility business segments. To the extent Washington Gas does not have weather-related instruments or billing adjustment mechanisms in place, its revenues are volume driven and its current rates are based upon an assumption of normal weather. Without weather protection strategies, variations from normal weather will cause our earnings to increase or decrease depending on the weather pattern. Washington Gas currently has a weather protection strategy that is designed to minimize the estimated financial effects of weather on its net income within a reasonable range of weather expectations, as discussed below.

The financial results of our retail energy-marketing business, WGEServices, are affected by variations from normal weather primarily in the winter relating to its natural gas sales, and throughout the fiscal year relating to its electricity sales. WGEServices manages these weather risks with, among other things, weather-related instruments.

Variations from normal weather may also affect the financial results of our midstream energy business, WGL Midstream, primarily with regards to summer - winter storage spreads and in transportation spreads throughout the fiscal year. WGL Midstream manages these weather risks with, among other things, location, physical and financial basis hedging.

Billing Adjustment Mechanisms. In Maryland, Washington Gas has a Revenue Normalization Adjustment (RNA) billing mechanism that is designed to stabilize the level of net revenues collected from Maryland customers by eliminating the effect of deviations in customer usage caused by variations in weather from normal levels and other factors such as conservation. In Virginia, Washington Gas has a Weather Normalization Adjustment (WNA) billing adjustment mechanism that is designed to eliminate the effect of variations in weather from normal levels on utility net revenues. Additionally, as part of the Conservation and Ratemaking Efficiency (CARE) plan, Washington Gas has a Care Ratemaking Adjustment (CRA) mechanism that, coupled with the WNA, eliminates the effect of both weather and other factors such as conservation for residential, small commercial and industrial and group metered apartment customers in Virginia. For a discussion of current rates and regulatory matters, refer to the section entitled “Rates and Regulatory Matters” in Management’s Discussion & Analysis for Washington Gas.

For the RNA, WNA, and CRA mechanisms, periods of colder-than-normal weather generally would cause Washington Gas to record a reduction to its revenues and establish a refund liability to customers, while the opposite would generally result during periods of warmer-than-normal weather. However, factors such as volatile weather patterns and customer conservation may cause the RNA and the CRA mechanisms to function conversely because they adjust billed revenues to provide a designed level of net revenue per meter.

Weather-Related Instruments. There were no derivative instruments hedging variations from normal weather in the District of Columbia for fiscal year 2014. On August 15, 2012, Washington Gas executed Heating Degree Day (HDD) weather-related derivative contracts to manage its financial exposure to variations from normal weather in the District of Columbia for fiscal year 2013, resulting in a net premium payment to Washington Gas of $1.0 million. Under these contracts, Washington Gas purchased protections against net revenue shortfalls due to warmer-than-normal weather and sold colder-than-normal weather benefits.

On November 8, 2013, Washington Gas filed an application for approval of a Weather Normalization Adjustment (WNA) before the Public Service Commission of the District of Columbia. The proposal would authorize Washington Gas to implement a rate design mechanism that would eliminate the variability of weather from the calculation of revenues and offer customers more stability in their bills during colder than normal winter heating seasons. Comments and replies have been filed regarding Washington Gas’ application, which is pending before the PSC of DC.

WGEServices utilizes HDD instruments from time to time to manage weather risks related to its natural gas and electricity sales. WGEServices also utilizes cooling degree day (CDD) instruments and other instruments to manage weather and price risks related to its electricity sales during the summer cooling season. These instruments cover a portion of WGEServices’ estimated revenue or energy-related cost exposure to variations in HDDs or CDDs. Refer to Note 14—Derivative and Weather-Related Instruments of the Notes to Consolidated Financial Statements for further discussion of the accounting for these weather-related instruments.

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WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

Interest-Rate Risk

We are exposed to interest-rate risk associated with our short-term and long-term financing. WGL utilizes derivative instruments from time to time in order to minimize its exposure to the risk of interest-rate volatility.

Short-Term Debt. At September 30, 2014 and 2013, WGL Holdings and its subsidiaries had outstanding notes payable of $453.5 million and $373.1 million, respectively. The carrying amount of our short-term debt approximates fair value. In fiscal year 2014, a change of 100 basis points in the underlying average interest rate for our short-term debt would have caused a change in interest expense of approximately $3.2 million.

Long-Term Debt. At September 30, 2014, we had outstanding fixed-rate MTNs and other long-term debt aggregating $679.3 million, excluding current maturities and unamortized discounts. While fixed-rate debt does not expose us to earnings risk when market interest rates change, such debt is subject to changes in fair value. Fair value is defined as the present value of the debt securities’ future cash flows discounted at interest rates that reflect market conditions as of the remeasurement date. As of September 30, 2014, the fair value of our fixed-rate debt was $809.3 million. Our sensitivity analysis indicates that fair value would increase by approximately $33.7 million or decrease by approximately $31.4 million if interest rates were to decline or increase by 10%, respectively. from current market levels. In general, such an increase or decrease in fair value would impact earnings and cash flows only if Washington Gas were to reacquire some or all of these instruments in the open market prior to their maturity.

A total of $527.5 million, or approximately 78.6%, of Washington Gas’ outstanding MTNs, excluding current maturities, have make-whole call options which, if exercised, would require us to pay a premium over the face amount.

Derivative Instruments. WGL and Washington Gas utilize derivative instruments from time to time in order to minimize its exposure to the risk of interest-rate volatility. On July 18, 2013, Washington Gas entered into a forward starting swap in anticipation of its December 2013 MTN issuance. The swap was terminated on December 2, 2013 at a gain to Washington Gas of $1.2 million. During September 2014, WGL entered into interest rate swaps associated with an expected $150.0 million debt issuance. WGL elected cash flow hedge accounting for its interest rate derivative instruments. Therefore, the effective portion of the gains and losses on the hedge are recorded within other comprehensive income and are expected to be amortized over the life of the debt (through 2044). In connection with the issuance of the 2044 Notes, WGL settled forward starting swap hedges for $75.0 million and $50.0 million, both of which resulted in payments to the counterparties of $4.6 million and $3.1 million, respectively. On September 12, 2014, Washington Gas entered into a forward starting swap in anticipation of its September 25, 2014 MTN issuance. The swap was terminated on September 25, 2014 for a loss of $1.0 million. On September 24, 2014, WGL entered into forward starting swaps associated with an expected $150.0 million issuance of 30-year debt. WGL elected cash flow hedge accounting for these interest rate derivative instruments. In connection with the issuance of $125.0 million of debt on October 22, 2014, WGL settled a portion of the interest rate hedge for a loss of $7.7 million. $25.0 million of the interest rate hedge remains outstanding related to the remaining debt issuance expected in December 2014. The unsettled portion of the interest rate hedge of $25 million is outstanding related to the remaining debt issuance expected in December 2014. Refer to the section entitled “Long-Term Cash Requirements and Related Financing” for further discussion of our interest-rate risk management activity.

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WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

WASHINGTON GAS LIGHT COMPANY

This section of Management’s Discussion focuses on Washington Gas for the reported periods. In many cases, explanations and disclosures for both WGL and Washington Gas are substantially the same.

RESULTS OF OPERATIONS

The results of operations for the regulated utility segment and Washington Gas are substantially the same; therefore, this section primarily focuses on statistical information and other information that is not discussed in the results of operations for the regulated utility segment. Refer to the section entitled “Results of Operations—Regulated Utility” for a detailed discussion of the results of operations for the regulated utility segment.

Washington Gas’ net income applicable to its common stock was $97.0 million, $71.0 million and $108.7 million for the fiscal years ended September 30, 2014, 2013 and 2012, respectively. Net income increased $26.0 million in fiscal year 2014 compared to fiscal year 2013 primarily due to:

• higher net revenues attributed to the colder weather impacts during 2014 that were in excess of our weather protection provisions;

• higher revenues due to new base rates in Maryland and the District of Columbia;

• increase in revenues related to the growth of more than 12,200 average active customer meters;

• favorable effects of changes in natural gas consumption patterns in the District of Columbia;

• surcharge-based rate recovery related to the accelerated pipeline replacement programs;

• higher realized margins associated with our asset optimization program;

• lower expenses related to operations and maintenance activities; and a

• decrease in the effective tax rate primarily due to the reinstatement of regulatory assets related to the tax effect of Med D and tax sharing among the consolidated affiliates.

Partially offsetting these favorable variances were:

• higher unrealized losses associated with our asset optimization program; and

• higher depreciation expense due to the growth in investment in utility plant.

Net income for fiscal year 2013 decreased $37.7 million compared to fiscal year 2012 primarily due to:

• a decrease in unrealized margins associated with our asset optimization program;

• an increase in employee incentives and benefits primarily due to a decrease in the discount rate;

• recoveries in fiscal year 2012 (adjusted by recoveries in fiscal year 2013) associated with a loss previously recognized in 2011 for refunds to customers ordered by the PSC of MD related to a cash settlement of gas imbalances with competitive service providers and

• higher depreciation expense due to the growth in investment in utility plant.

Partially offsetting these unfavorable variances were:

• higher net revenues that were in excess of our weather protection provisions; attributed to the weather that was essentially normal compared to the warm weather impacts of 2012;

• higher revenues due to rate relief in Maryland and the District of Columbia;

• lower bad debt expense due to a reduction in customer delinquencies and charge-offs;

• lower environmental expense due primarily to net insurance proceeds;

• an increase in revenues related to the growth in average active customer meters;

• favorable effects of changes in natural gas consumption patterns in the District of Columbia; and

• lower income taxes due to a decrease in the effective tax rate driven primarily by the write-off in 2012 of regulatory assets related to the tax effects of Med D.

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Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

Key gas delivery, weather and meter statistics are shown in the table below for the fiscal years ending September 30, 2014, 2013 and 2012.

Gas Deliveries, Weather and Meter Statistics
	Years Ended September 30,									Increase (decrease)
	2014			2013			2012			2014 vs. 2013		2013 vs. 2012
Gas Sales and Deliveries (millions of therms)
Firm
Gas sold and delivered		939.1			841.4			689.7			97.7		151.7
Gas delivered for others		535.5			488.2			436.7			47.3		51.5
Total firm		1,474.6			1,329.6			1,126.4			145.0		203.2
Interruptible
Gas sold and delivered		2.2			2.9			2.0			(0.7)		0.9
Gas delivered for others		267.7			270.9			243.0			(3.2)		27.9
Total interruptible		269.9			273.8			245.0			(3.9)		28.8
Electric generation—delivered for others		144.4			177.5			343.2			(33.1)		(165.7)
Total deliveries		1,888.9			1,780.9			1,714.6			108.0		66.3
Degree Days
Actual		4,111			3,769			3,036			342		733
Normal		3,751			3,775			3,799			(24)		(24)
Percent colder (warmer) than normal		9.6	%		(0.2	)%		(20.1	)%		n/a		n/a
Average active customer meters		1,116,527			1,104,283			1,093,351			12,244		10,932
New customer meters added		13,327			12,468			11,250			859		1,218

Gas Service to Firm Customers

The volume of gas delivered to firm customers is highly sensitive to weather variability as a large portion of the natural gas delivered by Washington Gas is used for space heating. Washington Gas’ rates are based on an assumption of normal weather. The tariffs in the Maryland and Virginia jurisdictions include provisions that consider the effects of the RNA and the WNA/CRA mechanisms, respectively, that are designed to, among other things, eliminate the effect on net revenues of variations in weather from normal levels (refer to the section entitled “Weather Risk” for a further discussion of these mechanisms and other weather-related instruments included in our weather protection strategy).

Fiscal Year 2014 vs. Fiscal Year 2013. During the fiscal year ended 2014, total gas deliveries to firm customers were 1,474.6 billion therms, an increase of 145.0 million therms from 1,329.6 billion therms in fiscal year 2013. This comparison in natural gas deliveries to firm customers primarily reflects colder weather in the current fiscal year than the prior year and an increase in average active customer meters of 12,244.

Weather, when measured by HDDs for fiscal year 2014 was 9.6% colder than normal, compared to 0.2% warmer than normal for fiscal year 2013. There was a $5.3 million favorable impact to pre-tax income attributed to colder weather for the year ended September 30, 2014 and no material effects on net income attributed to colder or warmer than normal weather during fiscal year 2013.

Many customers choose to buy the natural gas commodity from unregulated third party marketers, rather than purchase the natural gas commodity and delivery service from Washington Gas on a “bundled” basis. Natural gas delivered to firm customers but purchased from unregulated third party marketers represented 36.3% of total firm therms delivered during fiscal year 2014, compared to 36.7% of therms delivered during fiscal year 2013. On a per unit basis, Washington Gas earns the same net revenues from delivering gas for others as it earns from bundled gas sales in which customers purchase both the natural gas commodity and the associated delivery service from Washington Gas. Therefore, Washington Gas does not experience any loss in utility net revenues when customers choose to purchase the natural gas commodity from an unregulated third party marketer.

Fiscal Year 2013 vs. Fiscal Year 2012. During the fiscal year ended 2013, total gas deliveries to firm customers were 1,329.6 billion therms, an increase of 203.2 million therms from 1,126.4 billion therms in fiscal year 2012. This comparison in natural gas deliveries to firm customers primarily reflects colder weather in the current fiscal year than the prior year and an increase in average active customer meters of 10,932.

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WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

Weather, when measured by HDDs for fiscal year 2013 was 0.2% warmer than normal, compared to 20.1% warmer than normal for fiscal year 2012. Including the effects of our weather protection strategy, there were no material effects on net income attributed to colder or warmer than normal weather during fiscal year 2013. Due to the extremely warm weather, our weather protection instruments were not sufficient to offset approximately $3.4 million of the reduction in revenue for the year ended September 30, 2012.

Natural gas delivered to firm customers but purchased from unregulated third party marketers represented 36.7% of total firm therms delivered during fiscal year 2013, compared to 38.8% of therms delivered during fiscal year 2012.

Gas Service to Interruptible Customers

Washington Gas must curtail or interrupt service to this class of customer when the demand by firm customers exceeds specified levels. Therm deliveries to interruptible customers decreased by 3.9 million therms in fiscal year 2014 compared to fiscal year 2013, reflecting interruptions to serve firm customers’ increased demand due to colder weather. Therm deliveries to interruptible customers increased by 28.8 million therms in fiscal year 2013 compared to fiscal year 2012, reflecting the conversion of a major contract from firm service to this class and increased demand due to colder weather compared to 2012.

In the District of Columbia, the effect on net income of any changes in delivered volumes and prices to interruptible customers is limited by margin-sharing arrangements that are included in Washington Gas’ rate designs in the District of Columbia. In the District of Columbia, Washington Gas shares a majority of the margins earned on interruptible gas sales and deliveries with firm customers. A portion of the fixed costs for servicing interruptible customers is collected through the firm customers’ rate design. Rates for interruptible customers in Maryland and Virginia are based on a traditional cost of service approach. In Virginia, Washington Gas retains all revenues above a pre-approved margin threshold level. In Maryland, Washington Gas retains a defined amount of revenues based on a set threshold.

Gas Service for Electric Generation

Washington Gas delivers natural gas for use at two electric generation facilities in Maryland that are each owned by companies independent of WGL. During fiscal year 2014, deliveries to these customers decreased by 33.1 million therms from fiscal year 2013. During fiscal year 2013, deliveries to these customers decreased by 165.7 million therms from fiscal year 2012. Washington Gas shares with firm customers a significant majority of the margins earned from natural gas deliveries to these customers. Therefore, changes in the volume of interruptible gas deliveries to these customers do not materially affect either net revenues or net income.

Cost of Gas

Washington Gas’ cost of natural gas purchased includes both fixed and variable components. Washington Gas pays fixed costs or “demand charges” to pipeline companies for system capacity needed to transport and store natural gas. Washington Gas pays variable costs, or the cost of the natural gas commodity itself, to natural gas producers and suppliers. Variations in the utility’s cost of gas expense result from changes in gas sales volumes, the price of the gas purchased and the level of gas costs collected through the operation of firm gas cost recovery mechanisms. Under these regulated recovery mechanisms, Washington Gas records cost of gas expense equal to the cost of gas recovered from customers and included in revenues. The difference between the firm gas costs incurred and the gas costs recovered from customers is deferred on the balance sheet as an amount to be collected from or refunded to customers in future periods. Therefore, increases or decreases in the cost of gas associated with sales made to firm customers have no direct effect on Washington Gas’ net revenues and net income. Changes in the cost of gas can cause significant variations in Washington Gas’ cash provided by or used in operating activities. Washington Gas receives from or pays to its customers in the District of Columbia and Virginia, carrying costs associated with under-collected or over-collected gas costs recovered from its customers using short-term interest rates. Additionally, included in “Utility cost of gas” for Washington Gas are the net margins associated with our internal asset optimization program. To the extent these amounts are shared with customers, they are a reduction to the cost of gas invoiced to customers. Refer to the section entitled “Market Risk” for a further discussion of Washington Gas’ optimization program.

The commodity cost of gas invoiced to Washington Gas (excluding the cost and related volumes applicable to asset optimization) were $0.56, $0.38, and $0.44 per therm for fiscal years 2014, 2013 and 2012, respectively.

Revenue Taxes

Revenue taxes are comprised of gross receipts taxes, public service commission fees, franchise fees and energy taxes. Changes in revenue taxes reflect changes in the volume of gas sold and delivered. The increase in revenue taxes in 2014 from 2013 and 2013 from 2012 of $2.9 million and $7.2 million, respectively, was primarily related to the increase in therms delivered.

LIQUIDITY AND CAPITAL RESOURCES

Liquidity and capital resources for Washington Gas are substantially the same as the liquidity and capital resources discussion included in the Management’s Discussion of WGL (except for certain items and transactions that pertain to WGL Holdings and its unregulated subsidiaries). Those explanations are incorporated by reference into this discussion.

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WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

RATES AND REGULATORY MATTERS

Washington Gas determines its request to modify existing rates based on the level of net investment in plant and equipment, operating expenses and the need to earn a just and reasonable return on invested capital.

Summary of Major Rate Increase Applications and Results
Jurisdiction	Application  Filed		Effective Date		Test Year 12  Months Ended		Increase in Annual Revenues   (Millions)						Allowed Rate of      Return
							Requested			Granted			Overall		Equity
District of Columbia		02/29/12		06/04/13		09/30/11	$	29.0	14.00%	$	8.4	4.03%		7.93%		9.25%
Maryland		04/26/13		11/22/13		03/31/13	$	28.3	5.80%	$	8.9	1.80%		7.70%		9.50%
Virginia		01/31/11		10/01/11		09/30/10	$	28.5	5.75%	$	20.0	4.04%		8.26%		9.75%

The following is a discussion of significant current regulatory matters in each of Washington Gas’ jurisdictions.

District of Columbia Jurisdiction

Accelerated Pipe Replacement Plan.  On August 15, 2013, Washington Gas filed a request for approval with the PSC of DC of a Revised Accelerated Pipe Replacement Plan, including a surcharge mechanism to recover the associated costs for the first five years of the plan. Washington Gas proposes to replace bare and/or unprotected steel services, bare and targeted unprotected steel main, and cast iron main in its distribution system in the District of Columbia at an estimated five-year cost of $110 million. Comments and replies were filed by interested parties. On March 31, 2014, the PSC of DC issued an order conditionally approving the plan, contingent on Washington Gas submitting an implementation plan and other information directed in the Order, by April 30, 2014. Washington Gas filed responsive information, as directed and sought reconsideration/clarification on several issues in the Order. On May 30, 2014, the PSC of DC granted Washington Gas’ application for reconsideration/clarification. On August 21, 2014, the PSC of DC issued an Order approving the revised plan and establishing a procedural schedule for consideration of Washington Gas’ proposed surcharge mechanism. On November 5, 2014, Washington Gas, filed a motion on behalf of all parties to the proceedings, advising the Commission that the parties had reached a settlement in principle on the issues related to the cost recovery mechanism and requesting that the proceeding be stayed pending the filing of a settlement agreement for commission approval.

Weather Normalization Adjustment.  On November 8, 2013, Washington Gas filed an application for approval of a WNA, which is a rate design mechanism that eliminates the variability of weather from the calculation of actual billed revenues and offers customers more stability in their bills during colder-than-normal winter heating seasons. Comments and replies have been filed regarding Washington Gas’ application, which is pending before the PSC of DC.

Maryland Jurisdiction

Maryland Base Rate Case.  On November 22, 2013, the PSC of Maryland issued an order granting an overall increase of $8.9 million, based on the capital structure recommended by the Staff of the PSC. The order approved a return on equity of 9.50% resulting in an overall rate of return of 7.70%. The order also clarified that Washington Gas was authorized to establish a regulatory asset and amortize the costs related to the change in tax treatment of Med D. Finally, the PSC of MD denied Washington Gas’ appeal on recovery of the costs to initiate the outsourcing agreement with Accenture, LLP. As a result of this order, Washington Gas established a Med D regulatory asset in the first quarter of fiscal year 2014 and has begun amortizing the balance. On December 20, 2013, Washington Gas filed a request for rehearing and an appeal with the Baltimore City Circuit Court appealing the PSC of MD’s rulings on capital structure, return on equity, and recovery of the costs to initiate the outsourcing agreement. Oral argument occurred on September 23, 2014. On October 2, 2014, the Baltimore City Circuit Court issued a Memorandum Opinion and order affirming the PSC of MD decision.

Maryland Strategic Infrastructure Development and Enhancement Plan.  On November 7, 2013, pursuant to the STRIDE law in Maryland, Washington Gas filed an application with the PSC of MD for authority to implement a STRIDE Plan and to recover the reasonable and prudent costs associated with the infrastructure replacements through monthly surcharges. The surcharge may not exceed $2.00 per month for residential customers. Under the new law, “eligible infrastructure” means replacement or improvement of existing infrastructure of a gas company that (i) is made on or after June 1, 2013; (ii) is designed to improve public safety or infrastructure reliability; (iii) does not increase revenue of a gas company by connecting directly to new customers; (iv) reduces or has the potential to reduce greenhouse gas emissions through a reduction in leaks; and (v) is not included in the current rate base of the gas company. In the application, Washington Gas proposes to invest approximately $200 million in the initial five years of a 22-year overall plan. The STRIDE Plan will enable Washington Gas to expedite replacement of aging infrastructure in its distribution system in Maryland. The new law provides that the Commission must approve the cost-recovery schedule associated with the STRIDE Plan at the same time that it approves the Plan and has 180 days to issue a final decision on Washington Gas’ request.

67

WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (continued)

On May 6, 2014, the PSC of MD issued an order which conditionally approved Washington Gas’ proposed STRIDE Plan with a January 1, 2014 start date. The PSC of MD authorized Washington Gas to substitute eligible infrastructure replacement projects contingent on review and approval by the PSC of MD. On June 4, 2014, Washington Gas filed its proposed project list for calendar year 2014 and proposed surcharges to collect the associated revenue requirement over the six months July through December 2014. On July 9, 2014, the PSC of MD issued a letter order approving Washington Gas’ 2014 project list and revised surcharges permitting Washington Gas to collect the associated revenue requirement over the five months August through December 2014. On June 5, 2014, the Maryland Office of People’s Counsel filed an appeal of the PSC of MD’s May 6, 2014 order with the Circuit Court for Baltimore City. Washington Gas filed a notice on June 13, 2014 that it intends to participate in the appeal. On October 29, 2014, the parties to the appeal jointly requested that the proceedings be stayed pending the outcome of the appeal of a Baltimore Gas & Electric Company case that may be dispositive of the issues in the Washington Gas proceeding.

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WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 7. Management’s Discussion and Analysis of

Financial Condition and Results of Operations (concluded)

Virginia Jurisdiction

Affiliate Transactions.  On June 16, 2011, Washington Gas submitted an application to the SCC of VA requesting approval of three affiliate transactions with WGL Midstream: (i) the transfer to WGL Midstream of the remainder of the term of two agreements for natural gas storage service at the WSS and ESS storage fields; (ii) the sale to WGL Midstream of any storage gas balances associated with the WSS and ESS agreements; and (iii) the assignment to WGL Midstream of Washington Gas’ rights to buy base gas in the WSS storage field. The SCC of VA did not approve the transfer of the agreements on the grounds that ratepayers funded a portion of the costs associated with the assets. On June 5, 2013, Washington Gas filed a petition requesting the SCC of VA to issue a declaratory judgment that the proposed capacity releases are governed by the FERC, and that the SCC of VA does not have jurisdiction over the transaction.

On October 31, 2013, the Senior Hearing Examiner issued a report finding that the SCC of VA has jurisdiction over the proposed transfers. Washington Gas filed comments on the report on December 5, 2013. The SCC of VA issued an Order on May 14, 2014, remanding the case for hearing, which has been scheduled for November 18, 2014. Washington Gas filed Direct Testimony on August 15, 2014. Staff Testimony and Washington Gas Rebuttal Testimony was due on October 15, 2014 and November 5, 2014, respectively. The case is pending review by the SCC of VA.

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WGL Holdings, Inc.

Washington Gas Light Company

Part II

ITEM 7A.  QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

The following issues related to our market risks are included under Item 7 of this report and are incorporated by reference into this discussion.

• Price Risk Related to the Regulated Utility Segment

• Price Risk Related to the Non-Utility Segments

• Value-At-Risk

• Weather Risk

• Interest-Rate Risk

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

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WGL Holdings, Inc.

Consolidated Balance Sheets

Part II

Item 8. Financial Statements and Supplementary Data

	September 30,
(In thousands)	2014			2013
ASSETS
Property, Plant and Equipment
At original cost	$	4,582,764		$	4,118,149
Accumulated depreciation and amortization		(1,268,319)			(1,210,686)
Net property, plant and equipment		3,314,445			2,907,463
Current Assets
Cash and cash equivalents		8,811			3,478
Receivables
Accounts receivable		222,253			229,544
Gas costs and other regulatory assets		3,752			10,825
Unbilled revenues		96,314			98,598
Allowance for doubtful accounts		(23,341	)		(20,433)
Net receivables		298,978			318,534
Materials and supplies—principally at average cost		23,647			24,904
Storage gas		333,602			347,291
Deferred income taxes		26,664			24,522
Prepaid taxes		66,578			24,450
Other prepayments		34,269			29,922
Derivatives		18,331			35,315
Other		24,635			11,595
Total current assets		835,515			820,011
Deferred Charges and Other Assets
Regulatory assets
Gas costs		191,346			93,963
Pension and other post-retirement benefits		192,981			240,634
Other		71,638			66,010
Prepaid post-retirement benefits		96,385			-
Derivatives		18,739			26,306
Investments in direct financing leases, capital leases		18,159			23,390
Investments in unconsolidated affiliates		100,528			67,522
Other		16,763			14,761
Total deferred charges and other assets		706,539			532,586
Total Assets	$	4,856,499		$	4,260,060
CAPITALIZATION AND LIABILITIES
Capitalization
Common shareholders’ equity	$	1,246,576		$	1,274,545
Washington Gas Light Company preferred stock		28,173			28,173
Long-term debt		679,228			524,067
Total capitalization		1,953,977			1,826,785
Current Liabilities
Current maturities of long-term debt		20,000			67,000
Notes payable		453,500			373,100
Accounts payable and other accrued liabilities		313,221			270,658
Wages payable		19,995			18,645
Accrued interest		3,488			3,399
Dividends declared		22,449			22,075
Customer deposits and advance payments		68,318			67,154
Gas costs and other regulatory liabilities		22,563			27,013
Accrued taxes		14,133			16,056
Derivatives		48,555			48,413
Other		34,063			36,564
Total current liabilities		1,020,285			950,077
Deferred Credits
Unamortized investment tax credits		99,351			46,378
Deferred income taxes		660,908			629,807
Accrued pensions and benefits		120,446			148,890
Asset retirement obligations		175,203			101,321
Regulatory liabilities
Accrued asset removal costs		327,388			321,266
Other post-retirement benefits		86,428			-
Other		17,588			13,459
Derivatives		294,745			141,334
Other		100,180			80,743
Total deferred credits		1,882,237			1,483,198
Commitments and Contingencies (Note 13)
Total Capitalization and Liabilities	$	4,856,499		$	4,260,060

The accompanying notes are an integral part of these statements.

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WGL Holdings, Inc.

Consolidated Statements of Income

Part II

Item 8. Financial Statements and Supplementary Data (continued)

	Years Ended September 30,
(In thousands, except per share data)	2014		2013		2012
OPERATING REVENUES
Utility	$	1,416,951	$	1,174,724	$	1,109,355
Non-utility		1,363,996		1,291,414		1,315,955
Total Operating Revenues		2,780,947		2,466,138		2,425,310
OPERATING EXPENSES
Utility cost of gas		700,305		496,487		394,955
Non-utility cost of energy-related sales		1,255,279		1,187,844		1,190,093
Operation and maintenance		365,873		366,889		342,810
Depreciation and amortization		110,772		103,284		96,476
General taxes and other assessments		151,196		145,816		135,455
Total Operating Expenses		2,583,425		2,300,320		2,159,789
OPERATING INCOME		197,522		165,818		265,521
Equity in earnings of unconsolidated affiliates		3,194		1,510		1,240
Other income — net		1,536		2,548		4,154
Interest expense		37,738		36,011		36,428
INCOME BEFORE INCOME TAXES		164,514		133,865		234,487
INCOME TAX EXPENSE		57,254		52,292		93,349
NET INCOME	$	107,260	$	81,573	$	141,138
Dividends on Washington Gas Light Company preferred stock		1,320		1,320		1,320
NET INCOME APPLICABLE TO COMMON STOCK	$	105,940	$	80,253	$	139,818
AVERAGE COMMON SHARES OUTSTANDING
Basic		51,759		51,697		51,522
Diluted		51,770		51,808		51,589
EARNINGS PER AVERAGE COMMON SHARE
Basic	$	2.05	$	1.55	$	2.71
Diluted	$	2.05	$	1.55	$	2.71
DIVIDENDS DECLARED PER COMMON SHARE	$	1.7400	$	1.6600	$	1.5875

The accompanying notes are an integral part of these statements.

72

WGL Holdings, Inc.

Consolidated Statements of Comprehensive Income

Part II

Item 8. Financial Statements and Supplementary Data (continued)

	Years Ended September 30,
(In thousands)	2014			2013			2012
NET INCOME	$	107,260		$	81,573		$	141,138
OTHER COMPREHENSIVE INCOME (LOSS), BEFORE INCOME TAXES:
Qualified cash flow hedging instruments		(1,548	)		-			-
Pension and other post-retirement benefit plans
Change in prior service (cost) credit		6,095			(1,671	)		(640)
Change in actuarial net gain (loss)		1,594			3,399			(2,125)
Change in transition obligation		-			238			239
TOTAL OTHER COMPREHENSIVE INCOME (LOSS) BEFORE TAXES	$	6,141		$	1,966		$	(2,526)
INCOME TAX EXPENSE (BENEFIT) RELATED TO OTHER COMPREHENSIVE INCOME		3,054			813			(987)
OTHER COMPREHENSIVE INCOME (LOSS)	$	3,087		$	1,153		$	(1,539)
COMPREHENSIVE INCOME	$	110,347		$	82,726		$	139,599

The accompanying notes are an integral part of these statements.

73

WGL Holdings, Inc.

Consolidated Statements of Cash Flows

Part II

Item 8. Financial Statements and Supplementary Data (continued)

	Years Ended September 30,
(In thousands)	2014			2013			2012
OPERATING ACTIVITIES
Net income	$	107,260		$	81,573		$	141,138
ADJUSTMENTS TO RECONCILE NET INCOME TO NET CASH PROVIDED
BY OPERATING ACTIVITIES
Depreciation and amortization		110,772			103,284			96,476
Amortization of:
Other regulatory assets and liabilities—net		610			574			881
Debt related costs		886			873			894
Deferred income taxes—net		25,795			1,431			107,699
Accrued/deferred pension and other post-retirement benefit cost		33,384			36,127			(60,459	)
Compensation expense related to stock-based awards		4,105			3,050			4,122
Provision for doubtful accounts		14,252			9,258			18,316
Impairment loss		2,639			2,600			5,015
Other non-cash charges (credits)—net		(3,079	)		2,536			(5,151	)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable and unbilled revenues—net		(1,769	)		12,105			(65,329	)
Gas costs and other regulatory assets/liabilities—net		2,623			36,359			(13,650	)
Storage gas		13,689			(64,283	)		7,386
Prepaid Taxes		(42,128	)		33,506			(36,643	)
Accounts payable and other accrued liabilities		21,326			2,017			(16,683	)
Customer deposits and advance payments		1,164			(22,166	)		11,181
Accrued taxes		(1,923	)		(6,980	)		6,111
Unamortized investment tax credits		56,639			19,296			14,736
Other current assets		(16,130	)		(2,513	)		(5,768	)
Other current liabilities		(1,062	)		22,106			27,297
Deferred gas costs—net		(97,383	)		(113,474	)		36,309
Deferred assets—other		(7,525	)		(133	)		(51,889	)
Deferred liabilities—other		(3,130	)		45			(5,230	)
Derivatives		178,104			163,571			(1,858	)
Pension and other post-retirement benefits		(16,602	)		(4,417	)		10,613
Other—net		(350	)		1,679			(7,915	)
Net Cash Provided by Operating Activities		382,167			318,024			217,599
FINANCING ACTIVITIES
Common stock issued		714			-			631
Long-term debt issued		175,253			4,157			-
Long-term debt retired		(67,000	)		(2,295	)		(77,000	)
Debt issuance costs		(1,543	)		-			(123	)
Notes payable issued (retired)—net		80,400			125,400			208,279
Dividends on common stock and preferred stock		(85,901	)		(86,078	)		(77,182	)
Repurchase of common stock		(56,136	)		-			-
Other financing activities—net		(560	)		5,156			564
Net Cash Provided By Financing Activities		45,227			46,340			55,169
INVESTING ACTIVITIES
Capital expenditures (excluding AFUDC)		(394,762	)		(312,345	)		(251,128	)
Investments in non-utility interests		(31,415	)		(62,894	)		(24,636	)
Distributions from non-utility interests		4,116			4,090			8,927
Net Cash Used in Investing Activities		(422,061	)		(371,149	)		(266,837	)
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS		5,333			(6,785	)		5,931
Cash and Cash Equivalents at Beginning of Year		3,478			10,263			4,332
Cash and Cash Equivalents at End of Year	$	8,811		$	3,478		$	10,263
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Income taxes paid (refunded)—net	$	20,110		$	(10,741	)	$	23,915
Interest paid	$	36,991		$	35,471		$	36,777
SUPPLEMENTAL DISCLOSURES OF NON-CASH INVESTING AND FINANCING ACTIVITIES
Project debt financing activities—net	$	253		$	1,386		$	2,004
Capital expenditure accruals included in accounts payable and other accrued liabilities	$	55,164		$	32,040		$	34,980
Dividends paid in common stock	$	5,312		$	6,863		$	5,260

The accompanying notes are an integral part of these statements.

74

WGL Holdings, Inc.

Consolidated Statements of Capitalization

Part II

Item 8. Financial Statements and Supplementary Data (continued)

	September 30,
($ In thousands, except shares)	2014					2013
Common Shareholders’ Equity
Common stock, no par value, 120,000,000 shares authorized, 50,656,553 and 51,774,204 shares issued, respectively	$	525,932				$	574,461
Paid-in capital		11,847					10,710
Retained earnings		716,758					700,422
Accumulated other comprehensive loss, net of taxes		(7,961	)				(11,048	)
Total Common Shareholders’ Equity		1,246,576		63.8	%		1,274,545		69.8%
Preferred Stock
WGL Holdings, Inc., without par value, 3,000,000 shares authorized, none issued		-					-
Washington Gas Light Company, without par value, 1,500,000 shares authorized—issued and outstanding:
$4.80 series, 150,000 shares		15,000					15,000
$4.25 series, 70,600 shares		7,173					7,173
$5.00 series, 60,000 shares		6,000					6,000
Total Preferred Stock		28,173		1.4	%		28,173		1.5%
Long-Term Debt
Washington Gas Light Company Unsecured Medium-Term Notes
Due fiscal year 2014, 4.88% to 5.17%		-					67,000
Due fiscal year 2015, 4.83%		20,000					20,000
Due fiscal year 2016, 5.17%		25,000					25,000
Due fiscal year 2019, 7.46%		50,000					50,000
Due fiscal year 2020, 4.76%		50,000					50,000
Due fiscal year 2023, 6.65%		20,000					20,000
Due fiscal year 2025, 5.44%		40,500					40,500
Due fiscal year 2027, 6.40% to 6.82%		125,000					125,000
Due fiscal year 2028, 6.57% to 6.85%		52,000					52,000
Due fiscal year 2030, 7.50%		8,500					8,500
Due fiscal year 2036, 5.70% to 5.78%		50,000					50,000
Due fiscal year 2041, 5.21%		75,000					75,000
Due fiscal year 2044, 4.22% to 5.00%		175,000					-
Total Unsecured Medium-Term Notes		691,000					583,000
Other long-term debt		8,350					8,097
Unamortized discount		(122	)				(30	)
Less—current maturities		20,000					67,000
Total Long-Term Debt		679,228		34.8	%		524,067		28.7%
Total Capitalization	$	1,953,977		100.0	%	$	1,826,785		100.0%

The accompanying notes are an integral part of these statements.

75

WGL Holdings, Inc.

Consolidated Statements of Common Shareholders’ Equity

Part II

Item 8. Financial Statements and Supplementary Data (continued)

												Accumulated
												Other
												Comprehensive
	Common Stock						Paid-In		Retained			Loss,
(In thousands, except shares)	Shares			Amount			Capital		Earnings			Net of Taxes			Total
Balance, September 30, 2011		51,365,337		$	557,594		$	7,731	$	648,052		$	(10,662	)	$	1,202,715
Net income		-			-			-		141,138			-			141,138
Other comprehensive income		-			-			-		-			(1,539	)		(1,539)
Dividend reinvestment		152,435			6,317			-		-			-			6,317
Stock-based compensation		93,875			3,687			401		-			-			4,088
Dividends declared:
Common stock ($1.5875 per share)		-			-			-		(81,843	)		-			(81,843)
Preferred stock		-			-			-		(1,320	)		-			(1,320)
Balance, September 30, 2012		51,611,647			567,598			8,132		706,027			(12,201	)		1,269,556
Net income		-			-			-		81,573			-			81,573
Other comprehensive income		-			-			-		-			1,153			1,153
Dividend reinvestment		145,920			6,254			-		-			-			6,254
Stock-based compensation		16,637			609			2,578		-			-			3,187
Dividends declared:
Common stock ($1.6600 per share)		-			-			-		(85,858	)		-			(85,858)
Preferred stock		-			-			-		(1,320	)		-			(1,320)
Balance, September 30, 2013		51,774,204			574,461			10,710		700,422			(11,048	)		1,274,545
Net income		-			-			-		107,260			-			107,260
Other comprehensive income		-			-			-		-			3,087			3,087
Dividend reinvestment		114,883			4,649			-		-			-			4,649
Repurchase of common stock		(1,304,504	)		(56,136	)		-		-			-			(56,136)
Stock-based compensation		71,970			2,958			1,137		-			-			4,095
Dividends declared:
Common stock ($1.7400 per share)		-			-			-		(89,604	)		-			(89,604)
Preferred stock		-			-			-		(1,320	)		-			(1,320)
Balance, September 30, 2014		50,656,553		$	525,932		$	11,847	$	716,758		$	(7,961	)	$	1,246,576

The accompanying notes are an integral part of these statements.

76

Washington Gas Light Company

Balance Sheets

Part II

Item 8. Financial Statements and Supplementary Data (continued)

	September 30,
(In thousands)	2014			2013
ASSETS
Property, Plant and Equipment
At original cost	$	4,250,194		$	3,903,482
Accumulated depreciation and amortization		(1,228,130	)		(1,178,600)
Net property, plant and equipment		3,022,064			2,724,882
Current Assets
Cash and cash equivalents		1,060			-
Receivables
Accounts receivable		121,419			91,405
Gas costs and other regulatory assets		3,752			10,825
Unbilled revenues		20,881			19,418
Allowance for doubtful accounts		(19,209	)		(17,498)
Net receivables		126,843			104,150
Materials and supplies—principally at average cost		23,600			24,857
Storage gas		156,083			132,226
Deferred income taxes		22,916			27,000
Prepaid taxes		16,137			14,868
Other prepayments		14,272			7,926
Receivables from associated companies		4,821			7,173
Derivatives		3,884			4,278
Total current assets		369,616			322,478
Deferred Charges and Other Assets
Regulatory assets
Gas costs		191,346			93,963
Pension and other post-retirement benefits		191,896			239,434
Other		71,584			65,984
Prepaid post-retirement benefits		95,660			-
Derivatives		9,455			16,051
Other		13,457			11,597
Total deferred charges and other assets		573,398			427,029
Total Assets	$	3,965,078		$	3,474,389
CAPITALIZATION AND LIABILITIES
Capitalization
Common shareholder’s equity	$	1,050,166		$	1,024,583
Preferred stock		28,173			28,173
Long-term debt		679,228			524,067
Total capitalization		1,757,567			1,576,823
Current Liabilities
Current maturities of long-term debt		20,000			67,000
Notes payable		89,000			124,500
Accounts payable and other accrued liabilities		176,467			132,814
Wages payable		18,290			17,057
Accrued interest		3,488			3,399
Dividends declared		19,722			19,359
Customer deposits and advance payments		68,318			67,154
Gas costs and other regulatory liabilities		22,563			27,013
Accrued taxes		24,610			25,380
Payables to associated companies		54,685			20,557
Derivatives		33,858			24,749
Other		7,199			9,047
Total current liabilities		538,200			538,029
Deferred Credits
Unamortized investment tax credits		6,479			7,354
Deferred income taxes		619,946			611,453
Accrued pensions and benefits		118,954			147,479
Asset retirement obligations		173,775			99,972
Regulatory liabilities
Accrued asset removal costs		327,388			321,266
Other post-retirement benefits		85,814			-
Other		17,588			13,459
Derivatives		260,789			106,144
Other		58,578			52,410
Total deferred credits		1,669,311			1,359,537
Commitments and Contingencies (Note 13)
Total Capitalization and Liabilities	$	3,965,078		$	3,474,389

The accompanying notes are an integral part of these statements.

77

Washington Gas Light Company

Statements of Income

Part II

Item 8. Financial Statements and Supplementary Data (continued)

	Years Ended September 30,
(In thousands)	2014		2013		2012
OPERATING REVENUES	$	1,443,800	$	1,200,357	$	1,137,666
OPERATING EXPENSES
Utility cost of gas		726,879		521,508		421,539
Operation and maintenance		294,613		295,664		282,746
Depreciation and amortization		102,713		99,188		93,811
General taxes and other assessments		137,472		133,391		124,814
Total Operating Expenses		1,261,677		1,049,751		922,910
OPERATING INCOME		182,123		150,606		214,756
Other income —net		862		1,544		3,135
Interest expense		37,127		35,631		36,098
INCOME BEFORE INCOME TAXES		145,858		116,519		181,793
INCOME TAX EXPENSE		47,534		44,197		71,747
NET INCOME	$	98,324	$	72,322	$	110,046
Dividends on Washington Gas preferred stock		1,320		1,320		1,320
NET INCOME APPLICABLE TO COMMON STOCK	$	97,004	$	71,002	$	108,726

The accompanying notes are an integral part of these statements.

78

Washington Gas Light Company

Consolidated Statements of Comprehensive Income

Part II

Item 8. Financial Statements and Supplementary Data (continued)

	Years Ended September 30,
(In thousands)	2014		2013			2012
NET INCOME	$	98,324	$	72,322		$	110,046
OTHER COMPREHENSIVE INCOME (LOSS), BEFORE INCOME TAXES:
Pension and other post-retirement benefit plans
Change in prior service (cost) credit		6,095		(1,671	)		(640	)
Change in actuarial net gain (loss)		1,594		3,399			(2,125	)
Change in transition obligation		-		238			239
Total pension and other post-retirement benefit plans	$	7,689	$	1,966		$	(2,526	)
INCOME TAX EXPENSE (BENEFIT) RELATED TO OTHER COMPREHENSIVE INCOME		3,054		813			(987	)
OTHER COMPREHENSIVE INCOME (LOSS)	$	4,635	$	1,153		$	(1,539	)
COMPREHENSIVE INCOME	$	102,959	$	73,475		$	108,507

The accompanying notes are an integral part of these statements.

79

Washington Gas Light Company

Statements of Cash Flows

Part II

Item 8. Financial Statements and Supplementary Data (continued)

	Years Ended September 30,
(In thousands)	2014			2013			2012
OPERATING ACTIVITIES
Net income	$	98,324		$	72,322		$	110,046
ADJUSTMENTS TO RECONCILE NET INCOME TO NET CASH PROVIDED BY OPERATING ACTIVITIES
Depreciation and amortization		102,713			99,188			93,811
Amortization of:
Other regulatory assets and liabilities—net		610			911			881
Debt related costs		886			527			894
Deferred income taxes—net		7,050			(2,915	)		89,132
Accrued/deferred pension and other post-retirement benefit cost		33,670			35,707			(58,645	)
Compensation expense related to stock-based awards		3,185			2,292			3,394
Provision for doubtful accounts		11,839			7,183			12,794
Impairment loss		2,639			2,600			5,015
Other non-cash charges (credits)—net		8,838			7,615			(2,726	)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable, unbilled revenues and receivables from associated companies—net		(39,253	)		(464	)		(19,041	)
Gas costs and other regulatory assets/liabilities—net		2,623			36,359			(13,650	)
Storage gas		(23,857	)		(17,400	)		51,228
Prepaid Taxes		(1,269	)		31,937			(32,546	)
Accounts payable and other accrued liabilities, including payables to associated companies		49,429			(24,949	)		27,214
Customer deposits and advance payments		1,164			(22,166	)		11,181
Accrued taxes		(770	)		6,272			(3,721	)
Other current assets		(5,089	)		5,843			2,964
Other current liabilities		(526	)		19,253			3,676
Deferred gas costs—net		(97,383	)		(113,474	)		36,309
Deferred assets—other		(10,073	)		(757	)		(43,553	)
Deferred liabilities—other		(3,007	)		(966	)		(23,887	)
Derivatives		170,744			137,559			(3,608	)
Pension and other post-retirement benefits		(16,973	)		(4,261	)		10,786
Other—net		(359	)		(4,167	)		(1,673	)
Net Cash Provided by Operating Activities		295,155			274,049			256,275
FINANCING ACTIVITIES
Long-term debt issued		175,253			4,157			-
Long-term debt retired		(67,000	)		(2,295	)		(77,000	)
Debt issuance costs		(1,543	)		-			-
Notes payable issued (retired)—net		(35,500	)		25,700			98,778
Dividends on common stock and preferred stock		(79,665	)		(76,522	)		(75,239	)
Other financing activities—net		(1,749	)		336			2,533
Net Cash Used in Financing Activities		(10,204	)		(48,624	)		(50,928	)
INVESTING ACTIVITIES
Capital expenditures (excluding AFUDC)		(283,891	)		(225,426	)		(206,699	)
Net Cash Used in Investing Activities		(283,891	)		(225,426	)		(206,699	)
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS		1,060			(1	)		(1,352	)
Cash and Cash Equivalents at Beginning of Year		-			1			1,353
Cash and Cash Equivalents at End of Year	$	1,060		$	-		$	1
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Income taxes paid (refunded)—net	$	19,007		$	(15,799	)	$	29,625
Interest paid	$	36,380		$	35,091		$	36,447
SUPPLEMENTAL DISCLOSURES OF NON-CASH INVESTING AND FINANCING ACTIVITIES
Project debt financing activities—net	$	253		$	1,386		$	2,004
Capital expenditure accruals included in accounts payable and other accrued liabilities	$	46,331		$	16,429		$	22,909

The accompanying notes are an integral part of these statements.

80

Washington Gas Light Company

Statements of Capitalization

Part II

Item 8. Financial Statements and Supplementary Data (continued)

	September 30,
($ In thousands, except shares)	2014				2013
Common Shareholder’s Equity
Common stock, $1 par value, 80,000,000 shares authorized, 46,479,536 shares issued	$	46,479			$	46,480
Paid-in capital		480,620				477,968
Retained earnings		529,480				511,183
Accumulated other comprehensive loss, net of taxes		(6,413	)			(11,048	)
Total Common Shareholder’s Equity		1,050,166		59.8%		1,024,583		65.0%
Preferred Stock
Washington Gas Light Company, without par value, 1,500,000 shares authorized—issued and outstanding:
$4.80 series, 150,000 shares		15,000				15,000
$4.25 series, 70,600 shares		7,173				7,173
$5.00 series, 60,000 shares		6,000				6,000
Total Preferred Stock		28,173		1.6%		28,173		1.8%
Long-Term Debt
Washington Gas Light Company Unsecured Medium-Term Notes
Due fiscal year 2014, 4.88% to 5.17%		-				67,000
Due fiscal year 2015, 4.83%		20,000				20,000
Due fiscal year 2016, 5.17%		25,000				25,000
Due fiscal year 2019, 7.46%		50,000				50,000
Due fiscal year 2020, 4.76%		50,000				50,000
Due fiscal year 2023, 6.65%		20,000				20,000
Due fiscal year 2025, 5.44%		40,500				40,500
Due fiscal year 2027, 6.40% to 6.82%		125,000				125,000
Due fiscal year 2028, 6.57% to 6.85%		52,000				52,000
Due fiscal year 2030, 7.50%		8,500				8,500
Due fiscal year 2036, 5.70% to 5.78%		50,000				50,000
Due fiscal year 2041, 5.21%		75,000				75,000
Due fiscal year 2044, 4.22% to 5.00%		175,000				-
Total Unsecured Medium-Term Notes		691,000				583,000
Other long-term debt		8,350				8,097
Unamortized discount		(122	)			(30	)
Less—current maturities		20,000				67,000
Total Long-Term Debt		679,228		38.6%		524,067		33.2%
Total Capitalization	$	1,757,567		100.0%	$	1,576,823		100.0%

The accompanying notes are an integral part of these statements.

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Statements of Common Shareholder’s Equity

Part II

Item 8. Financial Statements and Supplementary Data (continued)

										Accumulated    Other    Comprehensive
	Common Stock				Paid-In		Retained			Loss,
(In thousands, except shares)	Shares		Amount		Capital		Earnings			Net of Taxes		Total
Balance, September 30, 2011		46,479,536	$	46,479	$	473,099	$	481,219		$	(10,662)	$	990,135
Net income		-		-		-		110,046			-		110,046
Other comprehensive income		-		-		-		-			(1,539)		(1,539)
Stock-based compensation(a)		-		-		2,535		-			-		2,535
Dividends declared:
Common stock		-		-		-		(74,114	)		-		(74,114)
Preferred stock		-		-		-		(1,320	)		-		(1,320)
Balance, September 30, 2012		46,479,536		46,479		475,634		515,831			(12,201)		1,025,743
Net income		-		-		-		72,322			-		72,322
Other comprehensive income		-		-		-		-			1,153		1,153
Stock-based compensation(a)		-		-		2,334		-			-		2,334
Dividends declared:
Common stock		-		-		-		(75,649	)		-		(75,649)
Preferred stock		-		-		-		(1,320	)		-		(1,320)
Balance, September 30, 2013		46,479,536		46,479		477,968		511,184			(11,048)		1,024,583
Net income		-		-		-		98,324			-		98,324
Other comprehensive income		-		-		-		-			4,635		4,635
Stock-based compensation(a)		-		-		2,652		-			-		2,652
Dividends declared:
Common stock		-		-		-		(78,708	)		-		(78,708)
Preferred stock		-		-		-		(1,320	)		-		(1,320)
Balance, September 30, 2014		46,479,536	$	46,479	$	480,620	$	529,480		$	(6,413)	$	1,050,166

^(a) Stock-based compensation is based on the stock awards of WGL Holdings that are allocated to Washington Gas Light Company for its pro-rata share.

The accompanying notes are an integral part of these statements.

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

NOTE 1. ACCOUNTING POLICIES

GENERAL

WGL Holdings, Inc. (WGL) is a holding company that owns all of the shares of common stock of Washington Gas Light Company (Washington Gas), a regulated natural gas utility, and all of the shares of common stock of Washington Gas Resources Corporation (Washington Gas Resources), Hampshire Gas Company (Hampshire) and Crab Run Gas Company. Washington Gas Resources owns all of the shares of common stock of four non-utility subsidiaries that include Washington Gas Energy Services, Inc. (WGEServices), Washington Gas Energy Systems, Inc. (WGESystems), WGL Midstream and WGSW, Inc. (WGSW). Except where the content clearly indicates otherwise, “WGL,” “we,” “us” or “our” refers to the holding company or the consolidated entity of WGL Holdings, Inc. and all of its subsidiaries. Unless otherwise noted, these notes apply equally to WGL and Washington Gas.

NATURE OF OPERATIONS

Washington Gas and Hampshire comprise our regulated utility segment. Washington Gas is a public utility that sells and delivers natural gas to more than one million customers primarily in the District of Columbia, and the surrounding metropolitan areas in Maryland and Virginia. Deliveries to firm residential and commercial customers accounted for 78.1% of the total therms delivered to customers by Washington Gas in fiscal year September 30, 2014. Deliveries to interruptible customers accounted for 14.3% and deliveries to customers who use natural gas to generate electricity accounted for 7.6%. These amounts do not include deliveries related to Washington Gas’ asset optimization program discussed below. Hampshire operates an underground natural gas storage facility that provides services exclusively to Washington Gas. Hampshire is regulated under a cost of service tariff by the Federal Energy Regulatory Commission (FERC).

The retail energy-marketing segment consists of WGEServices which competes with regulated utilities and other unregulated third party marketers to sell natural gas and electricity directly to residential, commercial, industrial and governmental customers with the objective of earning a profit through competitive pricing. The commodities that WGEServices sells are delivered to retail customers through assets owned by regulated utilities. Washington Gas delivers the majority of natural gas sold by WGEServices, and unaffiliated electric utilities deliver all of the electricity sold. WGEServices owned multiple solar PV distributed generation assets at September 30, 2014, though the results from these activities are presented in the commercial energy systems segment. Other than these facilities, WGEServices does not own or operate any other natural gas or electric generation, production, transmission or distribution assets. At September 30, 2014, WGEServices served approximately 157,000 natural gas customers and approximately 162,000 electricity customers located in Maryland, Virginia, Delaware, Pennsylvania and the District of Columbia.

The commercial energy systems segment consists of WGESystems, WGSW and the results of operations of affiliate owned commercial distributed energy projects. This segment focuses on clean and energy efficient solutions for its customers, driving earnings through i) upgrading the mechanical, electrical, water and energy-related infrastructure of large governmental and commercial facilities by implementing both traditional as well as alternative energy technologies; ii) owning and operating distributed generation assets such as solar PV systems, combined heat and power plants, and natural gas fuel cells and iii) passive investments in residential and commercial retail solar PV companies. This segment has activities in 15 different states and the District of Columbia, but is concentrated in the mid-Atlantic and northeast regions.

The midstream energy services segment, which consists of the operations of WGL Midstream, engages in investing in and optimizing natural gas pipelines and storage facilities in the Midwest and Eastern United States. WGL Midstream enters into both physical and financial transactions in a manner intended to utilize the most effective energy risk management products available to mitigate risks while maximizing potential profits from the optimization of these assets under its management.

Refer to Note 16—Operating Segment Reporting for further discussion of our segments.

CONSOLIDATION OF FINANCIAL STATEMENTS

The consolidated financial statements include the accounts of WGL and its subsidiaries during the fiscal years reported. Certain prior period amounts have been recast to conform to current period presentation. Inter-company transactions have been eliminated. Refer to Note 18—Related Party Transactions for a discussion of inter-company transactions. WGL has a variable interest in five investments that qualify as variable interest entities (VIEs). At September 30, 2014, WGL and its subsidiaries are not the primary beneficiary for any of the VIEs, therefore we have not consolidated any of the VIE entities. Our other investment projects are recorded using the cost method and as direct financing leases. Refer to Note 17—Other Investments for a discussion of VIEs and other investments.

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

USE OF ESTIMATES IN THE PREPARATION OF FINANCIAL STATEMENTS

In accordance with generally accepted accounting principles in the United States of America (GAAP), we make certain estimates and assumptions regarding: (i) reported assets and liabilities; (ii) disclosed contingent assets and liabilities at the date of the financial statements and (iii) reported revenues, revenues subject to refund, and expenses during the reporting period. Actual results could differ from those estimates.

PROPERTY, PLANT AND EQUIPMENT

Property, plant and equipment (comprised principally of utility plant) are stated at original cost, including labor, materials, taxes and overhead costs incurred during the construction period. The cost of utility plant of Washington Gas includes an allowance for funds used during construction (AFUDC) that is calculated under a formula prescribed by our regulators. Washington Gas capitalizes AFUDC as a component of construction overhead. The before-tax rates for AFUDC for fiscal years September 30, 2014, 2013 and 2012 were 3.36%, 5.43% and 7.40%, respectively.

Washington Gas charges maintenance and repairs directly to operating expenses, except those charges applicable to transportation and power-operated equipment, which it allocates to operating expenses, construction and other accounts based on the use of the equipment. Washington Gas capitalizes betterments and renewal costs, and calculates depreciation applicable to its utility gas plant in service primarily using a straight-line method over the estimated remaining life of the plant. The composite depreciation and amortization rate of the regulated utility segment was 2.77%, 2.86% and 2.87% during fiscal years 2014, 2013 and 2012, respectively. In accordance with regulatory requirements, such rates include a component related to asset removal costs for Washington Gas. These asset removal costs are accrued through depreciation expense with a corresponding credit to “Regulatory liabilities—Accrued asset removal costs.” When Washington Gas retires depreciable utility plant and equipment, it charges the associated original costs to “Accumulated depreciation and amortization” and any related removal costs incurred are charged to “Regulatory liabilities—Accrued asset removal costs.” Washington Gas periodically reviews the adequacy of its depreciation rates by considering estimated remaining lives and other factors. For information about Asset Retirement Obligations (ARO’s), refer to the section entitled “Asset Retirement Obligations”.

At September 30, 2014 and 2013, 93.6% and 95.6%, respectively, of WGL’s consolidated original cost of property, plant and equipment was related to the regulated utility segment as shown below.

Property, Plant and Equipment at Original Cost
September 30,	2014				2013
($ In millions)	Dollars		%		Dollars		%
Regulated utility segment
Distribution, transmission and storage	$	3,635.3		79.3	$	3,356.1		81.5
General, miscellaneous and intangibles		448.3		9.8		430.6		10.4
Construction work in progress (CWIP)		203.9		4.5		150.8		3.7
Total regulated utility segment		4,287.5		93.6		3,937.5		95.6
Unregulated segments		295.3		6.4		180.6		4.4
Total	$	4,582.8		100.0	$	4,118.1		100.0

IMPAIRMENT OF LONG-LIVED ASSETS

Management regularly reviews property and equipment and other long-lived assets, including certain definite-lived intangible assets and our equity method investments for possible impairment. This review occurs quarterly, or more frequently if events or changes in circumstances indicate the carrying amount of the asset may not be recoverable.

During September 30, 2014, 2013 and 2012, Washington Gas recorded impairment charges of $0.8 million, $2.6 million and $5.0 million, respectively, in operation and maintenance expense related to its Springfield Operations Center asset. Washington Gas is actively marketing the unused operations facility for sale. At September 30, 2014 and 2013, Washington Gas recorded a $1.9 million and $0.5 million impairment loss for the unrecoverable portion of the costs incurred associated with an abandoned LNG storage project.

For our equity and cost method investments, an impairment is recorded when the investment has experienced decline in value that is other-than-temporary. Additionally, if the projects in which we hold an investment recognize an impairment loss, we would record our proportionate share of that impairment loss and evaluate the investment for decline in value that is other-than-temporary. There were no events or circumstances during the years ended September 30, 2014, 2013 and 2012 that resulted in any impairment charges.

OPERATING LEASES

We have classified the lease of our corporate headquarters as an operating lease. We amortize as rent expense the total of all scheduled lease payments (including lease payment escalations) and tenant allowances on a straight-line basis over the term of the lease. For this purpose, the lease term began on the date when the lessor commenced constructing the leasehold improvements which allowed us to occupy our corporate headquarters. Leasehold improvement costs are classified as “Property, Plant and Equipment” on the Balance Sheets, and are being amortized to depreciation and amortization expense on a straight-line basis over the 15-year non-cancelable period of the lease. Refer to Note 13—Commitments and Contingencies for financial data for all of our operating leases.

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

CASH AND CASH EQUIVALENTS

We consider all investments with original maturities of three months or less to be cash equivalents. We did not have any restrictions on our cash balances that would impact the payment of dividends by WGL or our subsidiaries as of September 30, 2014 and 2013.

REVENUE AND COST RECOGNITION

Regulated Utility Operations

Revenues.  For regulated deliveries of natural gas, Washington Gas reads meters and bills customers on a 21 day monthly cycle basis. The billing cycles for customers do not coincide with the accounting periods used for financial reporting purposes; therefore, Washington Gas accrues unbilled revenues for gas delivered, but not yet billed, at the end of each accounting period.

Cost of Gas.  Washington Gas’ jurisdictional tariffs contain mechanisms that provide for the recovery of the cost of gas incurred on behalf of firm customers, including related pipeline transportation and storage capacity charges. Under these mechanisms, Washington Gas periodically adjusts its firm customers’ rates to reflect increases and decreases in these costs. Under or over-collections of gas costs in the current cycle are charged or credited to deferred charges or credits on the balance sheet as non-current regulatory assets or liabilities. Amounts deferred at the end of the cycle, August 31 of each year, are fully reconciled and transferred to current assets or liabilities under the balance sheet captions “Gas costs and other regulatory assets” and “Gas costs and other regulatory liabilities.” These balances are recovered or refunded to customers over the subsequent 12 month period.

Revenue Taxes.  Revenue taxes such as gross receipts taxes, Public Service Commission (PSC) fees, franchise fees and energy taxes are reported gross in operating revenues. Refer to Note 16—Operating Segment Reporting for amounts recorded related to revenue taxes.

Transportation Gas Imbalance.  Interruptible shippers and third party marketer shippers transport gas to Washington Gas’ distribution system as part of the unbundled services offered. The delivered volumes of gas from third party shippers into Washington Gas’ distribution system rarely equal the volumes billed to third party marketer customers, resulting in transportation gas imbalances. These imbalances are usually short-term in duration, and Washington Gas monitors the activity and regularly notifies the shippers when their accounts have an imbalance. In accordance with regulatory treatment, Washington Gas does not record a receivable from or liability to third party marketers associated with gas volumes related to these transportation imbalances but, rather, reflects the financial impact as a regulatory asset or liability related to its gas cost adjustment mechanism, thereby eliminating any profit or loss that would occur as a result of the imbalance. The regulatory treatment combines the imbalance for all marketers, including WGEServices, into a single “net” adjustment to the regulatory asset or liability. Refer to Note 18—Related Party Transactions for further discussion of the accounting for these imbalance transactions.

Asset Optimization Program.  Washington Gas optimizes the value of its long-term natural gas transportation and storage capacity resources by entering into physical and financial transactions in the form of forwards, futures and option contracts for periods when these resources are not being used to physically serve utility customers. Refer to “Derivative Activities” below for further discussion of the accounting for derivative transactions entered into under this program. Regulatory sharing mechanisms in all three jurisdictions allow the profit from these transactions to be shared between Washington Gas’ customers and shareholders.

All unrealized fair value gains and losses, and margins generated from the physical and financial settlement of these asset optimization contracts are recorded in utility cost of gas or, in the case of amounts to be shared with rate payers, regulatory liabilities.

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

Non-Utility Operations

Retail Energy-Marketing Segment.  WGEServices sells natural gas and electricity on an unregulated basis to residential, commercial and industrial customers both inside and outside the Washington Gas service territory.

WGEServices enters into indexed or fixed-rate contracts with residential, commercial and industrial customers for sales of natural gas and electricity. Customer contracts, which typically have terms less than 24 months, but may extend up to five years, allow WGEServices to bill customers based upon metered gas and electricity usage. Usage is measured either on a cycle basis at customer premises or based on quantities delivered to the local utility, both of which may vary by month. The billing cycles for customers do not coincide with the accounting periods used for financial reporting purposes; therefore, WGEServices accrues unbilled revenues for gas and electricity delivered, but not yet billed, at the end of each accounting period. Revenues are reflected in “Operating Revenues—Non utility.”

WGEServices procures natural gas and electricity supply under contract structures in which it assembles the various components of supply from multiple suppliers to match its customer requirements. The cost of natural gas and electricity for these purchases is recorded using the contracted volumes and prices in “Non-Utility cost of energy-related sales.”

Commercial Energy Systems Segment.  WGESystems recognizes income and expenses for all design-build construction contracts using the percentage-of-completion method in “Operating Revenues—Non-utility” and “Non-Utility cost of energy-related sales.” WGESystems also recognizes income from its distributed energy assets based on the terms of the related power purchase agreements. Solar Renewable Energy Certificates (SRECs) are recorded as inventory by WGESystems after every 1,000 Kilowatt-hours (kwh) of electricity are produced by an eligible solar facility. WGESystems recognizes income on the sale of SRECs based on the contractual terms and conditions of the sale. WGSW recognizes income on its investments in distributed energy assets based on the specific terms of its sale leaseback arrangements and through the hypothetical liquidation at book value approach to the equity method of investment accounting for its investment interest. Other income and expense is recognized from the lease of distributed energy assets associated with the SunEdison and Nextility associations.

Midstream Energy Services Segment.  WGL Midstream reports its margins in non-utility revenue by netting its cost / loss on physical and financial gas purchase contracts with revenues / gains on physical and financial gas sales contracts.

Other Activities.  Washington Gas Resources recognizes income on its investment using the cost approach of investment accounting. Crab Run recognizes income using the equity method of accounting.

STORAGE GAS VALUATION METHODS

For Washington Gas and WGEServices, storage gas inventory is stated at the lower-of-cost or market as determined using the first-in, first-out method. For WGL Midstream, storage gas inventory is stated at the lower-of-cost or market using the weighted average cost method.

For the fiscal year ended September 30, 2014, Washington Gas recorded a decrease to net income due to a lower-of-cost or market adjustment of $0.2 million. For the fiscal year ended September 30, 2013, Washington Gas did not record any lower-of-cost or market adjustments. For the fiscal year ended September 30, 2012, Washington Gas recorded a decrease to net income due to a lower-of-cost or market adjustment of $1.4 million. For the fiscal years ended September 30, 2014, 2013 and 2012, WGEServices did not record any lower-of-cost or market adjustments. For the fiscal years ended September 30, 2014, 2013 and 2012, WGL Midstream recorded a decrease to net income due to lower-of-cost or market adjustments of $3.0 million, $10.1 million and $22.4 million, respectively.

RATE REFUNDS DUE TO CUSTOMERS

When Washington Gas files a request with certain regulatory commissions to modify customers’ rates, it is permitted to charge customers new rates, subject to refund, until the regulatory commission renders a final decision on the amount of the authorized change in rates. During this interim period, Washington Gas records a provision for a rate refund regulatory liability based on the difference between the amount it collects in rates and the amount it expects to recover from a final regulatory decision. Similarly, Washington Gas periodically records provisions for rate refunds related to other transactions. Actual results for these regulatory contingencies are often difficult to predict and could differ significantly from the estimates reflected in the financial statements. Refer to Note 13—Commitments and Contingencies for further discussion of regulatory matters and related contingencies.

WEATHER-RELATED INSTRUMENTS

Periodically, we purchase certain weather-related instruments, such as HDD derivatives and CDD derivatives. We account for these weather related instruments in accordance with Financial Accounting Standards Board Accounting Standards Codification (ASC) Subtopic 815-45, Derivatives and Hedging—Weather Derivatives. For weather insurance policies and HDD derivatives, benefits or costs are ultimately recognized to the extent actual HDDs fall above or below the contractual HDDs for each instrument. Benefits or costs are recognized for CDD derivatives when the average temperature exceeds a contractually stated level during the contract period. Premiums for weather-related instruments are amortized based on the pattern of normal temperature days over the coverage period. Weather-related instruments for which we collect a premium are carried at fair value. Washington Gas’ weather related instrument premium expense or benefit is not considered in establishing retail rates. Washington Gas does not purchase such instruments for jurisdictions in which it has received rate mechanisms that compensate it on a normal weather basis. Refer to Note 14—Derivative and Weather-Related Instruments for further discussion of our weather-related instruments.

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

DERIVATIVE ACTIVITIES

Regulated Utility.  Washington Gas enters into both physical and financial derivative contracts for the purchase and sale of natural gas that are subject to mark-to-market accounting. Changes in the fair value of derivative instruments recoverable or refundable to customers and therefore subject to ASC Topic 980, Regulated Operations, are recorded as regulatory assets or liabilities while changes in the fair value of derivative instruments not affected by rate regulation are reflected in earnings.

As part of its asset optimization program, Washington Gas enters into derivative contracts related to the sale and purchase of natural gas at a future price with the primary objective of locking in operating margins that Washington Gas expects to ultimately realize. The derivatives used under this program may cause significant period-to-period volatility in earnings for the portion of net profits retained for shareholders; however, this volatility will not change the margins that Washington Gas expects to realize from these transactions. In accordance with ASC Topic 815, all financially and physically settled contracts under our asset optimization program are reported on a net basis in the statements of income in “Utility cost of gas”.

From time to time, Washington Gas also utilizes derivative instruments that are designed to minimize the risk of interest-rate volatility associated with planned issuances of Medium-Term Notes (MTNs). Gains or losses associated with these derivative transactions are deferred as regulatory assets or liabilities and amortized to interest expense in accordance with regulatory accounting requirements. Refer to Note 14—Derivative and Weather-Related Instruments for further discussion of our derivative activities.

Non-Utility Operations.  WGEServices enters into both physical and financial contracts for the purchase and sale of natural gas and electricity. We designate a portion of these physical contracts related to the purchase of natural gas and electricity to serve our customers as “normal purchases and normal sales;” therefore, they are not subject to the mark-to-market accounting requirements of ASC Topic 815. WGL Midstream enters into derivative contracts for the purpose of optimizing its storage and transportation capacity as well as managing the transportation and storage assets on behalf of third parties. The financial contracts and the portion of the physical contracts that qualify as derivative instruments and are subject to the mark-to-market accounting requirements are recorded on the balance sheet at fair value and are reflected in earnings. WGEServices records these derivatives as revenues or expenses depending on the nature of the economically hedged item. WGL Midstream nets financial and physical contracts in revenues. WGL may, from time to time, designate interest rate swaps used to manage the interest rate risk associated with future debt issuances, as cash flow hedges. Any gains or losses arising from the effective portion of cash flow hedges are recorded in other comprehensive income and are amortized using the effective interest rate method into earnings over the same period as the hedged interest payments are made. Gains or losses arising from the ineffective portion of cash flow hedges are recognized in earnings immediately.

INCOME TAXES

We recognize deferred income tax assets and liabilities for all temporary differences between the financial statement basis and the tax basis of assets and liabilities, including those where regulators prohibit deferred income tax treatment for ratemaking purposes of Washington Gas. Regulatory assets or liabilities, corresponding to such additional deferred income tax assets or liabilities, may be recorded to the extent recoverable from or payable to customers through the ratemaking process. Refer to Note 2—Regulated Operations for Washington Gas’ regulatory assets and liabilities associated with income taxes due from and to customers at September 30, 2014 and 2013. Amounts applicable to income taxes due from and due to customers primarily represent differences between the book and tax basis of net utility plant in service. We amortize investment tax credits as reductions to income tax expense over the estimated service lives of the related properties. Refer to Note 9—Income Taxes which provides detailed financial information related to our income taxes.

STOCK-BASED COMPENSATION

We account for stock-based compensation expense in accordance with ASC Topic 718, Compensation—Stock Compensation, which requires us to measure and recognize stock-based compensation expense in our financial statements based on the fair value at the date of grant for our equity-classified share-based awards, which include performance shares and stock options granted to certain employees and shares issued to directors. For liability-classified share-based awards, which include performance units, we recognize stock-based compensation expense based on their fair value at the end of each reporting period. For both equity-classified and liability-classified share-based awards, we estimate forfeitures over the requisite service period when recognizing compensation expense; these estimates are periodically adjusted to the extent to which actual forfeitures differ from such estimates. Refer to Note 11—Stock-Based Compensation for further discussion of the accounting for our stock-based compensation plans.

ASSET RETIREMENT OBLIGATIONS

Washington Gas accounts for its AROs in accordance with ASC Subtopic 410-20, Asset Retirement and Environmental Obligations—Asset Retirement Obligations. Our asset retirement obligations include the costs to cut, purge and cap distribution system, remove asbestos and plug storage wells upon their retirement. These standards require recording the estimated retirement cost over the life of the related asset by depreciating the present value of the

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

retirement obligation, measured at the time of the asset’s acquisition, and accreting the liability until it is settled. There are timing differences between the ARO-related accretion and depreciation amounts being recorded pursuant to GAAP and the recognition of depreciation expense for legal asset removal costs that we are currently recovering in rates. These timing differences are recorded as a reduction to “Regulatory liabilities—Accrued asset removal costs” in accordance with ASC Topic 980. We do not have any assets that are legally restricted related to the settlement of asset retirement obligations.

WGL Holdings, Inc.
Changes in Asset Retirement Obligations
	September 30,
(In millions)	2014		2013
Asset retirement obligations at beginning of year	$	104.0	$	72.7
Liabilities incurred in the period		4.9		1.2
Liabilities settled in the period		(5.2)		(1.0)
Accretion expense		4.4		3.3
Revisions in estimated cash flows(a)		73.1		27.8
Asset retirement obligations at the end of the year(b)	$	181.2	$	104.0
Washington Gas Light Company
Changes in Asset Retirement Obligations
	September 30,
(In millions)	2014		2013
Asset retirement obligations at beginning of year	$	102.7	$	71.5
Liabilities incurred in the period		4.9		1.1
Liabilities settled in the period		(5.2)		(1.0)
Accretion expense		4.3		3.3
Revisions in estimated cash flows(a)		73.1		27.8
Asset retirement obligations at the end of the year(b)	$	179.8	$	102.7

^(a) WGL revised its assumptions regarding the timing and amounts related to its obligation to cut, cap and purge pipeline. The revision is primarily driven by our accelerated pipeline replacement programs.

^(b) Includes short-term asset retirement obligations of $6.0 million and $2.7 million for fiscal year 2014 and 2013, respectively.

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

ACCOUNTING STANDARDS ADOPTED IN FISCAL YEAR 2014
Standard	Description	Date of adoption	Effect on the financial statements or other significant matters
ASU 2011-11, Disclosures about Offsetting Assets and Liabilities (Topic 210)	The standard amends the existing disclosure requirements on offsetting by requiring enhanced disclosures about financial instruments and derivative instruments that are either: (i) offset in accordance with existing guidance or (ii) subject to an enforceable master netting arrangement or similar agreement, irrespective of whether they are offset on the balance sheet.	October 1,   2013	As a result of the standards, additional disclosures regarding master netting arrangements were added to Note 14 - Derivative and Weather-Related Instruments. The adoption of these standards did not otherwise affect our financial statements.
ASU 2013-01, Clarifying the Scope of the Disclosures about Offsetting Assets and Liabilities (Topic 210)	The standard limits the scope of the required disclosures to derivatives, repurchase agreements and securities borrowing and securities lending transactions. The disclosures are required irrespective of whether the transactions are offset in the statement of financial position.
ASU 2013-02, Comprehensive Income (Topic 220): Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income	The standard requires entities to (i) present information about reclassification adjustments from accumulated other comprehensive income (AOCI) to net income in their entirety – the effect on the reclassification on each affected net income line item and (ii) for AOCI reclassification items that are not reclassified in their entirety into net income – a cross-reference to other required US GAAP disclosures. The reclassification information may be presented in a single note or on the face of the financial statements.	October 1,   2013	We have presented information about reclassification adjustments out of accumulated other comprehensive income in a footnote to the financial statements. Refer to Note 19 – Changes in Accumulated Other Comprehensive Income for the details of this disclosure. The adoption of this standard did not otherwise affect our financial statements.

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

OTHER NEWLY ISSUED ACCOUNTING STANDARDS
Standard	Description	Date of adoption	Effect on the financial statements or other significant matters
ASU 2013-11, Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists (Topic 740)	The standard amends the existing disclosure requirement by requiring an unrecognized tax benefit, or a portion of an unrecognized tax benefit to be presented in the financial statements as a reduction to a deferred tax asset in most circumstances.	October 1,   2014	We do not expect the adoption of this standard to have a material effect on our financial statements.
ASU 2014-09, Revenue from Contracts with Customers (Topic 606)	The standard establishes a comprehensive revenue recognition model clarifying the method used to determine the timing and requirements for revenue recognition from contracts with customers. The disclosure requirements under the new standard will enable users of financial statements to understand the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers.	October 1,   2017	We are in the process of evaluating the impact the adoption of this standard will have on our financial statements.
ASU 2014-10, Development Stage Entities (Topic 915)	The standard amends the existing disclosure requirement by eliminating certain disclosure requirements relating to those entities. The update also removes certain guidance on evaluating whether a development stage entity has sufficient equity at risk as a criteria used in determining whether an entity is a variable interest entity.	October 1,   2016	We do not expect the adoption of this standard to have a material effect on our financial statements.
ASU 2014-15, Presentation of Financial Statements - Going Concern (Topic 205)	The standard amends the existing disclosure requirement providing guidance about management’s responsibility to evaluate whether there is substantial doubt about the entity’s ability to continue as a going concern and to provide related footnote disclosures. The new guidance requires that management perform a going concern analysis as of the date that the financial statements are issued and for the analysis to cover the year following the issuance date.	October 1,   2017	We do not expect adoption of this standard to have a material effect on our financial statements.

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

NOTE 2. REGULATED OPERATIONS

Washington Gas accounts for its regulated operations in accordance with ASC Topic 980. This standard includes accounting principles for companies whose rates are determined by independent third party regulators. When setting rates, regulators may require us to record expense in different periods than may be appropriate for unregulated enterprises. When this occurs, Washington Gas defers the associated costs as assets (regulatory assets) on its balance sheet and records them as expenses on its income statement as it collects the revenues designed to recover these costs through customers’ rates. Further, regulators can also impose liabilities upon a company for amounts previously collected from customers and for future outflows that are expected to be incurred in the future (regulatory liabilities).

At September 30, 2014 and 2013, we recorded the following regulatory assets and liabilities on our balance sheets. These assets and liabilities will be recognized as expenses or revenues in future periods as they are reflected in customers’ rates.

Regulatory Assets and Liabilities
(In millions)	Regulatory Assets				Regulatory Liabilities
September 30,	2014		2013		2014		2013
Current:
Gas costs due from/to customers(a)	$	-	$	-	$	16.2	$	23.4
Interruptible sharing(a)		3.4		10.7		-		1.9
Revenue normalization mechanisms for Maryland and Virginia(a)		-		0.1		5.5		1.5
Plant recovery mechanisms		0.4		-		0.9		0.2
Total current	$	3.8	$	10.8	$	22.6	$	27.0
Deferred:
Accrued asset removal costs	$	-	$	-	$	327.4	$	321.3
Deferred gas costs(a)		191.3		94.0		-		-
Pension and other post-retirement benefits
Other post-retirement benefit costs—trackers(b)		-		0.7		-		-
Deferred pension costs/income—trackers(b)		45.1		51.0		-		-
ASC Topic 715 unrecognized costs/income(a)(c)
Pensions		147.9		155.1		-		-
Other post-retirement benefits		-		33.8		86.4		-
Total pension and other post-retirement benefits		193.0		240.6		86.4		-
Other
Income tax-related amounts due from/to customers(d)		30.4		24.9		4.8		4.5
Losses/gains on issuance and extinguishments of debt and interest-rate derivative instruments(a)(e)		12.0		11.6		1.7		0.6
Deferred gain on sale of assets(a)		-		-		1.4		1.7
Rights-of-way fees(a)		1.5		-		-		1.6
Other costs—Business process outsourcing (a)		1.0		1.4		-		-
Nonretirement postemployment benefits(a)(f)		16.3		15.4		-		-
Deferred integrity management expenditures(a)(g)		2.7		-		-		-
Recoverable portion of abandoned LNG facility(a)		5.6		7.9		-		-
Other regulatory expenses(a)		2.1		4.8		9.7		5.1
Total other	$	71.6	$	66.0	$	17.6	$	13.5
Total deferred	$	455.9	$	400.6	$	431.4	$	334.8
Total	$	459.7	$	411.4	$	454.0	$	361.8

^(a) Washington Gas does not earn its overall rate of return on these assets. Washington Gas is allowed to recover and required to pay, using short-term interest rates, the carrying costs related to billed gas costs due from and to its customers in the District of Columbia and Virginia jurisdictions.

^(b) Relates to the District of Columbia jurisdiction.

^(c) Refer to Note 10-Pension and Other Post-Retirement Benefit Plans for a further discussion of these amounts.

^(d) This balance represents amounts due from customers for deferred tax liabilities related to tax benefits on deduction flowed directly to customers prior to the adoption of income tax normalization for ratemaking purposes.

^(e) The losses or gains on the issuance and extinguishment of debt and interest-rate derivative instruments include unamortized balances from transactions executed in prior fiscal years. These transactions create gains and losses that are amortized over the remaining life of the debt as prescribed by regulatory accounting requirements.

^(f) Represents the timing difference between the recognition of workers compensation and short-term disability costs in accordance with generally accepted accounting principles and the way these costs are recovered through rates.

^(g) This balance represents amounts for deferred expenditures associated with Washington Gas’ Distribution Integrity Management Program (DIMP) in Virginia.

As required by ASC Topic 980, Washington Gas monitors its regulatory and competitive environment to determine whether the recovery of its regulatory assets remains probable. If Washington Gas were to determine that recovery of these assets is no longer probable, it would write off the assets against earnings. We have determined that ASC Topic 980 continues to apply to our regulated operations, and the recovery of our regulatory assets at September 30, 2014 is probable. Refer to Note 13—Commitments and Contingencies for further discussion of our regulated operations.

NOTE 3. ACCOUNTS PAYABLE AND OTHER ACCRUED LIABILITIES

The tables below provide details for the amounts included in “Accounts payable and other accrued liabilities” on the balance sheets for both WGL and Washington Gas.

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Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

WGL Holdings, Inc.
	September 30,
(In millions)	2014		2013
Accounts payable—trade	$	278.8	$	216.3
Employee benefits and payroll accruals		19.8		23.4
Embedded derivatives and other accrued liabilities		14.6		30.9
Total	$	313.2	$	270.6
Washington Gas Light Company
	September 30,
(In millions)	2014		2013
Accounts payable—trade	$	146.4	$	99.7
Employee benefits and payroll accruals		18.2		21.4
Embedded derivatives and other accrued liabilities		11.9		11.7
Total	$	176.5	$	132.8

NOTE 4. SHORT-TERM DEBT

WGL and Washington Gas satisfy their short-term financing requirements through the sale of commercial paper or through bank borrowings. Due to the seasonal nature of the regulated utility and retail energy-marketing segments, short-term financing requirements can vary significantly during the year. Revolving credit agreements are maintained to support outstanding commercial paper and to permit short-term borrowing flexibility. WGL’s policy is to maintain bank credit facilities in amounts equal to or greater than the expected maximum commercial paper position. The following is a summary of committed credit available at September 30, 2014 and 2013.

Committed Credit Available (In millions)
September 30, 2014	WGL     Holdings, Inc.(b)		Washington  Gas		Total  Consolidated
Committed credit agreements
Unsecured revolving credit facility, expires April 3, 2017(a)	$	450.0	$	350.0	$	800.0
Less: Commercial Paper		(364.5)		(89.0)		(453.5)
Net committed credit available	$	85.5	$	261.0	$	346.5
Weighted average interest rate		0.20%		0.13%		0.19%
September 30, 2013
Committed credit agreements
Unsecured revolving credit facility, expires April 3, 2017(a)	$	450.0	$	350.0	$	800.0
Less: Commercial Paper		(248.6)		(124.5)		(373.1)
Net committed credit available	$	201.4	$	225.5	$	426.9
Weighted average interest rate		0.21%		0.13%		0.19%

^(a) Both WGL and Washington Gas have the right to request extensions with the banks’ approval. WGL’s revolving credit facility permits it to borrow an additional $100 million, with the banks’ approval, for a total of $550 million. Washington Gas’ revolving credit facility permits it to borrow an additional $100 million, with the banks’ approval, for a total of $450 million.

^(b) WGL Holdings includes all subsidiaries other than Washington Gas Light Company.

At September 30, 2014 and 2013, there were no outstanding bank loans from WGL’s or Washington Gas’ revolving credit facilities.

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Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

Under the terms of the credit agreements, the ratio of consolidated financial indebtedness to consolidated total capitalization may not exceed 0.65 to 1.0 (65%). In addition, WGL and Washington Gas are required to inform lenders of changes in corporate existence, financial conditions, litigation and environmental warranties that might have a material adverse effect. Failure to inform the lenders’ agent of these material changes might constitute default under the agreements. Another potential default may be deemed if WGL or Washington Gas fail to pay principal or interest when due on any other indebtedness. Such defaults, if not remedied, could lead to suspension of further loans and/or acceleration in which obligations become immediately due and payable. At September 30, 2014, WGL and Washington Gas were in compliance with all of the covenants under their revolving credit facilities.

NOTE 5. LONG-TERM DEBT

FIRST MORTGAGE BONDS

The Mortgage of Washington Gas dated January 1, 1933 (Mortgage), as supplemented and amended, securing any First Mortgage Bonds (FMBs) it issues, constitutes a direct lien on substantially all property and franchises owned by Washington Gas, other than a small amount of property that is expressly excluded. Washington Gas had no debt outstanding under the Mortgage at September 30, 2014 and 2013. Any FMBs that may be issued in the future will represent indebtedness of Washington Gas.

SHELF REGISTRATION

On August 18, 2014, WGL entered into an Indenture with The Bank of New York Mellon (the “Trustee”) to issue an unlimited amount of debt securities. Supplemental indentures will supplement the Indenture and establish the respective terms of the notes. The offering of the notes has been registered under a shelf registration statement on Form S-3.

At September 30, 2014, Washington Gas had the capacity under a shelf registration to issue up to $275.0 million of additional MTNs.

UNSECURED NOTES

Washington Gas issues unsecured MTNs and private placement notes with individual terms regarding interest rates, maturities and call or put options. These notes can have maturity dates of one or more years from the date of issuance. At September 30, 2014 and 2013, outstanding MTNs and private placement notes were $691.0 million and $583.0 million, respectively, at a weighted average interest rate of 5.65% and 5.91%, respectively.

The indenture for the unsecured MTNs and the note purchase agreement for the private placement notes provide that Washington Gas will not issue any FMBs under its Mortgage without securing all MTNs and the subject private placement notes with the Mortgage.

Certain of Washington Gas’ outstanding MTNs and private placement notes have a make-whole call feature that pays the holder a premium based on a spread over the yield to maturity of a U.S. Treasury security having a comparable maturity, when that particular note is called by Washington Gas before its stated maturity date. With the exception of this make-whole call feature, Washington Gas is not required to pay call premiums for calling debt prior to the stated maturity date.

The table below shows MTN and private placement issuances and retirements for the year ended September 30, 2014.

MTN and Private Placement Issuances and Retirements
($ In millions)	Principal		Interest       Rate			Nominal           Maturity  Date
Year Ended September 30, 2014
Issuances:
12/5/2013	$	75.0		5.00	%(a)		12/15/2043
9/12/2014		100.0		4.22	%(b)		9/15/2044
Total	$	175.0
Retirements:
11/7/2013	$	37.0		4.88	%		11/7/2013
9/10/2014		30.0		5.17	%		9/10/2014
Total	$	67.0
(a)The estimated effective cost of the issued notes, including consideration of issuances fees and hedge costs, is 4.95%. (b)The estimated effective cost of the issued notes, including consideration of issuances fees and hedge costs, is 4.27%.

There were no MTN or private placement issuances or retirements for the year ended September 30, 2013.

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

LONG-TERM DEBT MATURITIES

Maturities of long-term debt for each of the next five fiscal years and thereafter as of September 30, 2014 are summarized in the following table.

Long-Term Debt Maturities(a)
(In millions)	MTNs		Other		Total
2015	$	20.0	$	-	$              20.0
2016		25.0		-	25.0
2017		-		-	-
2018		-		-	-
2019		50.0		-	50.0
Thereafter		596.0		-	596.0
Total (before project debt financing)	$	691.0	$	-	$            691.0
Project debt financing(b)		-		8.3	8.3
Total	$	691.0	$	8.3	$            699.3
Less: current maturities		20.0		-	20.0
Total non-current	$	671.0	$	8.3	$            679.3
(a)Excludes unamortized discounts of $121,567 at September 30, 2014. (b)Project debt financing is anticipated to be a non-cash extinguishment. Refer to Note 13—Commitments and Contingencies for further discussion of this construction project financing.

NOTE 6. COMMON STOCK — WGL

COMMON STOCK OUTSTANDING

Shares of common stock outstanding were 50,656,553 and 51,774,204 at September 30, 2014 and 2013, respectively.

COMMON STOCK RESERVES

At September 30, 2014, there were 4,582,301 authorized, but unissued, shares of common stock reserved under the following plans:

Common Stock Reserves
Reserve for:	Number of Shares
Omnibus incentive compensation plan(a)		999,443
Dividend reinvestment and common stock purchase plan		2,849,012
Employee savings plans		637,196
Directors’ stock compensation plan		96,650
Total common stock reserves		4,582,301

^(a)In March 2007, WGL adopted a shareholder-approved Omnibus Incentive Compensation Plan to replace on a prospective basis the 1999 Incentive Compensation Plan. Included are shares that may be issued which would reduce the number of shares authorized under the Omnibus Incentive Compensation Plan. These shares include 301,378 shares dedicated to performance shares granted but not vested and include 5,318 shares dedicated to stock options issued but not exercised. Refer to Note 11—Stock-Based Compensation for a discussion regarding our stock-based compensation plans.

NOTE 7. PREFERRED STOCK

Washington Gas has three series of cumulative preferred stock outstanding, and each series is subject to redemption by Washington Gas. All three series have a dividend preference that prohibits Washington Gas from declaring and paying dividends on shares of its common stock unless dividends on all outstanding shares of the preferred stock have been fully paid for all past quarterly dividend periods. In addition, all outstanding shares of preferred stock have a preference as to the amounts that would be distributed in the event of a liquidation or dissolution of Washington Gas. The following table presents this information, as well as call prices for each preferred stock series outstanding.

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Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

Preferred Stock
Preferred		Liquidation Preference
Series	Shares	Per Share		Call Price
Outstanding	Outstanding	Involuntary	Voluntary	Per Share
$4.80	150,000	$100	$101	$101
$4.25	70,600	$100	$105	$105
$5.00	60,000	$100	$102	$102

NOTE 8. EARNINGS PER SHARE

Basic EPS is computed by dividing net income by the weighted average number of common shares outstanding during the reported period. Diluted EPS assumes the issuance of common shares pursuant to stock-based compensation plans at the beginning of the applicable period unless the effect of such issuance would be anti-dilutive (refer to Note 11—Stock-Based Compensation). The following table reflects the computation of our basic and diluted EPS for the fiscal years ended September 30, 2014, 2013 and 2012.

Basic and Diluted EPS
	Years Ended September 30,
(In thousands, except per share data)	2014		2013		2012
Basic earnings per average common share:
Net income applicable to common stock	$	105,940	$	80,253	$	139,818
Average common shares outstanding—basic		51,759		51,697		51,522
Basic earnings per average common share	$	2.05	$	1.55	$	2.71
Diluted earnings per average common share:
Net income applicable to common stock	$	105,940	$	80,253	$	139,818
Average common shares outstanding—basic		51,759		51,697		51,522
Stock-based compensation plans		11		111		67
Total average common shares outstanding—diluted		51,770		51,808		51,589
Diluted earnings per average common share	$	2.05	$	1.55	$	2.71

NOTE 9. INCOME TAXES

WGL files consolidated, federal, combined unitary including California, District of Columbia, West Virginia and various other state income tax returns. We are no longer subject to income tax examinations by the Internal Revenue Service (IRS) for years before September 30, 2011. Substantially all state income tax years in major jurisdictions are closed for years before September 30, 2010.

WGL and each of its subsidiaries also participate in a tax sharing agreement that establishes the method for allocating tax benefits from losses that are utilized on the consolidated income tax return. The consolidated tax is apportioned among the subsidiaries on the separate return method and losses of the parent, WGL, are allocated to the subsidiaries that have taxable income. In fiscal year 2014, Washington Gas shared $2.9 million of tax benefits from the tax sharing agreement that was reflected as a tax decrease on Washington Gas’ statements of income. During fiscal years 2013 and 2012, Washington Gas realized $1.3 million and $0.3 million of tax savings as a result of this tax sharing agreement. The effect of this allocation of benefits to Washington Gas has no effect on our consolidated financial statements. State income tax returns are filed on a separate company basis in most states where we have operations and/or a requirement to file. Beginning with the fiscal year ended September 30, 2012, we filed a combined unitary return for California, District of Columbia and West Virginia due to recent law changes.

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

Washington Gas provides certain healthcare benefits for active and retired employees (the Plan). Washington Gas is self-insured for the majority of healthcare costs. Because the Plan provides prescription drug benefits equal to or greater than Medicare Part D (Med D) coverage, Washington Gas qualified for a non-taxable subsidy from the federal government, which has had the effect of lowering other post retirement employee benefit expense (OPEB) and Washington Gas’ effective tax rate.

Since the year ended September 30, 2004, Washington Gas reflected the favorable tax benefit (“the Med D tax benefit”) of the non-taxable subsidy in its effective tax rate. The Patient Protection and Affordable Care Act and the Health Care and Education Reconciliation Act (collectively the “PPACA”) became law which eliminated future Med D tax benefits for Washington Gas’ tax years beginning after September 30, 2013. During the fiscal year ended September 30, 2010, regulatory assets were increased by $42.2 million to reflect the probable recovery of the higher future tax expense from utility customers and an immaterial amount of tax expense was recorded related to the effect of the PPACA on our non-utility business. Based on positions taken by the SCC of VA in Washington Gas’ rate case during the fiscal year ended September 30, 2011, we determined that it was not probable that the SCC of VA would permit recovery of this asset. Therefore, the Virginia portion of the regulatory asset related to the Med D benefit was charged to tax expense which resulted in an increase in the effective tax rate for the fiscal year ended September 30, 2011. Washington Gas charged the Maryland portion of the Med D regulatory asset to tax expense during the fiscal year ended September 30, 2012, based on positions taken by the PSC of MD in Washington Gas’ rate case during the fiscal year that didn’t permit recovery. Washington Gas received an order in the first quarter of the current fiscal year end September 30, 2014 in its recent rate case from the PSC of MD that will allow recovery of the Med D regulatory asset over a 5-year amortization period. Therefore the tax benefit has been recognized to reinstate the regulatory asset which results in a decrease in the effective rate for the fiscal year ended September 30, 2014. The Med D adjustments results in an effective tax rate at September 30, 2014 of 34.8%. The Med D adjustment results in an effective rate for Washington Gas at September 30, 2014 of 32.6%. In June 2013, the District of Columbia approved a 5-year amortization of the regulatory asset relating to Med D, which should have a minimal impact to the effective tax rate over the period allowed.

On September 13, 2013, the U.S. Treasury Department issued final income tax regulations to address the costs incurred in acquiring, producing, or improving tangible property. The regulations are effective for WGL and Washington Gas for the tax year beginning October 1, 2014. WGL and Washington Gas have assessed the financial impact of these regulations, and we do not expect the guidance to have a material impact on the financial statements. Any changes in method of accounting for income tax purposes required to conform to the final regulations will be made for the taxable year ending September 30, 2015.

The tables below provide the following for WGL and Washington Gas: (i) the components of income tax expense; (ii) a reconciliation between the statutory federal income tax rate and the effective income tax rate and (iii) the components of accumulated deferred income tax assets and liabilities at September 30, 2014 and 2013.

WGL Holdings, Inc.
Components of Income Tax Expense
	Years Ended September 30,
(In thousands)	2014			2013		2012
INCOME TAX EXPENSE
Current:
Federal	$	29,976		$	41,425	$	(13,188)
State		5,149			11,258		(30)
Total current		35,125			52,683		(13,218)
Deferred:
Federal
Accelerated depreciation		35,747			33,394		45,506
Other		(18,014	)		(31,173)		44,727
State
Accelerated depreciation		9,822			6,795		9,412
Other		(1,760	)		(7,585)		8,054
Total deferred		25,795			1,431		107,699
Amortization of investment tax credits		(3,666	)		(1,822)		(1,132)
Total income tax expense	$	57,254		$	52,292	$	93,349

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

WGL Holdings, Inc.
Reconciliation Between the Statutory Federal Income Tax Rate and Effective Tax Rate
	Years Ended September 30,
($ In thousands)	2014					2013					2012
Income taxes at statutory federal income tax rate	$	57,580		35.00	%	$	46,853		35.00	%	$	82,070		35.00	%
Increase (decrease) in income taxes resulting from:
Accelerated depreciation less amount deferred		1,875		1.14			2,106		1.57			1,178		0.50
Amortization of investment tax credits		(3,666	)	(2.23	)		(1,822	)	(1.36	)		(1,132	)	(0.48	)
Cost of removal		(4,902	)	(2.98	)		(2,356	)	(1.76	)		(2,291	)	(0.98	)
State income taxes-net of federal benefit		8,734		5.31			7,448		5.56			12,068		5.15
Medicare Part D adjustment		(3,621	)	(2.20	)		-		-			2,827		1.21
Other items-net		1,254		0.76			63		0.05			(1,371	)	(0.59	)
Total income tax expense and effective tax rate	$	57,254		34.80	%	$	52,292		39.06	%	$	93,349		39.81	%

WGL Holdings, Inc.
Components of Deferred Income Tax Assets (Liabilities)
	September 30,
(In thousands)	2014					2013
ACCUMULATED DEFERRED INCOME TAXES	Current		Non-current			Current			Non-current
Deferred income tax assets:
Pensions	$	-	$	24,349		$	-		$	17,362
Other post-retirement benefits		-		-			-			18,510
Uncollectible accounts		9,268		-			8,127			-
Inventory overheads		6,591		-			6,431			-
Capital gains/losses-net		-		-			2			-
Valuation allowance		-		-			(2	)		-
Employee compensation and benefits		6,306		37,873			5,876			37,301
Customer advances		-		197			-			197
Derivatives		6,503		31,555			-			7,872
Deferred gas costs		-		4,218			4,911			-
Solar grant/investment tax credit		-		39,184			-			17,415
Other		814		1,225			816			2,530
Total assets		29,482		138,601			26,161			101,187
Deferred income tax liabilities:
Other post-retirement benefits		-		38,299			-			-
Accelerated depreciation and other plant related items		-		669,040			-			596,754
Losses/gains on reacquired debt		-		1,426			-			1,567
Income taxes recoverable through future rates		-		65,374			-			112,222
Deferred gas costs		2,818		-			-			4,667
Derivatives		-		-			1,639			-
Partnership basis differences		-		25,370			-			15,784
Total liabilities		2,818		799,509			1,639			730,994
Net accumulated deferred income tax assets (liabilities)	$	26,664	$	(660,908	)	$	24,522		$	(629,807	)

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

Washington Gas Light Company
Components of Income Tax Expense
	Years Ended September 30,
(In thousands)	2014			2013			2012
INCOME TAX EXPENSE
Current:
Federal	$	37,098		$	40,492		$	(13,155	)
State		4,262			7,515			(3,332	)
Total current		41,360			48,007			(16,487	)
Deferred:
Federal
Accelerated depreciation		34,833			34,518			45,661
Other		(30,523	)		(35,982	)		27,851
State
Accelerated depreciation		9,540			6,770			9,423
Other		(6,800	)		(8,221	)		6,197
Total deferred		7,050			(2,915	)		89,132
Amortization of investment tax credits		(876	)		(895	)		(898	)
Total income tax expense	$	47,534		$	44,197		$	71,747

Washington Gas Light Company
Reconciliation Between the Statutory Federal Income Tax Rate and Effective Tax Rate
	Years Ended September 30,
($ In thousands)	2014					2013					2012
Income taxes at statutory federal income tax rate	$	51,050		35.00	%	$	40,782		35.00	%	$	63,628		35.00	%
Increase (decrease) in income taxes resulting from:
Accelerated depreciation less amount deferred		1,875		1.29			2,106		1.81			1,178		0.65
Amortization of investment tax credits		(876	)	(0.60	)		(895	)	(0.77	)		(898	)	(0.49	)
Cost of removal		(4,902	)	(3.36	)		(2,356	)	(2.02	)		(2,291	)	(1.26	)
State income taxes-net of federal benefit		6,711		4.60			5,487		4.71			8,916		4.90
Consolidated tax sharing allocation		(2,862	)	(1.96	)		(1,290	)	(1.11	)		(309	)	(0.17	)
Medicare Part D adjustment		(3,621	)	(2.48	)		-		-			2,827		1.56
Other items-net		159		0.09			363		0.31			(1,304	)	(0.72	)
Total income tax expense and effective tax rate	$	47,534		32.58	%	$	44,197		37.93	%	$	71,747		39.47	%

98

WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

Washington Gas Light Company
Components of Deferred Income Tax Assets (Liabilities)
	Years Ended September 30,
(In thousands)	2014				2013
ACCUMULATED DEFERRED INCOME TAXES	Current		Non-current		Current		Non-current
Deferred income tax assets:
Pensions	$	-	$	23,738	$	-	$	16,768
Other post-retirement benefits		-		-		-		18,474
Uncollectible accounts		7,618		-		6,948		-
Inventory overheads		6,591		-		6,431		-
Employee compensation and benefits		5,902		27,961		5,756		27,125
Customer advances		-		197		-		197
Derivatives		4,809		31,555		2,138		7,872
Deferred gas costs		-		4,218		4,911		-
Investment tax credit		-		312		-		312
Other		814		-		816		1,727
Total assets		25,734		87,981		27,000		72,475
Deferred income tax liabilities:
Other post-retirement benefits		-		38,065		-		-
Accelerated depreciation and other plant related items		-		602,376		-		565,996
Losses/gains on reacquired debt		-		1,426		-		1,567
Income taxes recoverable through future rates		-		65,128		-		111,698
Deferred gas costs		2,818		-		-		4,667
Other		-		932		-		-
Total liabilities		2,818		707,927		-		683,928
Net accumulated deferred income tax assets (liabilities)	$	22,916	$	(619,946)	$	27,000	$	(611,453)

In June 2014, we filed our tax return for the year ended September 30, 2013.

The following table summarizes the change in unrecognized tax benefits during fiscal year 2014, 2013, 2012 and our total unrecognized tax benefits at September 30, under the provisions of ASC Topic 740, Income Taxes:

Unrecognized Tax Benefits
(In thousands)	2014			2013			2012
Total unrecognized tax benefits, October 1,	$	25,051		$	22,082		$	20,699
Increases in tax positions relating to current year		10,512			5,251			3,396
Decreases in tax positions relating to prior year		(2,950	)		(2,282	)		(2,013	)
Total unrecognized tax benefits, September 30,	$	32,613		$	25,051		$	22,082

During the year, the unrecognized tax benefits for WGL and Washington Gas increased by approximately $7.6 million relating to uncertain tax positions, primarily due to the change in tax accounting for repairs. If the amounts of unrecognized tax benefits are eventually realized, it would not materially impact the effective tax rate. It is reasonably possible that the amount of the unrecognized tax benefit with respect to some of WGL’s and Washington Gas’ uncertain tax positions will increase or decrease in the next 12 months. The IRS completed its audit of the tax years related to the change in accounting method for repairs without proposing any changes, however, they could re-examine this issue in the future.

99

WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

WGL and Washington Gas recognize any accrued interest associated with uncertain tax positions in interest expense and recognizes any accrued penalties associated with uncertain tax positions in other expenses in the statements of income. During the fiscal year ended September 30, 2014, we reversed minimal interest and during the fiscal year ended September 30, 2013 we accrued minimal interest expenses on uncertain tax positions. During the fiscal year ended September 30, 2012, we reversed $1.6 million for interest on uncertain tax positions.

NOTE 10. PENSION AND OTHER POST-RETIREMENT BENEFIT PLANS

Washington Gas maintains a qualified, trusteed, non-contributory defined benefit pension plan (qualified pension plan) covering most active and vested former employees of Washington Gas. The non-contributory defined benefit pension plan is closed to all employees hired on or after January 1, 2010. Washington Gas accounts for the qualified pension plan and other post-retirement benefit plans under the provisions of ASC 715, Compensation-Retirement Benefits.

Most executive officers of Washington Gas also participate in a non-funded defined benefit supplemental executive retirement plan (DB SERP), a non-qualified pension plan. A rabbi trust has been established for the potential future funding of the DB SERP liability. The DB SERP was closed to new entrants beginning January 1, 2010 and instead, executive officers are eligible to participate in a new non-funded defined contribution SERP (DC SERP). In addition, effective January 1, 2010, Washington Gas established a non-funded defined benefit restoration plan (DB restoration) for the purpose of providing supplemental pension and pension-related benefits to a select group of management employees.

WGL subsidiaries offer defined-contribution savings plans to all eligible employees. These plans allow participants to defer on a pre-tax or after-tax basis, a portion of their salaries for investment in various alternatives. We make matching contributions to the amounts contributed by employees in accordance with the specific plan provisions. The Washington Gas plan was amended during 2013 to implement the merger of the WGEServices plan. The WGEServices plan was merged into the Washington Gas plan effective January 1, 2014. Beginning January 1, 2014, matching and supplemental contributions to the Washington Gas plan included matching and supplemental contributions from the former WGEServices plan. Total matching contributions to the Washington Gas plan were $4.2 million, $3.5 million and $3.4 million during fiscal years 2014, 2013 and 2012, respectively. All employees not participating in the qualified pension plan receive an employer provided supplemental contribution ranging from 4% to 6% depending on years of service. Total supplemental contributions to the plan were $1.6 million, $0.8 million and $0.6 million during fiscal years ended September 30, 2014, 2013 and 2012, respectively.

Total matching contributions to the former WGEServices plan were $0.8 million and $0.4 million during fiscal years 2013 and 2012, respectively.

Washington Gas provides certain healthcare and life insurance benefits for retired employees. Substantially all employees of Washington Gas may become eligible for such benefits if they attain retirement status while working for Washington Gas. Washington Gas accounts for these benefits under the provisions of ASC 715, Compensation-Retirement Benefits. Washington Gas elected to amortize the accumulated post-retirement benefit obligation of $190.6 million existing at the October 1, 1993 adoption date of this standard, known as the transition obligation, over a twenty-year period ended in 2013.

On April 24, 2014, Washington Gas replaced the existing retiree medical benefit plan and dental plan options for Medicare-eligible retirees age 65 and older with a special tax-free Health Reimbursement Account (HRA) plan effective January 1, 2015. With the introduction of the new plan, effective January 1, 2015, participating retirees and dependents will receive a subsidy each year through the HRA account to help purchase supplemental medical and dental coverage in the marketplace. As part of the new HRA plan, participants who enroll in a Medicare Part D prescription drug plan and meet the threshold for Medicare catastrophic prescription drug coverage will be eligible for an additional reimbursement of their out-of-pocket prescription drug costs in excess of the threshold. Retirees and dependents under age 65 will still be covered under the existing Washington Gas Retiree Medical Plan until they become eligible for Medicare at age 65 and can obtain coverage through the new HRA plan. Due to the impact of the amendment, we remeasured the funded status of the plan in April 2014. The funded status of the plan changed by approximately $127.5 million from an underfunded liability to an overfunded asset as a result of the plan amendment. The offsetting amount for this remeasurement was substantially recorded as a decrease to regulatory assets. The overfunded asset for this plan at September 30, 2014 was $96.4 million.

Almost all costs associated with Washington Gas’ defined benefit post-retirement plans have historically been, and will continue to be, recovered through Washington Gas’ rates. Therefore, in accordance with ASC Topic 980 and ASC Topic 715, Washington Gas established a regulatory asset/liability for the substantial majority of the unrecognized costs/income associated with its defined benefit post-retirement plans. To the extent these amounts will not be recovered through Washington Gas’ rates, they are recorded directly to “Accumulated other comprehensive loss, net of taxes.”

100

WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

Obligations and Assets

Washington Gas uses a measurement date of September 30 for its pension, and retiree healthcare and life insurance benefit plans. The following table provides certain information about Washington Gas’ post-retirement benefits:

Post-Retirement Benefits
							Health and Life
(In millions)	Pension Benefits(a)						Benefits
Year Ended September 30,	2014			2013			2014			2013
Change in projected benefit obligation(b)
Benefit obligation at beginning of year	$	837.4		$	937.2		$	429.8		$	480.1
Service cost		14.0			17.0			7.6			9.6
Interest cost		40.4			36.6			18.7			18.8
Change in plan benefits		-			-			(136.5	)		-
Actuarial loss (gain)		68.6			(110.0	)		38.2			(62.3)
Retiree contributions		-			-			4.4			3.9
Medicare Part D reimbursements		-			-			0.5			0.7
Benefits paid		(43.3	)		(43.4	)		(19.5	)		(21.0)
Projected benefit obligation at end of year(b)	$	917.1		$	837.4		$	343.2		$	429.8
Change in plan assets
Fair value of plan assets at beginning of year	$	745.2		$	750.6		$	380.9		$	358.3
Actual return on plan assets		103.3			38.6			57.8			19.9
Company contributions		1.7			1.8			16.0			18.0
Retiree contributions and Medicare Part D reimbursements		-			-			4.4			5.7
Expenses		(2.2	)		(2.4	)		-			-
Benefits paid		(43.3	)		(43.4	)		(19.5	)		(21.0)
Fair value of plan assets at end of year	$	804.7		$	745.2		$	439.6		$	380.9
Funded status at end of year	$	(112.4	)	$	(92.2	)	$	96.4		$	(48.9)
Total amounts recognized on balance sheet
Non-current asset	$	-		$	-		$	96.4		$	-
Current liability		(4.2	)		(3.5	)		-			-
Non-current liability		(108.2	)		(88.7	)		-			(48.9)
Total recognized	$	(112.4	)	$	(92.2	)	$	96.4		$	(48.9)

^(a)The DB SERP and DB Restoration, included in pension benefits in the table above, have no assets.

^(b)For the Health and Life Benefits, the change in projected benefit obligation represents the accumulated benefit obligation.

The following table provides the projected benefit obligation (PBO) and accumulated benefit (ABO) for the qualified pension plan, DB SERP and DB Restoration at September 30, 2014 and 2013.

Projected and accumulated benefit obligation
(In millions)	Qualified Pension Plan				DB SERP				DB Restoration
September 30,	2014		2013		2014		2013		2014		2013
Projected benefit obligation	$	865.2	$	788.8	$	50.7	$	47.8	$	1.2	$	0.8
Accumulated benefit obligation	$	801.9	$	737.2	$	46.2	$	43.9	$	0.7	$	0.5

AMOUNTS RECOGNIZED IN REGULATORY ASSETS/LIABILITIES AND ACCUMULATED OTHER COMPREHENSIVE INCOME

The following table provides amounts recorded to regulatory assets, regulatory liabilities and accumulated other comprehensive loss at September 30, 2014 and 2013:

Unrecognized Costs/Income Recorded on the Balance Sheet
(In millions)	Pension Benefits				Health and Life Benefits
September 30,	2014		2013		2014		2013
Actuarial net loss	$	162.6	$	171.1	$	50.1	$	55.3
Prior service cost (credit)		1.2		1.3		(149.3)		(22.4)
Total	$	163.8	$	172.4	$	(99.2)	$	32.9
Regulatory asset (liability)	$	147.9	$	155.1	$	(94.6)	$	31.3
Pre-tax accumulated other comprehensive loss (gain)(a)		15.9		17.3		(4.6)		1.6
Total	$	163.8	$	172.4	$	(99.2)	$	32.9

^(a)The total amount of accumulated other comprehensive loss recorded on our balance sheets at September 30, 2014 and 2013 is net of an income tax benefit of $4.9 million and $7.9 million, respectively.

101

WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

The following table provides amounts that are included in regulatory assets/liabilities and accumulated other comprehensive loss associated with our unrecognized pension and other post-retirement benefit costs that were recognized as components of net periodic benefit cost during fiscal year 2014.

Amounts Recognized During Fiscal Year 2014
	Regulatory assets/liabilities				Accumulated other comprehensive loss
(In millions)	Pension      Benefits		Health and   Life Benefits		Pension       Benefits		Health and    Life Benefits
Actuarial net loss		$    15.5		$      4.8		$     1.3	$       0.3
Prior service cost (credit)		0.2		(9.1)		0.1	(0.5)
Total		$    15.7		$    (4.3)		$     1.4	$     (0.2)

The following table provides amounts that are included in regulatory assets/liabilities and accumulated other comprehensive loss associated with our unrecognized pension and other post-retirement benefit costs that are expected to be recognized as components of net periodic benefit cost during fiscal year 2015.

Amounts to be Recognized During Fiscal Year 2015
	Regulatory assets/liabilities			Accumulated other comprehensive loss
(In millions)	Pension      Benefits		Health and    Life Benefits	Pension       Benefits		Health and    Life Benefits
Actuarial net loss		$    17.1	$           4.2		$     1.7	$         0.2
Prior service cost (credit)		0.2	(14.5)		0.1	(0.7)
Total		$    17.3	$       (10.3)		$     1.8	$       (0.5)

The increase in the actuarial net loss for pension benefits to be recognized in fiscal year 2015 when compared to fiscal year 2014 is primarily due to a decrease in the discount rate for our qualified pension plan. The decrease in the actuarial net loss for health and life benefits to be recognized in fiscal year 2015 when compared to fiscal year 2014 is primarily due to updated census data, offset by a decrease in the discount rate for our health and life plan.

Realized and unrealized gains and losses for assets under Washington Gas’ post-retirement benefit plans are spread over a period of five years. Each year, 20% of the prior five years’ asset gains and losses are recognized. The market-related value of assets is equal to the market value of assets less the following percentages of prior years’ realized and unrealized gains and losses on equities: 80% of the prior year, 60% of the second prior year, 40% of the third prior year and 20% of the fourth prior year.

102

WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

Net Periodic Benefit Cost

The components of the net periodic benefit costs (income) for fiscal years ended September 30, 2014, 2013 and 2012 related to pension and other postretirement benefits were as follows:

Components of Net Periodic Benefit Costs (Income)
(In millions)	Pension Benefits						Health and Life Benefits
Year Ended September 30,	2014		2013		2012		2014		2013		2012
Service cost	$	14.0	$	17.0	$	12.9	$	7.6	$	9.6	$      8.0
Interest cost		40.4		36.6		40.5		18.7		18.8	25.1
Expected return on plan assets		(41.0)		(41.9)		(43.5)		(19.3)		(18.3)	(18.8)
Recognized prior service cost		0.3		1.0		1.0		(9.6)		(3.9)	(3.9)
Recognized actuarial loss		16.8		28.7		16.1		5.0		9.2	13.3
Amortization of transition obligation		-		-		-		-		1.1	1.1
Net periodic benefit cost		30.5		41.4		27.0		2.4		16.5	24.8
Amount allocated to construction projects		(4.3)		(5.7)		(3.4)		(0.4)		(2.8)	(3.7)
Amount deferred as regulatory asset (liability)-net		7.0		(3.7)		(7.5)		(2.3)		2.4	1.5
Amount charged (credited) to expense	$	33.2	$	32.0	$	16.1	$	(0.3)	$	16.1	$    22.6

Amounts included in the line item “Amount deferred as regulatory asset/liability-net,” represent the difference between the cost of the applicable pension benefits and the health and life benefits and the amount that Washington Gas is permitted to recover in rates that it charges to customers in the District of Columbia. In June 2013, this mechanism was discontinued, however, any balances remaining will be amortized over five years.

ASSUMPTIONS

The weighted average assumptions used to determine net periodic benefit obligations and net periodic benefit costs were as follows:

Benefit Obligations Assumptions
	Pension Benefits				Health and Life Benefits
September 30,	2014		2013		2014		2013
Discount rate(a)		4.00%-4.40%		4.50%-5.00%		4.40%	5.10%
Rate of compensation increase		3.50%-4.10%		3.85%-5.15%		4.10%	3.85%

^(a)The decrease in the discount rate in fiscal year 2014 compared to prior years primarily reflects the decrease in long-term interest rates.

Net Periodic Benefit Cost Assumptions
	Pension Benefits					Health and Life Benefits
Years Ended September 30,	2014	2013		2012		2014	2013		2012
Discount rate(a)	4.50%-5.00%		4.00%		5.30%	4.60%-5.10%		4.00%		5.10%
Expected long-term return on plan assets(b)	6.50%		6.75%		7.50%	6.25%		6.75%		7.40%
Rate of compensation increase(c)	3.85%-5.15%		3.85%-5.15%		3.85%-5.15%	3.85%		3.85%		3.85%-5.15%

^(a) The changes in the discount rates over the last two fiscal years primarily reflects the changes in long-term interest rates.

^(b) For health and life benefits, the expected returns for certain funds may be lower due to certain portions of income that are subject to an assumed income tax rate of 41.5%.

^(c) The changes in the rate of compensation reflects the best estimates of actual future compensation levels including consideration of general price levels, productivity, seniority, promotion, and other factors such as inflation rates.

Washington Gas determines the expected long-term rate of return on plan assets by averaging the expected earnings for the target asset portfolio. In developing the expected rate of return assumption, Washington Gas evaluates an analysis of historical actual performance and long-term return projections, which gives consideration to our asset mix and anticipated length of obligation of our plan.

Washington Gas assumed the healthcare cost trend rates related to the accumulated post-retirement benefit obligation for non-Medicare eligible retirees to be 7.0% and 7.5% for fiscal years 2014 and 2013, respectively. Washington Gas expects these rates to decrease gradually to 5.0% in 2021 and remain at those levels thereafter. For Medicare eligible retirees age 65 and older that will receive a subsidy each year through an HRA account, Washington Gas assumed a 3.0% increase to approximate possible future increases to the stipend. While the plan terms do not guarantee increases to the stipend, Washington Gas intends to review the stipend annually.

103

WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

Healthcare Trends
(In millions)	One Percentage-Point  Increase			One Percentage-Point Decrease
Increase (decrease) total service and interest cost components		$	3.6		$      (2.7)
Increase (decrease) post-retirement benefit obligation		$	10.5		$      (9.2)

INVESTMENT POLICIES AND STRATEGIES

The investment objective of the qualified pension, healthcare, and life insurance benefit plans (“Plan” or “Plans”) is to allocate each Plan’s assets to appropriate investment asset classes (asset categories) so that the benefit obligations of each Plan are adequately funded, consistent with appropriate risk tolerance guidelines for the Plans’ and Washington Gas’ tolerance for risk.

In order to best achieve the investment objectives for each Plan, strategic allocation targets and ranges are established that control exposure to selected investment asset classes. Asset/liability modeling (ALM) is used to test the benefits and risks of several potential strategic asset allocation mixes. Simulated investment performance results based on assumptions about expected return, volatility, and correlation characteristics of the selected asset classes are tested for their effects on contributions, pension expense, PBO funded status, and downside Value at Risk metrics over a ten-year planning time horizon. Important outcomes from past ALM studies include decisions to increase fixed income exposure and to lengthen the duration of those fixed income assets. Both changes result in a better matching of each Plan’s assets and liabilities, and help reduce volatility of each Plan’s funded status. Implementation of these fixed income strategies occurred during fiscal year 2010 for the qualified pension plan and during fiscal year 2011 for the healthcare and life insurance benefit plans.

A pension plan ALM study that was completed during November 2011 resulted in a one-way dynamic asset allocation strategy that allows for the de-risking of the portfolio over time. Under this strategy, the target fixed income allocation percentage will increase by 5% for each 5% improvement in the plan’s funded ratio, as measured by an investment consultant. This strategy resulted in portfolio de-risking during October 2012 including increased fixed income exposure and reduced U.S. large-cap equity exposure.

For the qualified pension plan, Washington Gas’ funding policy is to contribute an amount sufficient to satisfy the minimum annual funding requirements under the Pension Protection Act. Any contributions above the minimum annual funding requirements would be limited to amounts that are deductible under appropriate tax law. For the healthcare and life insurance benefit plans, Washington Gas’ funding policy is to contribute amounts that are collected from ratepayers.

Significant amounts of the various Plans’ assets are managed by the same financial institution. In addition, the Plans have a high exposure to U.S. based investments. There are no other significant risk concentrations related to investments in any entity, industry, country, commodity, or investment fund.

Target qualified pension plan trust asset allocations are 32.5% U.S. Large-Cap Equities, 4.5% U.S. Small/Mid-Cap Equities, 8% International Equities, 5% Real Estate, and 50% Fixed Income.

Washington Gas’ portion of retired employee healthcare and life insurance benefits obligation is funded through two trusts: (i) the Washington Gas Light Company Postretirement Benefit Master Trust for Retired Previously Union-Eligible Employees (“union-eligible trust”) and (ii) the Washington Gas Light Company Postretirement Benefit Master Trust for Retired Management Employees (“management trust”). Target asset allocations are 50% U.S. Large-Cap Equities and 50% Fixed Income for the union-eligible trust. Target allocations are 60% U.S. Large-Cap Equities and 40% Fixed Income for the management trust.

Actual asset balances are reviewed monthly, and are allowed to range within plus or minus 5% or less of the target allocations. Assets are generally rebalanced to target allocations before actual amounts fall below or rise above the allowable ranges.

Investment vehicles used to manage qualified pension plan trust and management trust assets include commingled funds and separately managed portfolios. A private placement mutual fund is also employed to manage a portion of qualified pension plan trust assets. Commingled funds are used in the management of union-eligible trust assets.

104

WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

U.S. and international equity assets are diversified across sectors, industries, and investment styles. Fixed income assets are primarily diversified across U.S. government and investment grade corporate debt instruments, with some exposure to foreign sovereign debt and minor exposure to non-investment-grade securities. Real estate is diversified geographically across the U.S. by property type.

The qualified pension plan’s investment policy allows the use of futures, options, and other derivatives for purposes of reducing portfolio risk and as a low-cost option for gaining market exposure, but derivatives may not be used for leverage. The qualified pension plan’s investment policy prohibits investments in Washington Gas securities. The prohibition applies to separately managed portfolios but does not apply to any commingled fund investments.

The following tables present the fair value of the pension plan assets by asset category as of September 30, 2014 and 2013:

Pension Plan Assets
											% of
($ In millions)	Level 1		Level 2			Level 3		Total			Total
At September 30, 2014
Cash and cash equivalents	$	0.6	$	-		$	-	$	0.6			0.1	%
Equity securities
U.S. Small Cap		32.3		-			-		32.3			4.0
Preferred Securities		-		0.1			-		0.1			-
Fixed income securities
U.S. Treasuries		-		110.6			-		110.6			13.8
U.S. Corporate Debt		-		108.4			-		108.4			13.5
U.S. Agency Obligations and Government Sponsored Entities		-		24.6			-		24.6			3.0
Asset-Backed Securities and Collateralized Mortgage Obligations		-		1.8			-		1.8			0.2
Municipalities		-		9.2			-		9.2			1.1
Non-U.S. Corporate Debt		-		23.8			-		23.8			3.0
Repurchase Agreements(a)		-		2.5			-		2.5			0.3
Other(b)		-		7.0			-		7.0			0.8
Mutual Funds(c)		-		112.4			-		112.4			14.0
Commingled Funds and Pooled Separate Accounts(d)		-		316.2			23.8		340.0			42.3
Private Equity/Limited Partnerships(e)		-		30.5			-		30.5			3.8
Derivatives(f)		-		(0.1	)		-		(0.1	)		-
Total fair value of plan investments	$	32.9	$	747.0		$	23.8	$	803.7			99.9	%
Receivable (payable)(g)									1.0			0.1
Total plan assets at fair value								$	804.7			100.0	%

105

WGL Holdings, Inc.

Washington Gas Light Company

Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

Pension Plan Assets
											% of
($ In millions)	Level 1		Level 2			Level 3		Total			Total
At September 30, 2013
Cash and cash equivalents	$	0.9	$	-		$	-	$	0.9			0.1	%
Equity securities
U.S. Small Cap		31.5		-			-		31.5			4.2
Preferred Securities		-		0.1			-		0.1			-
Fixed income securities
U.S. Treasuries		-		124.5			-		124.5			16.7
U.S. Corporate Debt		-		93.6			-		93.6			12.6
U.S. Agency Obligations and Government Sponsored Entities		-		19.0			-		19.0			2.5
Asset-Backed Securities and Collateralized Mortgage Obligations		-		1.9			-		1.9			0.2
Municipalities		-		9.0			-		9.0			1.2
Non-U.S. Corporate Debt		-		18.4			-		18.4			2.5
Repurchase Agreements(a)		-		1.0			-		1.0			0.1
Other(b)		-		5.7			-		5.7			0.8
Mutual Funds(c)		-		93.2			-		93.2			12.5
Commingled Funds and Pooled Separate Accounts(d)		-		295.5			21.1		316.6			42.5
Private Equity/Limited Partnerships(e)		-		33.3			-		33.3			4.5
Derivatives(f)		-		(0.3	)		-		(0.3	)		-
Total fair value of plan investments	$	32.4	$	694.9		$	21.1	$	748.4			100.4	%
Receivable (payable)(g)									(3.2	)		(0.4)
Total plan assets at fair value								$	745.2			100.0	%

^(a) This category includes Treasury Bills with a pre-commitment from the counterparty to repurchase the same securities on the next business day at an agreed-upon price.

^(b) This category primarily includes Yankee bonds and non-U.S. government bonds.

^(c) At September 30, 2014 and September 30, 2013, investments in mutual funds consisted primarily of corporate fixed income instruments.

^(d) At September 30, 2014, investments in commingled funds and pooled separate accounts consisted primarily of 75% common stock of large-cap U.S. companies; 14% income producing properties located in the United States; 9% equity securities of non-U.S. companies; and 2% short-term money market investments. At September 30, 2013, investments in commingled funds and pooled separate accounts consisted primarily of 67% common stock of large-cap U.S. companies; 12% income producing properties located in the United States; 20% equity securities of non-U.S. companies; and 1% short-term money market investments.

^(e)  At September 30, 2014, investments in private equity/limited partnership consisted of common stock of international companies.

^(f) At September 30, 2014, this category includes long-term U.S. Treasury interest rate futures contracts and interest rate put options.

^(g) At September 30, 2014, this receivable represents a pending trade for investment sales. At September 30, 2013, this payable represents a pending trade for investment purchases.

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Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

Healthcare and Life Insurance Plan Assets
										% of
($ In millions)	Level 1		Level 2		Level 3		Total			Total
At September 30, 2014
Cash and Cash Equivalents	$	0.8	$	-	$	-	$	0.8			0.2	%
Mutual Funds(a)		-		1.9		-		1.9			0.4
Fixed Income Securities
U.S Agency Obligations		-		2.0		-		2.0			0.5
U.S. Treasuries		-		25.6		-		25.6			5.8
U.S. Corporate Debt		-		34.0		-		34.0			7.7
Municipalities		-		4.8		-		4.8			1.1
Non-U.S. Corporate Debt		-		5.7		-		5.7			1.3
Others(b)		-		5.3		-		5.3			1.2
Commingled Funds(c)		-		359.7		-		359.7			81.8
Total fair value of plan investments	$	0.8	$	439.0	$	-	$	439.8			100.0	%
Receivable (payable)								(0.2	)		-
Total plan assets at fair value							$	439.6			100.0	%
At September 30, 2013
Cash and Cash Equivalents	$	0.6	$	-	$	-	$	0.6			0.2	%
Fixed Income Securities
U.S Agency Obligations		-		1.7		-		1.7			0.4
U.S. Treasuries		-		23.6		-		23.6			6.2
U.S. Corporate Debt		-		28.7		-		28.7			7.5
Municipalities		-		4.1		-		4.1			1.1
Non-U.S. Corporate Debt		-		4.6		-		4.6			1.2
Others(b)		-		5.3		-		5.3			1.4
Commingled Funds(c)		-		311.2		-		311.2			81.7
Total fair value of plan investments	$	0.6	$	379.2	$	-	$	379.8			99.7	%
Receivable (payable)								1.1			0.3
Total plan assets at fair value							$	380.9			100.0	%

^(a) At September 30, 2014, investments in mutual funds consisted primarily of 63% short-term obligations consisting of certificates of deposit and time deposits, 23% high-quality commercial paper, 6% repurchase agreements, 4% corporate notes of U.S. and foreign corporations and 4% U.S. governmental and U.S. agency securities.

^(b) At September 30, 2014 and 2013, this category consisted primarily of 82% non-U.S. government bonds and 18% Yankee bonds.

^(c) At September 30, 2014 and 2013, investments in commingled funds consisted primarily of 66% common stock of large-cap U.S. companies, 17% U.S. agency obligations and government sponsored entities and 17% corporate bonds.

Valuation Methods

Equity securities are traded on a securities exchange and are valued at the closing quoted market price as of the balance sheet date.

Mutual funds are valued at the quoted net asset value (NAV) per share, which is computed as of the close of business on the balance sheet date. Mutual funds with a publicly quoted NAV per share are classified as Level 1; mutual funds with a NAV per share that is not made publicly available are classified as Level 2. Real Estate Investment Funds which have redemption restrictions are classified as Level 3.

Commingled funds and pooled separate accounts are valued at the quoted NAV per unit, computed as of the close of business on the balance sheet date.

Private Equity/Limited Partnership funds are valued at the quoted NAV, which is computed monthly and allocated based on ownership interest in partners’ capital.

Fixed income securities are valued using pricing models that consider various observable inputs such as benchmark yields, reported trades, broker quotes and issuer spreads to determine fair value.

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

The Plans may engage in repurchase transactions. Generally, in accordance with the terms of a repurchase agreement, the Plans take possession of Treasury Bills in exchange for cash and the counterparty is obligated to repurchase, and the Plan to resell, the same securities at an agreed-upon price and time. The repurchase agreements have a one-day maturity and a fair value equal to the Plan’s cash outlay at the time the agreement is executed.

The following table summarizes the changes in the fair value of the Level 3 assets for the fiscal years ended 2014 and 2013:

(In millions)
Years Ended September 30,	2014		2013
Balance, beginning of year	$	21.1	$	18.7
Actual return on plan assets:
Assets still held at year end		2.7		2.4
Balance, end of year	$	23.8	$	21.1

Benefit Contribution

During fiscal year 2014, Washington Gas did not contribute to its qualified pension but did contribute $1.8 million to its non-funded DB SERP plan. During fiscal year 2015, Washington Gas does not expect to make a contribution to its qualified pension plan and expects to make a payment of $4.1 million to its non-funded DB SERP. During fiscal year 2014, Washington Gas contributed $16.0 million to its health and life insurance benefit plans. Washington Gas expects to make a contribution of $16.6 million to its health and life insurance benefit plans during fiscal year 2015.

Expected Benefit Payments

Expected benefit payments, including benefits attributable to estimated future employee service, which are expected to be paid over the next ten years are as follows:

Expected Benefit Payments
(In millions)	Pension  Benefits		Health and  Life Benefits
2015	$	48.9	$    17.9
2016		50.3	18.8
2017		51.9	19.4
2018		53.0	20.1
2019		54.7	20.6
2020—2024		286.5	105.3

MEDICARE SUBSIDY RECEIPTS / EMPLOYER GROUP WAIVER PLAN

Prior to 2013 Washington Gas sponsored a post-65 retiree prescription drug plan that was at least actuarially equivalent to Medicare (Medicare Part D), and as a result was eligible to receive a federal subsidy under the Medicare Prescription Drug, Improvement and Modernization Act of 2003. Effective January 1, 2013 Washington Gas implemented an Employer Group Waiver Plan with a wraparound supplemental plan (“EGWP/wrap”). Accordingly, the Washington Gas retiree medical plan began receiving direct reimbursements and discounts from Medicare and the large pharmaceutical companies. During the year ended September 30, 2014, Washington Gas received $0.5 million in reimbursements related to the EGWP/wrap. Effective January 1, 2015, Washington Gas will cease to participate in the EGWP/wrap because participants age 65 and older will be transitioning into the new WGL Retiree HRA Plan, where such participants will receive an annual stipend that could be used to purchase health and prescription drug insurance.

REGULATORY MATTERS

A significant portion of the estimated pension and post-retirement medical and life insurance benefits apply to our regulated activities. Each regulatory commission having jurisdiction over Washington Gas requires it to fund amounts reflected in rates for post-retirement medical and life insurance benefits into irrevocable trusts.

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

District of Columbia Jurisdiction

The PSC of DC has approved a level of rates sufficient to recover annual costs associated with the qualified pension and other post-retirement benefits. Expenses of the SERP allocable to the District of Columbia are not recovered through rates. The PSC of DC granted the recovery of post-retirement medical and life insurance benefit costs determined in accordance with GAAP through a five-year phase-in plan that ended September 30, 1998. Washington Gas deferred the difference generated during the phase-in period as a regulatory asset. Effective October 1, 1998, the PSC of DC granted Washington Gas full recovery of costs determined under GAAP, plus a fifteen-year amortization of the regulatory asset established during the phase-in period that ended in fiscal year 2014.

Virginia Jurisdiction

On September 28, 1995, the SCC of VA issued a generic order that allowed Washington Gas to recover most costs determined under GAAP for post-retirement medical and life insurance benefits in rates over twenty years. The SCC of VA, however, set a forty-year recovery period of the transition obligation. As prescribed by GAAP, Washington Gas amortizes these costs over a twenty-year period. With the exception of the transition obligation, the SCC of VA has approved a level of rates sufficient to recover annual costs for all pension and other post-retirement medical and life insurance benefit costs determined under GAAP.

Maryland Jurisdiction

In Washington Gas’ most recent rate case, the PSC of MD approved 50% of the expenses of the SERP for recovery through rates. The PSC of MD has approved a level of rates sufficient to recover pension and other post-retirement benefit costs as determined under GAAP.

NOTE 11. STOCK-BASED COMPENSATION

STOCK-BASED COMPENSATION FOR KEY EMPLOYEES

We have stock-based awards outstanding in the form of stock options, performance shares and performance units. We have stock options outstanding under our shareholder-approved 1999 Incentive Compensation Plan, as amended and restated (1999 Plan). In March 2007, WGL adopted a shareholder-approved Omnibus Incentive Compensation Plan (Omnibus Plan) to replace, on a prospective basis, the 1999 Plan. Stock options, stock appreciation rights, restricted stock, deferred stock and stock as a bonus in lieu of other awards, dividend equivalents, other stock-based awards and cash awards may be granted under the Omnibus Plan. The Omnibus Plan allows WGL to issue up to 1,700,000 shares of common stock, subject to adjustment as provided by the plan, to persons including officers and key employees, designated by the Human Resources Committee of the Board of Directors. Refer to Note 6—Common Stock—WGL for amounts remaining to be issued under these plans.

During the fiscal year ended September 30, 2014, we granted performance shares and performance units under the Omnibus Plan. We have not issued stock options under either plan since October 2006. As of September 30, 2014, there are prior years’ stock option grants outstanding for which the exercise price is equal to the market value of our common stock on the date of the grant.

For both performance shares and performance units, the actual award that may be earned varies based on the total shareholder return of WGL relative to a selected peer group of companies. These performance awards generally vest over three years from the date of grant. Performance shares earned are paid in shares of common stock of WGL. Performance units are earned pursuant to terms of the grant, are paid in cash and are valued at $1.00 per performance unit. Outstanding stock options vest over three years from the date of the grant and expire ten years thereafter. Performance units, performance shares and stock option awards provide for accelerated vesting upon a change in control of WGL. Additionally, outstanding stock options provide for accelerated vesting upon retirement, death or disability of the recipient. We generally issue new shares of common stock to provide for redemption of performance shares and stock options; however, we may, from time to time, repurchase shares of our common stock on the open market in order to meet these requirements. Both performance shares and stock options are accounted for as equity awards, and performance units are accounted for as liability awards as they are settled in cash.

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

For the years ended September 30, 2014, 2013 and 2012, we recognized stock-based compensation expense of $3.4 million, $6.5 million and $3.6 million, net of related income tax benefits of $1.3 million, $2.6 million and $1.4 million, respectively.

As of September 30, 2014, total unrecognized compensation expense related to stock-based awards granted was $6.5 million. Performance shares and performance units comprised $4.0 million and $2.5 million of total unrecognized compensation expense, respectively. The total unrecognized compensation expense is expected to be recognized over a weighted average cost period of 1.7 years for performance shares and performance units.

Performance Shares

The following table summarizes information regarding performance share activity during the fiscal year ended September 30, 2014.

Performance Share Activity
	Year Ended September 30, 2014
	Number of     Shares(a)			Weighted Average Grant- Date Fair Value
Non-vested and outstanding, beginning of year		295,973			$              39.88
Granted		109,076			42.88
Vested		(84,849	)		41.14
Cancelled/forfeited		(18,822	)		40.47
Non-vested and outstanding, end of year		301,378			$              40.57

^(a)The number of common shares issued related to performance shares may range from zero to 200 percent of the number of shares shown in the table above based on our achievement of performance goals for total shareholder return relative to a selected peer group of companies.

The total fair value of the performance shares outstanding at September 30, 2014 for the shares expected to vest in the future was $11.6 million. The total intrinsic value of performance shares vested during the year ended September 30, 2014 was $2.2 million. No performance shares vested during the year ended September 30, 2013. The total intrinsic value of performance shares vested during the year ended September 30, 2012 was $3.3 million.

We measure compensation expense related to performance shares based on the fair value of these awards at their date of grant. Compensation expense for performance shares is recognized for awards that ultimately vest and is not adjusted based on the actual achievement of performance goals. We estimated the fair value of performance shares on the date of grant using a Monte Carlo simulation model and the following assumptions:

Fair Value Assumptions
Years Ended September 30,	2014			2013			2012
Expected stock-price volatility		19.10	%		19.40	%		27.80	%
Dividend yield		3.93	%		3.98	%		3.97	%
Weighted average grant-date fair value	$	42.88		$	39.73		$	38.99

Expected stock-price volatility is based on the daily historical volatility of our common shares for the past three fiscal years. The dividend yield represents our annualized dividend yield on the closing market price of our common stock at the date of the grant.

Performance Units

Our performance units are liability awards as they settle in cash; therefore, we measure and record compensation expense for these awards based on their fair value at the end of each period until their vesting date. Consequently, fluctuations in earnings may result that do not occur under the accounting requirements for both our stock options and performance shares.

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

The following table summarizes information regarding performance unit activity during the fiscal year ended September 30, 2014.

Performance Unit Activity
	Year Ended       September 30, 2014
	Number of Units
Non-vested and outstanding, beginning of year	11,582,556
Granted	4,658,648
Vested	(3,205,636)
Cancelled/forfeited	(766,647)
Non-vested and outstanding, end of year	12,268,921

The total fair value of performance units outstanding at September 30, 2014 for the units expected to vest in the future was $4.9 million. As of September 30, 2014, 2013 and 2012, we recorded a liability of $2.4 million, $4.9 million and $2.1 million, respectively, related to our performance units. This liability is recorded in “Deferred Credits—other”. During the fiscal year ended September 30, 2014, we paid $2.0 million in cash to settle performance unit awards. During fiscal year ended September 30, 2013, we did not make any cash payments to settle performance unit awards. During the fiscal year ended September 30, 2012, we paid $2.8 million in cash to settle performance unit awards.

We estimated the fair value of performance units using a Monte Carlo simulation model. The following table provides the year-end assumptions used to value our performance units:

Fair Value Assumptions
	September 30, 2014
	10/1/2013 Grant		10/1/2012 Grant
Expected stock-price volatility		18.1%		19.5%

Expected stock-price volatility is based on the daily historical volatility of our common shares for a period equal to the remaining term of the performance units.

Stock Options

The following table summarizes information regarding stock option activity during the fiscal year ended September 30, 2014.

Stock Option Activity
	Number of Options			Weighted Average Exercise Price		Weighted Average Remaining Contractual Term (In years)		Aggregate Intrinsic Value (In thousands)
Outstanding at September 30, 2013		26,372		$	31.34		4.01	$	235
Granted		-			-		-		-
Exercised		(21,054	)		31.34		-		232
Cancelled/forfeited		-			-		-		-
Outstanding at September 30, 2014		5,318		$	31.34		2.00	$	57
Exercisable at September 30, 2014		5,318		$	31.34		2.00	$	57

We received $0.7 million from the exercise of stock options during the year ended September 30, 2014. There were no stock options exercised during the year ended September 30, 2013 and no related tax benefits realized. We received $0.8 million from the exercise of stock options during the year ended 2012. The related tax benefits realized for the fiscal years ended September 30, 2014 and 2012 were $0.1 million and $0.1 million, respectively.

We measure compensation expense related to stock options based on the fair value of these awards at their date of grant. Compensation expense for stock options is recognized for awards that ultimately vest. We estimated the fair value of stock options on the date of the grant using the Black-Scholes option-pricing model.

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

Expected stock-price volatility is based on the daily historical volatility of our common shares over a period that approximates the expected term of the stock options. The dividend yield represents our annualized dividend yield on the closing market price of our common stock at the date of grant. The risk-free interest rate is based on the zero-coupon U.S. Treasury bond, with a term equal to the expected term of the stock options. The expected option term is based on our historical experience with respect to stock option exercises and expectations about future exercises.

STOCK GRANTS TO DIRECTORS

Non-employee directors receive a portion of their annual retainer fee in the form of common stock through the Directors’ Stock Compensation Plan. Up to 270,000 shares of common stock may be awarded under the plan. Shares granted to directors were approximately 17,000, 16,600 and 11,900 for the fiscal years ended September 30, 2014, 2013 and 2012, respectively. For those years, the weighted average fair value of the stock on the grant dates was $40.06, $40.46, and $44.30, respectively. Shares awarded to the participants; (i) vest immediately and cannot be forfeited; (ii) may be sold or transferred and (iii) have voting and dividend rights. For each of the years ended September 30, 2014 and 2013, WGL recognized stock-based compensation expense related to stock grants of $0.7 million, net of related income tax benefits of $0.3 million. For the year ended September 30, 2012, WGL recognized stock-based compensation expense related to stock grants of $0.5 million, net of related income tax benefits of $0.2 million.

NOTE 12. ENVIRONMENTAL MATTERS

We are subject to federal, state and local laws and regulations related to environmental matters. These laws and regulations may require expenditures over a long time frame to control environmental effects. Almost all of the environmental liabilities we have recorded are for costs expected to be incurred to remediate sites where we or a predecessor affiliate operated MGPs. Estimates of liabilities for environmental response costs are difficult to determine with precision because of the various factors that can affect their ultimate level. These factors include, but are not limited to, the following:

• the complexity of the site;

• changes in environmental laws and regulations at the federal, state and local levels;

• the number of regulatory agencies or other parties involved;

• new technology that renders previous technology obsolete or experience with existing technology that proves ineffective;

• the level of remediation required and

• variations between the estimated and actual period of time that must be dedicated to respond to an environmentally-contaminated site.

Washington Gas has identified up to ten sites where it or its predecessors may have operated MGPs. Washington Gas last used any such plant in 1984. In connection with these operations, we are aware that coal tar and certain other by-products of the gas manufacturing process are present at or near some former sites, and may be present at others. Based on the information available to us, we have concluded that none of the sites are likely to present an unacceptable risk to human health or the environment, and either the appropriate remediation is being undertaken, or Washington Gas believes no remediation is necessary.

At both September 30, 2014 and 2013, Washington Gas recorded a liability of $8.5 million, on an undiscounted basis related to future environmental response costs, which included the estimated costs for four MGP sites. These estimates principally include the minimum liabilities associated with a range of environmental response costs expected to be incurred at the sites identified. At September 30, 2014 and 2013, Washington Gas estimated the maximum liability associated with all of its sites to be approximately $19.3 million and $20.5 million, respectively. The estimates were determined by Washington Gas’ environmental experts, based on experience in remediating MGP sites and advice from legal counsel and environmental consultants. The variation between the recorded and estimated maximum liability primarily results from differences in the number of years that will be required to perform environmental response processes at each site and the extent of remediation that may be required.

Regulatory orders issued by the PSC of MD allow Washington Gas to recover the costs associated with the sites applicable to Maryland over the period ending in 2025. Rate orders issued by the PSC of DC allow Washington Gas a three-year recovery of prudently incurred environmental response costs, and allow Washington Gas to defer additional costs incurred between rate cases. Regulatory orders from the SCC of VA have generally allowed the recovery of prudent environmental remediation costs to the extent they were included in the underlying financial data supporting an application for rate change.

At both September 30, 2014 and 2013, Washington Gas reported a regulatory asset of $0.6 million, for the portion of environmental response costs that are expected to be recoverable in future rates.

We do not expect that the ultimate impact of these matters will have a material effect on our financial position, cash flows, capital expenditures, earnings or competitive position.

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

NOTE 13. COMMITMENTS AND CONTINGENCIES

OPERATING LEASES

Minimum future rental payments under operating leases over the next five years and thereafter are as follows:

Minimum Payments Under Operating Leases
(In millions)
2015	$	7.8
2016		6.3
2017		4.9
2018		4.3
2019		1.0
Thereafter		10.5
Total	$	34.8

Rent expense totaled $5.5 million, $5.6 million and $5.2 million in fiscal years ended September 30, 2014, 2013 and 2012, respectively.

REGULATED UTILITY OPERATIONS

Natural Gas Contracts—Minimum Commitments

At September 30, 2014, Washington Gas had service agreements with four pipeline companies that provide direct service for firm transportation and/or storage services. These agreements, which have expiration dates ranging from fiscal years 2015 to 2032, require Washington Gas to pay fixed charges each month. Additionally, Washington Gas had agreements for other pipeline and peaking services with expiration dates ranging from 2015 to 2032. These agreements were entered into based on current estimates of growth of the Washington Gas system, together with other factors, such as current expectations of the timing and extent of unbundling initiatives in the Washington Gas service territory.

The following table summarizes the minimum contractual payments that Washington Gas will make under its pipeline transportation, storage and peaking contracts, as well as minimum contractual payments to purchase natural gas at prices based on market conditions during the next five fiscal years and thereafter. The gas purchase contracts noted below represent commitments to purchase natural gas based on market conditions at the time the natural gas is purchased.

Washington Gas Contract Minimums
(In millions)	Pipeline Contracts(a)		Gas Purchase Commitments(b)
2015		$        195.4		$                        280.0
2016		224.7		288.9
2017		217.7		336.7
2018		211.1		323.2
2019		201.3		303.5
Thereafter		1,205.3		2,990.2
Total		$     2,255.5		$                       4,522.5
(a) Represents minimum payments for natural gas transportation, storage and peaking contracts that have expiration dates through fiscal year 2032. (b) The contracts referenced above are estimated based on market prices at September 30, 2014.

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

When a customer selects a third party marketer to provide supply, Washington Gas generally assigns pipeline and storage capacity to unregulated third party marketers to deliver gas to Washington Gas’ city gate. In order to provide the gas commodity to customers who do not select an unregulated third party marketer, Washington Gas has a commodity acquisition plan to acquire the natural gas supply to serve the customers.

Currently, Washington Gas recovers its cost of gas to serve its customers through the purchased gas cost recovery mechanisms included in its retail rate schedules in each of its jurisdictions. However, the timing and extent of Washington Gas’ initiatives or regulatory requirements to separate the purchase and sale of natural gas from the delivery of gas could cause its gas supply commitments to exceed its continued sales obligations.

Washington Gas has rate provisions in each of its jurisdictions that would allow it to continue to recover these commitments in rates. Washington Gas also actively manages its supply portfolio to ensure its sales and supply obligations remain balanced. This reduces the likelihood that the contracted supply commitments would exceed supply obligations. However, to the extent Washington Gas were to determine that changes in regulation would cause it to discontinue recovery of these costs in rates, Washington Gas would be required to charge these costs to expense without any corresponding revenue recovery. If this occurred, depending upon the timing of the occurrence, the related impact on our financial position, results of operations and cash flows would likely be significant.

Regulatory Contingencies

Certain legal and administrative proceedings incidental to our business, including regulatory contingencies, involve WGL and/or its subsidiaries. In our opinion, we have recorded an adequate provision for probable losses or refunds to customers for regulatory contingencies related to these proceedings.

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

NON-UTILITY OPERATIONS

WGEServices enters into contracts to purchase natural gas and electricity designed to match the duration of its sales commitments, and to effectively lock in a margin on estimated sales over the terms of existing sales contracts. As listed below, natural gas purchase commitments are based on existing fixed-price purchase contracts using city gate equivalent deliveries, the majority of which are for fixed volumes. Also listed below are electricity purchase commitments that are based on existing fixed-price purchase commitments, all of which are for fixed volumes.

WGL Midstream enters into contracts to acquire, invest in, manage and optimize natural gas storage and transportation assets. Gas purchase commitments increased during fiscal year 2014 due to purchase commitments related to investment pipeline infrastructure.

The following table summarizes the minimum commitments and contractual obligations of WGEServices and WGL Midstream for the next five fiscal years and thereafter:

Contract Minimums
	WGEServices						WGL Midstream
(In millions)	Gas Purchase     Commitments(a)		Pipeline     Contracts(b)		Electric Purchase     Commitments(c)		Gas Purchase     Commitments(d)		Pipeline     Contracts(e)		Total
2015	$	167.5	$	2.4	$	359.4	$	29.2	$	15.3	$	573.8
2016		49.2		0.6		171.7		24.4		19.4		265.3
2017		13.8		0.6		65.0		80.2		17.7		177.3
2018		0.6		0.6		3.6		906.0		26.5		937.3
2019		-		0.6		-		933.4		24.6		958.6
Thereafter		-		1.3		-		13,479.8		260.9		13,742.0
Total	$	231.1	$	6.1	$	599.7	$	15,453.0	$	364.4	$	16,654.3

^(a)Represents fixed price commitments with city gate equivalent deliveries.

^(b)Represents minimum payments for natural gas transportation, storage and peaking contracts that have expiration dates through fiscal year 2025.

^(c)Represents electric purchase commitments that are based on existing fixed price and fixed volume contracts. Includes $15.3 million of commitments related to renewable energy credits.

^(d) Includes short-term commitments to purchase fixed volumes of natural gas, as well as long-term gas purchase commitments that contain fixed volume purchase requirements. Cost estimates are based on forward market prices for purchases under these purchase commitments.

^(e) Represents minimum payments for natural gas transportation, storage and peaking contracts that have expiration dates through fiscal year 2044.

Construction Project Financing

To fund certain of its construction projects, Washington Gas enters into financing arrangements with third party lenders. As part of these financing arrangements, Washington Gas’ customers agree to make principal and interest payments over a period of time, typically beginning after the projects are completed. Washington Gas assigns these customer payment streams to the lender. As the lender funds the construction project, Washington Gas establishes a receivable representing its customers’ obligations to remit principal and interest and a long-term payable to the lender. When these projects are formally “accepted” by the customer as completed, Washington Gas transfers the ownership of the receivable to the lender and removes both the receivable and the long-term financing from its financial statements. As of September 30, 2014 and 2013, work on these construction projects that was not completed or accepted by customers was valued at $8.3 million and $6.7 million, respectively, that are recorded on the balance sheet as a receivable in “Deferred Charges and Other Assets—Other” with the corresponding long-term obligation to the lender in “Long-term debt.” At any time before these contracts are accepted by the customer, should there be a contract default, such as, among other things, a delay in completing the project, the lender may call on Washington Gas to fund the unpaid principal in exchange for which Washington Gas would receive the right to the stream of payments from the customer. Construction projects are financed primarily for government agencies, which Washington Gas considers to have minimal credit risk. Based on this assessment and previous collection experience, Washington Gas did not record a corresponding reserve for bad debts related to these receivables at September 30, 2014 or September 30, 2013.

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

Financial Guarantees

WGL has guaranteed payments primarily for certain purchases of natural gas and electricity on behalf of WGEServices and for certain purchase commitments on behalf of WGL Midstream. At September 30, 2014, these guarantees totaled $227.3 million and $276.5 million for WGEServices and WGL Midstream, respectively. At September 30, 2014, the guarantees relating to WGESystems totaled $6.0 million. The amount of such guarantees is periodically adjusted to reflect changes in the level of financial exposure related to these purchase commitments. For all of our financial guarantees, WGL may cancel any or all future obligations upon written notice to the counterparty, but WGL would continue to be responsible for the obligations created under the guarantees prior to the effective date of the cancellation. WGL also has guaranteed payments for certain of our other external partners. At September 30, 2014, these guarantees totaled $18.7 million. At September 30, 2014, WGL’s guarantees for all its subsidiaries and external partners totaled $528.5 million. The fair value of these guarantees was insignificant at September 30, 2014.

Legal Matters

WGL has been cooperating with a Department of Justice (“the Department”) investigation of some of the federal contracting activities of one of its non-utility subsidiaries, WGESystems. The Department’s investigation concerned certain American Recovery and Reinvestment Act projects bid out by the General Services Administration in 2010, in which WGESystems participated as a subcontractor to an 8(a) prime contractor under the Small Business Administration’s 8(a) Business Development Program. As discussed in more detail in Note 20—Subsequent Events, on November 18, 2014, WGESystems entered into a deferred prosecution agreement with the Department, which will resolve the investigation.

We accrued approximately $2.6 million, representing the fine and monetary penalty to be paid to the Department in connection with this matter, in the fourth quarter of 2014.

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

NOTE 14. DERIVATIVE AND WEATHER-RELATED INSTRUMENTS

DERIVATIVE INSTRUMENTS

Regulated Utility Operations

Washington Gas enters into contracts related to the sale and purchase of natural gas that qualify as derivative instruments and are accounted for under ASC Topic 815. These derivative instruments are recorded at fair value on our balance sheet and Washington Gas does not designate any derivatives as hedges under ASC Topic 815. Washington Gas’ derivative instruments relate to: (i) Washington Gas’ asset optimization program; (ii) managing price risk associated with the purchase of gas to serve utility customers and (iii) managing interest rate risk.

Asset Optimization. Washington Gas optimizes the value of its long-term natural gas transportation and storage capacity resources during periods when these resources are not being used to physically serve utility customers. Specifically, Washington Gas utilizes its transportation capacity assets to benefit from favorable natural gas prices between different geographic locations and its storage capacity assets to benefit from favorable natural gas prices between different time periods. As part of this asset optimization program, Washington Gas enters into physical and financial derivative transactions in the form of forward, futures and option contracts with the primary objective of locking in operating margins that Washington Gas will ultimately realize. The derivatives used under this program are subject to mark-to-market accounting treatment while the capacity and transportation resources are not.

Regulatory sharing mechanisms allow the profit from these transactions to be shared between Washington Gas’ shareholders and customers; therefore, any changes in fair value are recorded through earnings, or as regulatory assets or liabilities to the extent that gains and losses associated with these derivative instruments will be included in the rates charged to customers when they are realized. Valuation changes for the portion of net profits to be retained for shareholders may cause significant period-to-period volatility in earnings from unrealized gains and losses. This volatility does not change the locked-in operating margins that Washington Gas expects to ultimately realize from these transactions through the use of its storage and transportation capacity resources.

All physically and financially settled contracts under our asset optimization program are reported on a net basis in the statements of income in “Utility cost of gas.” Total net margins recorded to “Utility cost of gas” after sharing and management fees associated with all asset optimization transactions for the fiscal year ended September 30, 2014 was a net loss of $35.4 million including an unrealized loss of $66.2 million. During the fiscal year ended September 30, 2013 we recorded a net loss of $33.2 million including an unrealized loss of $45.4 million. During the fiscal year ended September 30, 2012 we recorded a net gain of $28.3 million including an unrealized gain of $15.9 million.

Managing Price Risk. To manage price risk associated with acquiring natural gas supply for utility customers, Washington Gas enters into forward contracts, option contracts, financial contracts and other contracts, as authorized by its regulators. These instruments are accounted for as derivative instruments. Any gains and losses associated with these derivatives are recorded as regulatory liabilities or assets, respectively, to reflect the rate treatment for these economic hedging activities.

Managing Interest-Rate Risk. Washington Gas utilizes derivative instruments that are designed to minimize the risk of interest-rate volatility associated with planned issuances of debt securities. Any gains and losses associated with these types of derivatives are recorded as regulatory liabilities or assets, respectively, and amortized in accordance with regulatory requirements, typically over the life of the newly issued debt.

Non-Utility Operations

Managing Price Risk. WGEServices enters into certain derivative contracts as part of managing the price risk associated with the sale and purchase of natural gas and electricity. WGL Midstream enters into derivative contracts for the purpose of optimizing its storage and transportation capacity as well as managing the transportation and storage assets on behalf of third parties. As the storage and transportation capacities utilized by WGL Midstream are not considered to be derivative instruments, they are not recorded at fair value on our consolidated balance sheets. Washington Gas Resources has warrants to purchase stock from certain of its solar investments that are accounted for as derivative instruments. Derivative instruments are recorded at fair value on our consolidated balance sheets. WGEServices, WGL Midstream and Washington Gas Resources do not designate these derivatives as hedges under ASC Topic 815; therefore, changes in the fair value of these derivative instruments are reflected in the earnings of our non-utility operations and may cause significant period-to-period volatility in earnings.

Managing Interest-Rate Risk. WGL utilizes derivative instruments that are designed to minimize the risk of interest-rate volatility associated with future debt issuances. During September 2014, WGL entered into interest rate swaps associated with an expected $150 million debt issuance. WGL elected cash flow hedge accounting for its interest rate derivative instruments. Therefore, the effective portion of the gains and losses on the hedge are recorded within other comprehensive income and are expected to be amortized over the life of the debt (through 2044). The amount of ineffectiveness recorded to earnings for the period from the cash flow hedge was $0.2 million.

Consolidated Operations

Reflected in the tables below is information for WGL as well as Washington Gas. The information for WGL includes derivative instruments for both utility and non-utility operations.

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Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

At September 30, 2014 and 2013, respectively, the absolute notional amounts of our derivatives are as follows:

Absolute Notional Amounts
of Open Positions on Derivative Instruments
September 30, 2014	Notional Amounts
Derivative transactions	WGL Holdings		Washington Gas
Natural Gas (In millions of therms)
Asset Optimization		20,593.3		13,740.9
Retail sales		44.7		-
Other risk-management activities		1,641.3		1,398.2
Electricity (In millions of kWhs)
Retail sales		3,831.4		-
Other risk-management activities		16,734.1		-
Warrants (In millions of shares)		4.6		-
Interest Rate Swaps (In millions of dollars)		150.0		-

Absolute Notional Amounts
of Open Positions on Derivative Instruments
September 30, 2013	Notional Amounts
Derivative transactions	WGL Holdings		Washington Gas
Natural Gas (In millions of therms)
Asset Optimization		13,289.6		11,115.8
Retail sales		98.9		-
Other risk-management activities		1,803.6		1,455.7
Electricity (In millions of kWhs)
Retail sales		4,790.2		-
Other risk-management activities		17,647.9		-
Warrants (In millions of shares)		4.6		-
Interest Rate Swaps (In millions of dollars)(a)		75.0		75.0

^(a)  The fair value of our interest rate swaps was minimal at September 30, 2013.

As of September 30, 2014, the increase in volume of asset optimization related derivatives is primarily the result of new long-term gas purchase contracts for WGL Midstream.

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Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

The following tables present the balance sheet classification for all derivative instruments as of September 30, 2014 and 2013.

WGL Holdings, Inc.
Balance Sheet Classification of Derivative Instruments
(In millions)	Derivative Instruments Not Designated as Hedging Instruments				Derivative Instruments Designated as Hedging Instruments
As of September 30, 2014	Gross  Derivative  Assets		Gross  Derivative  Liabilities		Gross  Derivative  Assets		Gross  Derivative  Liabilities			Netting of  Collateral			Total(a)
Current Assets—Derivatives	$	20.8	$	(2.5)	$	-	$	-		$	-		$	18.3
Deferred Charges and Other Assets—Derivatives		18.7		-		-		-			-			18.7
Current Liabilities—Derivatives		15.4		(70.3)		-		(1.7	)		8.0			(48.6)
Deferred Credits—Derivatives		17.7		(316.4)		-		-			4.0			(294.7)
Total	$	72.6	$	(389.2)	$	-	$	(1.7	)	$	12.0		$	(306.3)
As of September 30, 2013
Current Assets—Derivatives	$	57.3	$	(19.3)	$	-	$	-		$	(2.7	)	$	35.3
Deferred Charges and Other Assets—Derivatives		57.4		(31.1)		-		-			-			26.3
Accounts Payable and Other Accrued Liabilities		1.5		-		-		-			-			1.5
Current Liabilities—Derivatives		4.1		(53.4)		-		-			0.9			(48.4)
Deferred Credits—Derivatives		-		(144.0)		-		-			2.7			(141.3)
Total	$	120.3	$	(247.8)	$	-	$	-		$	0.9		$	(126.6)
Washington Gas Light Company
Balance Sheet Classification of Derivative Instruments(b)
(In millions)
As of September 30, 2014					Gross    Derivative    Assets		Gross    Derivative      Liabilities			Netting of      Collateral			Total(a)
Current Assets—Derivatives					$	3.9	$	-		$	-		$	3.9
Deferred Charges and Other Assets—Derivatives						9.5		-			-			9.5
Current Liabilities—Derivatives						8.6		(43.2)			0.7			(33.9)
Deferred Credits—Derivatives						4.2		(265.2)			0.2			(260.8)
Total					$	26.2	$	(308.4)		$	0.9		$	(281.3)
As of September 30, 2013
Current Assets—Derivatives					$	19.3	$	(12.3)		$	(2.7	)	$	4.3
Deferred Charges and Other Assets—Derivatives						47.2		(31.1)			-			16.1
Current Liabilities—Derivatives						1.5		(26.2)			-			(24.7)
Deferred Credits—Derivatives						-		(106.1)			-			(106.1)
Total					$	68.0	$	(175.7)		$	(2.7	)	$	(110.4)

(a) WGL has elected to offset the fair value of recognized derivative instruments against the right to reclaim or the obligation to return collateral for derivative instruments executed under the same master netting arrangement in accordance with ASC 815. All recognized derivative contracts and associated financial collateral subject to a master netting arrangement or similar that is eligible for offset under ASC 815 have been presented net in the balance sheet.

(b) Washington Gas did not have any derivative instruments outstanding that were designated as hedging instruments at September 30, 2014, or 2013.

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Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

The following tables present all gains and losses associated with derivative instruments for the years ended September 30, 2014, 2013 and 2012.

WGL Holdings, Inc. Gains and Losses on Derivative Instruments
(In millions)
Fiscal Year Ended September 30,		2014		2013		2012
Recorded to income
Operating revenues—non-utility	$	(47.9)	$	(9.9)	$	19.2
Utility cost of gas		(87.3)		(45.9)		22.3
Non-utility cost of energy-related sales		36.2		(2.4)		(34.2)
Other income-net		(1.1)		0.2		0.9
Interest expense		(0.2)		-		-
Recorded to regulatory assets
Gas costs		(143.3)		(115.1)		42.2
Other		0.2		-		-
Recorded to other comprehensive income(a)		(1.5)		-		-
Total	$	(244.9)	$	(173.1)	$	50.4
(a)This pre-tax unrealized gain represents the effective portion of our cash flow hedge. Upon settlement of the hedge, the realized gain or loss, to the extent effective, will be amortized as an adjustment to the interest expense. We expect this amortization to be minimal for fiscal 2015.
Washington Gas Gains and Losses on Derivative Instruments
(In millions)
Fiscal Year Ended September 30,	2014		2013		2012
Recorded to income
Utility cost of gas	$	(87.3)	$	(45.9)	$	22.3
Recorded to regulatory assets
Gas costs		(143.3)		(115.1)		42.2
Other		0.2		-		-
Total	$	(230.4)	$	(161.0)	$	64.5

Collateral

WGL utilizes standardized master netting agreements, which facilitate the netting of cash flows into a single net exposure for a given counterparty. As part of these master netting agreements, cash, letters of credit and parental guarantees may be required to be posted or obtained from counterparties in order to mitigate credit risk related to both derivatives and non-derivative positions. Under WGL’s offsetting policy, collateral balances are offset against the related counterparties’ derivative positions to the extent the application would not result in the over-collateralization of those derivative positions on the balance sheet. At September 30, 2014, Washington Gas, WGEServices and WGL Midstream posted $8.2 million, $5.7 million and $11.4 million, respectively, of collateral deposits with counterparties that were not offset against open and settled derivative contracts. At September 30, 2013, Washington Gas, WGEServices and WGL Midstream posted $3.0 million, $12.1 million and $8.1 million, respectively, of collateral deposits with counterparties that were not offset against open and settled derivative contracts. In addition, at September 30, 2014 and 2013, Washington Gas held $2.5 million and $4.6 million of cash collateral, respectively, representing an obligation to counterparties that was not offset against open and settled derivative contracts. Any collateral posted that is not offset against open and settled derivative contracts is included in “Other prepayments” in the accompanying balance sheet. Collateral received and not offset against open and settled derivative contracts is included in “Customer deposits and advance payments” in the accompanying balance sheet.

Certain derivative instruments of Washington Gas, WGEServices and WGL Midstream contain contract provisions that require collateral to be posted if the credit rating of Washington Gas or WGL falls below certain levels or if counterparty exposure to WGEServices or WGL Midstream exceeds a certain level. Due to counterparty exposure levels, at September 30, 2014, WGEServices posted $5.3 million of collateral related to its derivative liabilities that contained credit-related contingent features. At September 30, 2013, WGEServices posted $3.6 million of collateral related to these aforementioned derivative liabilities. Washington Gas and WGL Midstream were not required to post any collateral related to its derivative liabilities that contained credit-related contingent features at September 30, 2014 and 2013. The following table shows the aggregate fair value of all derivative instruments with credit-related contingent features that are in a liability position, as well as the maximum amount of collateral that would be required if the most intrusive credit-risk-related contingent features underlying these agreements were triggered on September 30, 2014 and 2013, respectively.

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Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

Potential Collateral Requirements for Derivative Liabilities
with Credit-risk-Contingent Features
(In millions)	WGL Holdings, Inc.		Washington Gas
September 30, 2014
Derivative liabilities with credit-risk-contingent features	$	28.8	$	20.6
Maximum potential collateral requirements		16.5		16.1
September 30, 2013
Derivative liabilities with credit-risk-contingent features	$	77.0	$	44.7
Maximum potential collateral requirements		33.6		1.7

Washington Gas, WGEServices and WGL Midstream do not enter into derivative contracts for speculative purposes.

Concentration of Credit Risk

We are exposed to credit risk from derivative instruments with wholesale counterparties which is represented by the fair value of these instruments at the reporting date. We actively monitor and work to minimize counterparty concentration risk through various practices. At September 30, 2014, three counterparties each represented over 10% of Washington Gas’ credit exposure to wholesale derivative counterparties for a total credit risk of $16.7 million; two counterparties represented over 10% of WGEServices’ credit exposure to wholesale derivative counterparties for a total credit risk of $4.1 million; and three counterparties each represented over 10% of WGL Midstream’s credit exposure to wholesale counterparties for a total credit risk of $13.6 million.

WEATHER-RELATED INSTRUMENTS

Washington Gas did not use any weather-related instruments during the year ended September 30, 2014. During the fiscal years ended September 30, 2013 and 2012, Washington Gas used HDD weather–related instruments to manage its financial exposure to variations from normal weather in the District of Columbia. Under these contracts, Washington Gas purchased protection against net revenue shortfalls due to warmer-than-normal weather and sold to its counterparty the right to receive the benefit when weather is colder than normal. Washington Gas elected to value all weather-related instruments at fair value.

Gains and losses associated with Washington Gas’ weather-related instruments are recorded to “Operation and maintenance” expense. During the years ended September 30, 2013 and 2012, Washington Gas recorded a pre-tax net gain of $0.8 million and $7.9 million respectively, related to weather derivatives.

WGEServices utilizes weather-related instruments for managing the financial effects of weather risks. These instruments cover a portion of WGEServices’ estimated revenue or energy-related cost exposure to variations in heating or cooling degree days. These contracts provide for payment to WGEServices of a fixed-dollar amount for every degree day over or under specific levels during the calculation period depending upon the type of contract executed. During the years ended September 30, 2014, 2013 and 2012, WGEServices recorded a pre-tax gain of $3.4 million, a pre-tax loss of $0.8 million and a pre-tax gain of $11.8 million, respectively, related to these instruments.

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Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

NOTE 15. FAIR VALUE MEASUREMENTS

Recurring Basis

We measure the fair value of our financial assets and liabilities using a combination of the income and market approach in accordance with ASC Topic 820. These financial assets and liabilities primarily consist of (i) derivatives recorded on our balance sheet under ASC Topic 815, (ii) weather-related instruments and (iii) short-term investments, commercial paper and long-term debt outstanding required to be disclosed at fair value. Under ASC Topic 820, fair value is defined as the exit price, representing the amount that would be received in the sale of an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. To value our financial instruments, we use market data or assumptions that market participants would use, including assumptions about credit risk (both our own credit risk and the counterparty’s credit risk) and the risks inherent in the inputs to valuation.

We enter into derivative contracts in the futures and over-the-counter (OTC) wholesale and retail markets. These markets are the principal markets for the respective wholesale and retail contracts. Our relevant market participants are our existing counterparties and others who have participated in energy transactions at our delivery points. These participants have access to the same market data as WGL. We value our derivative contracts based on an “in-exchange” premise, and valuations are generally based on pricing service data or indicative broker quotes depending on the market location. We measure the net credit exposure at the counterparty level where the right to set-off exists. The net exposure is determined using the mark-to-market exposure adjusted for collateral, letters of credit and parent guarantees. We use published default rates from Standard & Poor’s Ratings Services and Moody’s Investors Service as inputs for determining credit adjustments.

ASC Topic 820 establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority to unobservable inputs. The three levels of the fair value hierarchy under ASC Topic 820 are described below:

Level 1.  Level 1 of the fair value hierarchy consists of assets or liabilities that are valued using observable inputs based upon unadjusted quoted prices in active markets for identical assets or liabilities at the reporting date. Level 1 assets and liabilities primarily include exchange traded derivatives and securities.

Level 2.  Level 2 of the fair value hierarchy consists of assets or liabilities that are valued using directly or indirectly observable inputs either corroborated with market data or based on exchange traded market data. Level 2 includes fair values based on industry-standard valuation techniques that consider various assumptions: (i) quoted forward prices, including the use of mid-market pricing within a bid/ask spread; (ii) discount rates; (iii) implied volatility and (iv) other economic factors. Substantially all of these assumptions are observable throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the relevant market. At September 30, 2014 and 2013, Level 2 financial assets and liabilities included energy-related derivatives such as financial contracts, options and physical forward contracts for deliveries at active market locations.

Level 3.  Level 3 of the fair value hierarchy consists of assets or liabilities that are valued using significant unobservable inputs at the reporting date. These unobservable assumptions reflect our assumptions about estimates that market participants would use in pricing the asset or liability, including natural gas basis prices, annualized volatilities of natural gas prices, and electricity congestion prices. A significant change to any one of these inputs in isolation could result in a significant upward or downward fluctuation in the fair value measurement. These inputs may be used with industry standard valuation methodologies that result in our best estimate of fair value for the assets or liabilities at the reporting date.

Our Risk Analysis and Mitigation (RA&M) Group determines the valuation policies and procedures. The RA&M Group reports to WGL’s Chief Financial Officer. In accordance with WGL’s valuation policy, we may utilize a variety of valuation methodologies to fair value Level 3 derivative contracts including internally developed valuation inputs and pricing models. The prices used in our valuations are corroborated using multiple pricing sources, and we periodically conduct assessments to determine whether each valuation model is appropriate for its intended purpose. The RA&M Group also evaluates changes in fair value measurements on a daily basis.

At September 30, 2014 and 2013, Level 3 derivative assets and liabilities included: (i) physical contracts valued at illiquid market locations with no observable market data; (ii) long-dated positions where observable pricing is not available over the life of the contract; (iii) contracts valued using historical spot price volatility assumptions; (iv) valuations using indicative broker quotes for inactive market locations and (v) non-publicly traded stock warrants.

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Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

The following tables set forth financial instruments recorded at fair value as of September 30, 2014 and 2013, respectively. A financial instrument’s classification within the fair value hierarchy is based on the lowest level of any input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy.

WGL Holdings, Inc.
Fair Value Measurements Under the Fair Value Hierarchy
(In millions)	Level 1		Level 2		Level 3		Total
At September 30, 2014
Assets
Natural gas related derivatives	$	-	$	22.7	$	33.7	$	56.4
Electricity related derivatives		-		0.3		15.9		16.2
Total Assets	$	-	$	23.0	$	49.6	$	72.6
Liabilities
Natural gas related derivatives	$	-	$	(39.8)	$	(328.4)	$	(368.2)
Electricity related derivatives		-		(0.1)		(20.9)		(21.0)
Interest rate derivatives		-		(1.7)		-		(1.7)
Total Liabilities	$	-	$	(41.6)	$	(349.3)	$	(390.9)

At September 30, 2013
Assets
Natural gas related derivatives	$	-	$	72.3	$	21.5	$	93.8
Electricity related derivatives		-		-		25.4		25.4
Warrants		-		-		1.1		1.1
Total Assets	$	-	$	72.3	$	48.0	$	120.3
Liabilities
Natural gas related derivatives	$	-	$	(41.1)	$	(176.7)	$	(217.8)
Electricity related derivatives		-		(7.0)		(23.0)		(30.0)
Total Liabilities	$	-	$	(48.1)	$	(199.7)	$	(247.8)

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Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

Washington Gas Light Company
Fair Value Measurements Under the Fair Value Hierarchy
(In millions)	Level 1		Level 2		Level 3		Total
At September 30, 2014
Assets
Natural gas related derivatives	$	- $		13.5 $		12.7 $		26.2
Total Assets	$	- $		13.5 $		12.7 $		26.2
Liabilities
Natural gas related derivatives	$	- $		(25.1)$		(283.3)$		(308.4)
Total Liabilities	$	- $		(25.1)$		(283.3)$		(308.4)
At September 30, 2013
Assets
Natural gas related derivatives	$	- $		51.0 $		17.0 $		68.0
Total Assets	$	- $		51.0 $		17.0 $		68.0
Liabilities
Natural gas related derivatives	$	- $		(25.1)$		(150.6)$		(175.7)
Total Liabilities	$	- $		(25.1)$		(150.6)$		(175.7)

The following table includes quantitative information about the significant unobservable inputs used in the fair value measurement of our Level 3 financial instruments and the respective fair values of the net derivative asset and liability positions, by contract type, as of September 30, 2014 and 2013.

Quantitative Information about Level 3 Fair Value Measurements
(In millions)	Net Fair Value  September 30, 2014	Valuation Techniques	Unobservable Inputs	Range
WGL Holdings, Inc.	(In millions)
		Discounted Cash Flow	Natural Gas Basis Price (per dekatherm)		($2.101) -	$6.154
Natural gas related derivatives	($294.7)	Option Model	Natural Gas Basis Price (per dekatherm)		($1.675) -	$6.154
			Annualized Volatility of Spot Market Natural Gas		30.9% -	589.6%
Electricity related derivatives	($5.0)	Discounted Cash Flow	Electricity Congestion Price (per megawatt hour)		($2.85) -	$90.95
Washington Gas Light Company
Natural gas related derivatives	($270.6)	Discounted Cash Flow	Natural Gas Basis Price (per dekatherm)		($2.101) -	$6.154

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Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

Quantitative Information about Level 3 Fair Value Measurements
(In millions)	Net Fair Value  September 30, 2013	Valuation Techniques	Unobservable Inputs	Range
WGL Holdings, Inc.	(In millions)
Natural gas related derivatives	($155.2)	Discounted Cash Flow	Natural Gas Basis Price (per dekatherm)	($1.780) -	$2.205
		Option Model	Natural Gas Basis Price (per dekatherm)	($0.181) -	$0.628
			Annualized Volatility of Spot Market Natural Gas	34.6%  -	276.6%
Electricity related derivatives	$2.4	Discounted Cash Flow	Electricity Congestion Price (per megawatt hour)	($1.995) -	$64.150
Washington Gas Light Company
Natural gas related derivatives	($133.6)	Discounted Cash Flow	Natural Gas Basis Price (per dekatherm)	($1.780) -	$2.205
		Option Model	Natural Gas Basis Price (per dekatherm)	$0.024  -	$0.628
			Annualized Volatility of Spot Market Natural Gas	46.8%  -	276.6%

The following tables are a summary of the changes in the fair value of our derivative instruments that are measured at net fair value on a recurring basis in accordance with ASC Topic 820 using significant Level 3 inputs during the years ended September 30, 2014 and 2013, respectively.

WGL Holdings, Inc. Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs
(In millions)	Natural Gas Related Derivatives			Electricity Related  Derivatives			Weather Related  Instruments		Warrants			Total
Fiscal Year Ended September 30, 2014
Balance at October 1, 2013	$	(155.2	)	$	2.4		$	-	$	1.1		$	(151.7)
Realized and unrealized gains (losses)
Recorded to income		(72.6	)		(5.7	)		-		(1.1	)		(79.4)
Recorded to regulatory assets - gas costs		(113.6	)		-			-		-			(113.6)
Transfers out of Level 3		1.7			-			-		-			1.7
Purchases		-			5.2			-		-			5.2
Settlements		45.0			(6.9	)		-		-			38.1
Balance at September 30, 2014	$	(294.7	)	$	(5.0	)	$	-	$	-		$	(299.7)

125

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

WGL Holdings, Inc. Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs
(In millions)	Natural Gas  Related Derivatives			Electricity Related  Derivatives			Weather Related  Instruments			Warrants		Total
Fiscal Year Ended September 30, 2013
Balance at October 1, 2012	$	39.6		$	2.8		$	(0.5	)	$	0.9	$	42.8
Realized and unrealized gains (losses)
Recorded to income		(72.4	)		(23.8	)		1.2			0.2		(94.8)
Recorded to regulatory assets - gas costs		(115.3	)		-			-			-		(115.3)
Transfers out of Level 3		(17.4	)		-			(0.7	)		-		(18.1)
Purchases		-			5.7			-			-		5.7
Settlements		10.3			17.7			-			-		28.0
Balance at September 30, 2013	$	(155.2	)	$	2.4		$	-		$	1.1	$	(151.7)

Washington Gas Light Company Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs
(In millions)	Natural Gas   Related Derivatives			Electricity Related   Derivatives		Weather Related   Instruments			Warrants		Total
Fiscal Year Ended September 30, 2014
Balance at October 1, 2013	$	(133.6	)	$	-	$	-		$	-	$	(133.6)
Realized and unrealized gains (losses)
Recorded to income		(69.4	)		-		-			-		(69.4)
Recorded to regulatory assets - gas costs		(113.6	)		-		-			-		(113.6)
Transfers out of Level 3		1.7			-		-			-		1.7
Settlements		44.3			-		-			-		44.3
Balance at September 30, 2014	$	(270.6	)	$	-	$	-		$	-	$	(270.6)
Washington Gas Light Company Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs
(In millions)	Natural Gas   Related Derivatives			Electricity Related   Derivatives		Weather Related   Instruments			Warrants		Total
Fiscal Year Ended September 30, 2013
Balance at October 1, 2012	$	35.6		$	-	$	(0.5	)	$	-	$	35.1
Realized and unrealized gains (losses)
Recorded to income		(45.9	)		-		1.2			-		(44.7)
Recorded to regulatory assets - gas costs		(115.3	)		-		-			-		(115.3)
Transfers out of Level 3		(17.4	)		-		(0.7	)		-		(18.1)
Settlements		9.4			-		-			-		9.4
Balance at September 30, 2013	$	(133.6	)	$	-	$	-		$	-	$	(133.6)

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

Transfers between different levels of the fair value hierarchy may occur based on the level of observable inputs used to value the instruments from period to period. It is our policy to show both transfers into and out of the different levels of the fair value hierarchy at the fair value as of the beginning of the reporting period. For WGL and Washington Gas net derivative assets transferred out of Level 3 during the fiscal year ended September 30, 2014 reflected an increase in the observable market inputs used to value those instruments.

The table below sets forth the line items on the statements of income to which amounts are recorded for the fiscal years ended September 30, 2014, 2013 and 2012, related to fair value measurements using significant level 3 inputs.

WGL Holdings, Inc. Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Fiscal Year Ended September 30, 2014
(In millions)	Natural Gas Related Derivatives			Electricity Related   Derivatives			Weather Related Instruments		Warrants			Total
Operating revenues—non-utility	$	(2.3	)	$	(22.1	)	$	-	$	-		$	(24.4)
Utility cost of gas		(69.4	)		-			-		-			(69.4)
Other income-net		-			-			-		(1.1	)		(1.1)
Non-utility cost of energy-related sales		(0.9	)		16.4			-		-			15.5
Total	$	(72.6	)	$	(5.7	)	$	-	$	(1.1	)	$	(79.4)
WGL Holdings, Inc. Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Fiscal Year Ended September 30, 2013
(In millions)	Natural Gas Related Derivatives			Electricity Related     Derivatives			Weather Related Instruments		Warrants			Total
Operating revenues—non-utility	$	(27.0	)	$	(9.1	)	$	-	$	-		$	(36.1	)
Utility cost of gas		(45.8	)		-			-		-			(45.8	)
Other income-net		-			-			-		0.2			0.2
Non-utility cost of energy-related sales		0.4			(14.7	)		-		-			(14.3	)
Operation and maintenance expense		-			-			1.2		-			1.2
Total	$	(72.4	)	$	(23.8	)	$	1.2	$	0.2		$	(94.8	)
WGL Holdings, Inc. Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Fiscal Year Ended September 30, 2012
(In millions)	Natural Gas Related Derivatives			Electricity Related     Derivatives			Weather Related Instruments		Warrants			Total
Operating revenues—non-utility	$	3.0		$	(14.2	)	$	-	$	-		$	(11.2	)
Utility cost of gas		14.3			-			-		-			14.3
Other income-net		-			-			-		0.9			0.9
Non-utility cost of energy-related sales		4.8			(33.5	)		-		-			(28.7	)
Operation and maintenance expense		-			-			7.9		-			7.9
Total	$	22.1		$	(47.7	)	$	7.9	$	0.9		$	(16.8	)

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

Washington Gas Light Company Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Fiscal Year Ended September 30, 2014
(In millions)	Natural Gas Related Derivatives			Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Utility cost of gas	$	(69.4	)	$	-	$	-	$	-	$	(69.4)
Total	$	(69.4	)	$	-	$	-	$	-	$	(69.4)
Washington Gas Light Company Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Fiscal Year Ended September 30, 2013
(In millions)	Natural Gas  Related Derivatives			Electricity Related   Derivatives		Weather Related   Instruments		Warrants		Total
Utility cost of gas	$	(45.9)		$	-	$	-	$	-	$	(45.9)
Operation and maintenance expense		-			-		1.2		-		1.2
Total	$	(45.9)		$	-	$	1.2	$	-	$	(44.7)
Washington Gas Light Company Realized and Unrealized Gains (Losses) Recorded for Level 3 Measurements
Fiscal Year Ended September 30, 2012
(In millions)	Natural Gas   Related Derivatives			Electricity Related   Derivatives		Weather Related   Instruments		Warrants		Total
Utility cost of gas	$	14.3		$	-	$	-	$	-	$	14.3
Operation and maintenance expense		-			-		7.9		-		7.9
Total	$	14.3		$	-	$	7.9	$	-	$	22.2

Unrealized gains (losses) for the fiscal years ended September 30, 2014, September 30, 2013 and September 30, 2012 attributable to derivative assets and liabilities measured using significant Level 3 inputs were recorded as follows, respectively:

WGL Holdings, Inc. Unrealized Gains (Losses) Recorded for Level 3 Measurements
Fiscal Year Ended September 30, 2014
(In millions)	Natural Gas Related  Derivatives		Electricity Related  Derivatives		Weather Related   Instruments		Warrants		Total
Recorded to income
Operating revenues—non-utility	$	(5.0)	$	(33.8)	$	-	$	-	$	(38.8)
Utility cost of gas		(60.6)		-		-		-		(60.6)
Non-utility cost of energy-related sales		3.7		30.0		-		-		33.7
Other income-net		-		-		-		(1.1)		(1.1)
Recorded to regulatory assets—gas costs		(109.9)		-		-		-		(109.9)
Total	$	(171.8)	$	(3.8)	$	-	$	(1.1)	$	(176.7)

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

WGL Holdings, Inc.

Unrealized Gains (Losses) Recorded for Level 3 Measurements

Fiscal Year Ended September 30, 2013
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Recorded to income
Operating revenues—non-utility	$	(25.3)	$	6.6	$	-	$	-	$	(18.7)
Utility cost of gas		(44.3)		-		-		-		(44.3)
Non-utility cost of energy-related sales		0.2		(1.1)		-		-		(0.9)
Other income-net		-		-		-		0.2		0.2
Recorded to regulatory assets—gas costs		(111.6)		-		-		-		(111.6)
Total	$	(181.0)	$	5.5	$	-	$	0.2	$	(175.3)
WGL Holdings, Inc. Unrealized Gains (Losses) Recorded for Level 3 Measurements
Fiscal Year Ended September 30, 2012
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Derivatives		Warrants		Total
Recorded to income
Operating revenues—non-utility	$	4.3	$	4.8	$	-	$	-	$	9.1
Utility cost of gas		13.8		-		-		-		13.8
Non-utility cost of energy-related sales		0.8		14.0		-		-		14.8
Other income-net		-		-		-		0.9		0.9
Operation and maintenance expense		-		-		0.2		-		0.2
Recorded to regulatory assets—gas costs		23.2		-		-		-		23.2
Total	$	42.1	$	18.8	$	0.2	$	0.9	$	62.0

Washington Gas Light Company

Unrealized Gains (Losses) Recorded for Level 3 Measurements

Fiscal Year Ended September 30, 2014
(In millions)	Natural Gas  Related  Derivatives		Electricity Related    Derivatives		Weather Related Instruments		Warrants		Total
Recorded to income
Utility cost of gas	$	(60.6)	$	-	$	-	$	-	$	(60.6)
Recorded to regulatory assets—gas costs		(109.9)		-		-		-		(109.9)
Total	$	(170.5)	$	-	$	-	$	-	$	(170.5)
Washington Gas Light Company Unrealized Gains (Losses) Recorded for Level 3 Measurements
Fiscal Year Ended September 30, 2013
(In millions)	Natural Gas Related Derivatives		Electricity Related   Derivatives		Weather Related   Instruments		Warrants		Total
Recorded to income
Utility cost of gas	$	(44.3)	$	-	$	-	$	-	$	(44.3)
Recorded to regulatory assets—gas costs		(111.6)		-		-		-		(111.6)
Total	$	(155.9)	$	-	$	-	$	-	$	(155.9)

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

Washington Gas Light Company Unrealized Gains (Losses) Recorded for Level 3 Measurements
Fiscal Years Ended September 30, 2012
(In millions)	Natural Gas   Related Derivatives		Electricity Related   Derivatives		Weather Related   Instruments		Warrants		Total
Recorded to income
Utility cost of gas	$	13.8	$	-	$	-	$	-	$	13.8
Operation and maintenance expense		-		-		0.2		-		0.2
Recorded to regulatory assets—gas costs		23.2		-		-		-		23.2
Total	$	37.0	$	-	$	0.2	$	-	$	37.2

The following table presents the carrying amounts and estimated fair values of our financial instruments at September 30, 2014 and 2013.

WGL Holdings, Inc.

Fair Value of Financial Instruments

At September 30,	2014				2013
(In millions)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Money market funds (a)	$	9.7	$	9.7	$	6.5	$	6.5
Other short- term investments(a)	$	-	$	-	$	0.1	$	0.1
Commercial paper (b)	$	453.5	$	453.5	$	373.1	$	373.1
Long-term debt(c)	$	679.2	$	809.3	$	524.1	$	630.2

Washington Gas Light Company

Fair Value of Financial Instruments

At September 30,	2014				2013
(In millions)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Money market funds (a)	$	4.3	$	4.3	$	3.1	$	3.1
Other short- term investments(a)	$	-	$	-	$	0.1	$	0.1
Commercial paper (b)	$	89.0	$	89.0	$	124.5	$	124.5
Long-term debt(c)	$	679.2	$	809.3	$	524.1	$	630.2

^(a) Balance located in cash and cash equivalents in the accompanying balance sheets. These amounts may be offset by outstanding checks.

^(b) Balance is located in notes payable in the accompanying balance sheets.

^(c) Less current maturities and unamortized discounts.

Our money market funds are Level 1 valuations and their carrying amount approximates fair value. Other short-term investments are primarily overnight investment accounts; therefore, their carrying amount approximates fair value based on Level 2 inputs. The maturity of our commercial paper outstanding at both September 30, 2014 and 2013 is under 30 days. Due to the short term nature of these notes, the carrying cost of our commercial paper approximates fair value using Level 2 inputs. Washington Gas’ long-term debt is not actively traded. The fair value of long-term debt was estimated based on the quoted market prices of the U.S. Treasury issues having a similar term to maturity, adjusted for Washington Gas’ credit quality. Our long-term debt fair value measurement is classified as Level 3.

Non Recurring Basis

During the fiscal year ended September 30, 2014, Washington Gas recorded an impairment of its previous operations center by reducing the carrying amount of $22.3 million down to its fair value of $21.5 million, resulting in an impairment charge of $0.8 million based on the progress made towards selling the facility. During the fiscal year ended September 30, 2013, Washington Gas recorded an impairment of this facility by reducing the carrying amount of $24.9 million down to its fair value of $22.3 million, resulting in an impairment charge of $2.6 million based on the progress made towards selling the facility. During the fiscal year ended September 30, 2012, Washington Gas recorded an impairment of this facility by reducing the carrying amount of $29.9 million down to its fair value of $24.9 million, resulting in an impairment charge of $5.0 million. The fair value of this facility is a Level 3 measurement. At September 30, 2012, the facility was valued using the discounted cash value model that incorporated the anticipated sale proceeds indicated through a comparable analysis, incorporating expected market trends, and the estimated costs to carry the asset until a sale is completed. The current fiscal year valuation is based on the progress in the efforts to sell the property.

On July 7, 2014, the SCC of VA disallowed full recovery of carrying costs related to an abandoned LNG storage facility. As a result, Washington Gas recorded an impairment charge of $1.9 million. During the fiscal year ended September 30, 2013, Washington Gas recorded an impairment charge of $0.5 million to the abandoned LNG storage facility.

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

NOTE 16. OPERATING SEGMENT REPORTING

We have four reportable operating segments: regulated utility, retail energy-marketing, commercial energy systems and midstream energy services. The division of these segments into separate revenue generating components is based upon regulation, products and services. Our chief operating decision maker is our Chief Executive Officer. While net income or loss applicable to common stock is the primary criterion for measuring a segment’s performance, we also evaluate our operating segments based on other relevant factors, such as penetration into their respective markets and return on equity. Our four segments are summarized below.

— Regulated Utility – The regulated utility segment is our core business. It consists of Washington Gas and Hampshire. Washington Gas provides regulated gas distribution services (including the sale and delivery of natural gas) to customers and natural gas transportation services to an unaffiliated natural gas distribution company in West Virginia under a Federal Energy Regulatory Commission (FERC) approved interstate transportation service operating agreement. Hampshire provides regulated interstate natural gas storage services to Washington Gas under a FERC approved interstate storage service tariff.

— Retail Energy-Marketing – The retail energy-marketing segment consists of WGEServices, which sells natural gas and electricity directly to retail customers in competition with regulated utilities and unregulated gas and electricity marketers.

— Commercial Energy Systems – The commercial energy systems segment consists of WGESystems which provides design-build energy efficient and sustainable solutions including commercial solar, energy efficiency and combined heat and power projects to government and commercial clients. In addition, this segment comprises the operations of WGSW, a holding company formed to invest in alternative energy assets.

— Midstream Energy Services – The midstream energy services segment consists of WGL Midstream, which engages in acquiring, investing in, managing and optimizing natural gas storage and transportation assets.

Activities and transactions that are not significant enough on a stand-alone basis to warrant treatment as an operating segment, and that do not fit into one of our four operating segments, are aggregated as “Other Activities” and included as part of non-utility operations in the Operating Segment Financial Information presented below. Administrative and business development activity costs associated with the WGL and Washington Gas Resources are included in this segment.

131

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

The following tables present operating segment information for the fiscal years ended September 30, 2014, 2013 and 2012.

Operating Segment Financial Information
			Non-Utility Operations
(In thousands)	Regulated Utility		Retail Energy- Marketing		Commercial Energy Systems		Midstream Energy Services			Other Activities			Eliminations (b)			Consolidated
Year Ended September 30, 2014
Operating Revenues (a)	$	1,443,800	$	1,310,279	$	40,679	$	16,555		$	-		$	(30,366	)	$	2,780,947
Operating Expenses:
Cost of Energy-Related Sales		726,879		1,238,970		20,348		-			-			(30,613	)		1,955,584
Operation		234,391		43,750		10,419		8,517			11,749			75			308,901
Maintenance		56,972		-		-		-			-			-			56,972
Depreciation and Amortization		104,064		756		6,178		124			-			(350	)		110,772
General Taxes and Other Assessments:
Revenue Taxes		84,287		8,276		5		-			-			-			92,568
Other		53,402		4,615		253		274			84			-			58,628
Total Operating Expenses	$	1,259,995	$	1,296,367	$	37,203	$	8,915		$	11,833		$	(30,888	)	$	2,583,425
Operating Income (Loss)		183,805		13,912		3,476		7,640			(11,833	)		522			197,522
Equity in Earnings of Unconsolidated Affiliates		-		1		1,953		771			469			-			3,194
Other Income (Expense)—Net		863		103		1,007		(239	)		(198	)		-			1,536
Interest Expense		37,127		10		-		-			601			-			37,738
Dividends on Washington Gas Preferred Stock		1,320		-		-		-			-			-			1,320
Income Tax Expense		48,181		5,764		1,019		1,969			111			210			57,254
Net Income (Loss) Applicable to Common Stock	$	98,040	$	8,242	$	5,417	$	6,203		$	(12,274	)	$	312		$	105,940
Total Assets at September 30, 2014	$	3,979,522	$	389,700	$	521,570	$	211,824		$	369,816		$	(615,933	)	$	4,856,499
Capital Expenditures	$	286,323	$	76	$	108,363	$	-		$	-		$	-		$	394,762
Equity Method Investments at September 30, 2014	$	-	$	-	$	66,810	$	28,076		$	16		$	-		$	94,902

^(a)Operating revenues are reported gross of revenue taxes. Revenue taxes of both the regulated utility and the retail energy-marketing segments include gross receipt taxes. Revenue taxes of the regulated utility segment also include PSC fees, franchise fees and energy taxes. Operating revenue amounts in the “Eliminations” column represent total intersegment revenues associated with sales from the regulated utility segment to the retail energy-marketing segment. Midstream Energy Services’ cost of energy related sales is netted with its gross revenues.

^(b)Intersegment eliminations net income includes a timing difference between Commercial Energy Systems’ recognition of revenue for the sale of Solar Renewable Energy Credits (SRECs) to Retail Energy-Marketing and Retail Energy’s Marketing’s recognition of the associate expense. Retail Energy-Marketing has recorded a portion of the SREC’s purchased as inventory to be used in future periods at which time they will be expensed.

132

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Part II

Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

Operating Segment Financial Information
			Non-Utility Operations
(In thousands)	Regulated Utility		Retail Energy- Marketing		Commercial Energy Systems			Midstream Energy Services			Other Activities			Eliminations  (b)			Consolidated
Year Ended September 30, 2013
Operating Revenues(a)	$	1,200,357	$	1,279,364	$	35,217		$	(20,390)		$	-		$	(28,410	)	$	2,466,138
Operating Expenses:
Cost of Energy-Related Sales		521,508		1,164,831		24,450			-			-			(26,458	)		1,684,331
Operation		243,341		49,574		6,875			8,683			9,344			(197	)		317,620
Maintenance		49,269		-		-			-			-			-			49,269
Depreciation and Amortization		100,438		726		2,411			124			-			(415	)		103,284
General Taxes and Other Assessments:
Revenue Taxes		81,422		6,831		7			-			-			-			88,260
Other		52,271		4,411		303			474			97			-			57,556
Total Operating Expenses	$	1,048,249	$	1,226,373	$	34,046		$	9,281		$	9,441		$	(27,070	)	$	2,300,320
Operating Income (Loss)		152,108		52,991		1,171			(29,671	)		(9,441	)		(1,340	)		165,818
Equity in Earnings of Unconsolidated Affiliates		-		-		1,070			312			128			-			1,510
Other Income (Expense)—Net		1,539		273		778			-			644			(686	)		2,548
Interest Expense		35,631		13		234			417			402			(686	)		36,011
Dividends on Washington Gas Preferred Stock		1,320		-		-			-			-			-			1,320
Income Tax Expense (Benefit)		44,883		20,227		(206	)		(10,951	)		(1,124	)		(537	)		52,292
Net Income (Loss) Applicable to Common Stock	$	71,813	$	33,024	$	2,991		$	(18,825	)	$	(7,947	)	$	(803	)	$	80,253
Total Assets at September 30, 2013	$	3,486,296	$	403,082	$	318,995		$	231,368		$	290,440		$	(470,121	)	$	4,260,060
Capital Expenditures	$	227,948	$	730	$	83,667		$	-		$	-		$	-		$	312,345
Equity Method Investments at September 30, 2013	$	-	$	-	$	54,977		$	6,507		$	413		$	-		$	61,897

^(a)Operating revenues are reported gross of revenue taxes. Revenue taxes of both the regulated utility and the retail energy-marketing segments include gross receipt taxes. Revenue taxes of the regulated utility segment also include PSC fees, franchise fees and energy taxes. Operating revenue amounts in the “Eliminations” column represent total intersegment revenues associated with sales from the regulated utility segment to the retail energy-marketing segment. Midstream Energy Services’ cost of energy related sales is netted with its gross revenues.

^(b)Intersegment eliminations net income includes a timing difference between Commercial Energy Systems’ recognition of revenue for the sale of Solar Renewable Energy Credits (SRECs) to Retail Energy-Marketing and Retail Energy’s Marketing’s recognition of the associate expense. Retail Energy-Marketing has recorded a portion of the SREC’s purchased as inventory to be used in future periods at which time will be expensed.

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Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

Operating Segment Financial Information
			Non-Utility Operations
(In thousands)	Regulated Utility		Retail Energy- Marketing		Commercial Energy Systems			Midstream Energy Services			Other Activities			Eliminations (b)			Consolidated
Year Ended September 30, 2012
Operating Revenues	$	1,137,666	$	1,267,070	$	60,325		$	(11,221)		$	-		$	(28,530	)	$	2,425,310
Operating Expenses:
Cost of Energy-Related Sales		421,539		1,139,162		51,149			-			-			(26,802	)		1,585,048
Operation		227,362		52,161		5,414			2,860			3,612			(1,093	)		290,316
Maintenance		52,494		-		-			-			-			-			52,494
Depreciation and Amortization		94,998		735		1,261			116			-			(634	)		96,476
General Taxes and Other Assessments:
Revenue Taxes		74,244		5,776		8			-			-			-			80,028
Other		50,822		4,070		280			240			16			(1	)		55,427
Total Operating Expenses	$	921,459	$	1,201,904	$	58,112		$	3,216		$	3,628		$	(28,530	)	$	2,159,789
Operating Income (Loss)		216,207		65,166		2,213			(14,437	)		(3,628	)		-			265,521
Equity in Earnings of Unconsolidated Affiliates		-		-		947			-			293			-			1,240
Other Income—Net		3,085		42		(32	)		-			1,097			(38	)		4,154
Interest Expense		36,098		1		1			-			366			(38	)		36,428
Dividends on Washington Gas Preferred Stock		1,320		-		-			-			-			-			1,320
Income Tax Expense (Benefit)		72,178		25,876		760			(5,347	)		(118	)		-			93,349
Net Income (Loss) Applicable to Common Stock	$	109,696	$	39,331	$	2,367		$	(9,090	)	$	(2,486	)	$	-		$	139,818
Total Assets at September 30, 2012	$	3,516,046	$	361,801	$	148,407		$	169,456		$	211,038		$	(295,801	)	$	4,110,947
Capital Expenditures	$	208,225	$	984	$	41,818		$	101		$	-		$	-		$	251,128
Equity Method Investments at September 30, 2012	$	-	$	-	$	23,346		$	-		$	-		$	-		$	23,346

^(a)Operating revenues are reported gross of revenue taxes. Revenue taxes of both the regulated utility and the retail energy-marketing segments include gross receipt taxes. Revenue taxes of the regulated utility segment also include PSC fees, franchise fees and energy taxes. Operating revenue amounts in the “Eliminations” column represent total intersegment revenues associated with sales from the regulated utility segment to the retail energy-marketing segment. Midstream Energy Services’ cost of energy related sales is netted with its gross revenues.

^(b)Intersegment eliminations net income includes a timing difference between Commercial Energy Systems’ recognition of revenue for the sale of Solar Renewable Energy Credits (SRECs) to Retail Energy-Marketing and Retail Energy’s Marketing’s recognition of the associate expense. Retail Energy-Marketing has recorded a portion of the SREC’s purchased as inventory to be used in future periods at which time they will be expensed.

NOTE 17. OTHER INVESTMENTS

When determining how to account for our interests in other legal entities, WGL first evaluates if we are required to apply the variable interest entity (VIE) model to the entity, otherwise the entity is evaluated under the voting interest model.

Under the VIE model, we have a controlling financial interest in a VIE (i.e. are the primary beneficiary) when we have current or potential rights that give us the power to direct the activities of a VIE that most significantly impact the VIE’s economic performance combined with a variable interest that gives us the right to receive potentially significant benefits or the obligation to absorb potentially significant losses. When changes occur to the design of an entity we reconsider whether it is subject to the VIE model. We continuously evaluate whether we have a controlling financial interest in a VIE.

Under the voting interest model, we generally have a controlling financial interest in an entity where we currently hold, directly or indirectly, more than 50% of the voting rights or where we exercise control through substantive participating rights. However, we consider substantive rights held by other partners in determining if we hold a controlling financial interest, and in some cases, despite owning more than 50% of the common stock of an investee, an evaluation of our rights results in the determination that we do not have a controlling financial interest. We reevaluate whether we have a controlling financial interest in these entities when our voting or substantive participating rights change.

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Notes to Consolidated Financial Statements

Unconsolidated affiliates are unconsolidated VIEs and other entities evaluated under the voting interest method in which we do not have a controlling financial interest, but over which we have varying degrees of influence. Where we have significant influence, the affiliates are accounted for as equity method investments. Where we do not have significant influence, the affiliates are accounted for under the cost method. Investments in, and advances to, affiliated companies are presented on a one-line basis in the caption “Investments in unconsolidated affiliates” on our Consolidated Balance Sheet.

WGL uses the Hypothetical Liquidation at Book Value (HLBV) methodology for certain equity method investments when the capital structure of the equity investment results in different liquidation rights and priorities than what is reflected by the underlying percentage ownership interests as defined by an equity investment agreement. For investments accounted for under the HLBV method, simply applying the percentage ownership interest to GAAP net income in order to determine earnings or losses does not accurately represent the income allocation and cash flow distributions that will ultimately be received by the investors. The equity investment agreements for ASD Solar, LP (ASD) and Meade Pipeline Co LLC (Meade) both have liquidation rights and priorities that are sufficiently different from the ownership percentages that the HLBV method was deemed appropriate.

WGL applies HLBV using a balance sheet approach. A calculation is prepared at each balance sheet date to determine the amount that WGL would receive if an equity investment entity were to liquidate all of its assets (as valued in accordance with GAAP) and distribute that cash to the investors based on the contractually defined liquidation priorities. The difference between the calculated liquidation distribution amounts at the beginning and the end of the reporting period is WGL’s share of the earnings or losses from the equity investment for the period. The calculation may vary in its complexity depending on the capital structure and the tax considerations for the investments.

Variable Interest Entities

WGL has a variable interest in five investments that qualify as VIEs:

• Meade,

• SunEdison,

• Nextility,

• ASD Solar LP and

• Crab Run.

WGL and its subsidiaries are not the primary beneficiary for any of the above VIEs, therefore we have not consolidated any of the VIE entities. At September 30, 2014, the nature of WGL’s involvement with these investments lacks the characteristics of a controlling financial interest. WGL does not have control over any of the VIEs’ activities that are economically significant to the VIEs. In addition, WGL does not have the obligation to absorb expected losses or the right to receive expected gains that could be significant to the VIE.

Meade

On February 14, 2014, WGL, through its subsidiary WGL Midstream, entered into a limited liability company agreement and formed Meade, a Delaware limited liability company with COG Holdings LLC, Vega Midstream MPC LLC and River Road Interests LLC. Meade was formed to partner with Transcontinental Gas Pipeline Company, LLC (Williams) to invest in a regulated pipeline project called Central Penn Pipeline (Central Penn). The Central Penn will be an approximately 177 mile pipeline originating in Susquehanna County, Pennsylvania and extending to Lancaster County, Pennsylvania that will have the capacity to transport and deliver up to approximately 1.7 million dekatherms per day of natural gas.

WGL Midstream plans to invest an estimated $410.0 million for a 55% interest in Meade. WGL Midstream joins COG Holdings LLC (20% share), Vega Midstream MPC LLC (15% share) and River Road Interests LLC (10% share) in Meade. Meade is accounted for under the HLBV equity method of accounting, and any profits and losses are included in “Equity in earnings of unconsolidated affiliates” in the accompanying Consolidated Statement of Income and are added to or subtracted from the carrying amount of WGL’s investment balance. WGL Midstream held a $5.8 million equity method investment in Meade at September 30, 2014.

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Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

Our maximum financial exposure includes contributions and guarantees on behalf of WGL Midstream. In addition, we have guaranteed the future commitments of one of the other partners in the venture. Our maximum exposure to loss at September 30, 2014 was $74.0 million, which represents the minimum funding requirements owed to Williams under the Construction and Ownership Agreement should Meade terminate its agreement with Williams early and the guarantee on behalf of one of the other partners.

SunEdison/Nextility

WGSW is party to three agreements to fund residential and commercial retail solar energy installations with three separate, privately held companies. WGSW has a master purchase agreement and master lease agreement with SunEdison, Inc. (SunEdison), formerly known as EchoFirst Finance Company LLC (EchoFirst) and Nextility, Inc. (Nextility), formerly known as Skyline Innovations, Inc (Skyline) for sale/leaseback arrangements for residential and commercial solar systems.

Our agreements with SunEdison and Nextility are accounted for as direct financing leases. WGSW records associated interest in the financing leases in “Other income (expenses)-net” line in the accompanying Consolidated Statement of Income. WGSW held a $19.9 million and $29.2 million combined investment in direct financing leases at September 30, 2014 and 2013, respectively, of which $1.7 million and $5.8 million are current receivables recorded in “Accounts Receivable” in the accompanying Consolidated Balance Sheets at September 30, 2014 and 2013, respectively.

Minimum future lease payments receivable under direct financing leases over the next five fiscal years and thereafter are as follows:

Minimum Payments Receivable for Direct Financing Leases
(In millions)
2015	$	2.3
2016		2.0
2017		1.9
2018		1.8
2019		1.7
Thereafter		12.3
Total	$	22.0

Minimum payments receivable exclude $5.1 million of residual values and $3.0 million in tax credits. Associated with these investments, WGSW holds $10.2 million of unearned income on its balance sheet. The initial direct costs (incurred in FY 2012) associated with these investments was $0.7 million.

Our maximum financial exposure from solar agreements is limited to its lease payment receivables and investment contributions made to these companies. All additional future committed contributions are contingent on the projects meeting required criteria. Our exposure is offset by the owned physical assets received as part of the transaction and the quick economic return for the investment through the investment tax credit/treasury grant proceeds and accelerated depreciation.

ASD Solar, LP

In addition to SunEdison/Skyline, WGSW is also a limited partner in ASD Solar, LP (ASD), a partnership formed to own and operate a portfolio of residential solar projects, primarily rooftop photovoltaic power generation systems. As a limited partner, WGSW provided funding to the partnership but is excluded from involvement in the partnership’s operations. In January 2014, the funding commitment period expired for the partnership. WGSW’s maximum financial exposure includes contributions made to the partnership.

Our investment in ASD is accounted for under the HLBV equity method of accounting; any profits and losses are included in “Equity in earnings of unconsolidated affiliates” in the accompanying Consolidated Statement of Income and are added to or subtracted from the carrying amount of WGSW’s investment balance. WGSW held a $66.8 million equity method investment in ASD at September 30, 2014.

ASD is consolidated by the general partner, Solar Direct LLC. Solar Direct LLC is a wholly owned subsidiary of American Solar Direct Inc. (ASDI). At September 30, 2014, the carrying amount of WGSW’s investment in ASD exceeded the amount of the underlying equity in net assets by $35.9 million due to WGSW recording additions to its investment in ASD’s net assets at fair value of contributions in accordance with GAAP. This basis difference is being amortized over the life of the assets.

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Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

Crab Run

WGL owns all of the shares of common stock of Crab Run Gas Company. Crab Run Gas Company is an exploration and production company who is the limited partner in the Western/Crab Run Limited Partnership (Crab Run). The partnership was formed to manage oil and gas properties and perform oil and gas leasing, marketing and production activities.

Crab Run is accounted for under the equity method of accounting; any profits and losses are included in “Equity in earnings of unconsolidated affiliates” in the accompanying Consolidated Statement of Income and are added to or subtracted from the carrying amount of WGL’s investment balance. WGL held a minimal portion of equity investment in Crab Run at September 30, 2014.

Non-VIE Investments

ASDHI

Washington Gas Resources held a $5.6 million investment in American Solar Direct Holdings Inc. (ASDHI), at both September 30, 2014 and 2013. This investment is recorded at cost. No identified events or changes in circumstances that may have a significant effect on the carrying value of this investment have occurred. At September 30, 2014 and 2013, Washington Gas Resources also held $0.8 million and $1.9 million, respectively in warrants of ASDHI which were accounted for as derivatives and recorded at fair value.

Constitution

In May of 2013, WGL Midstream invested in Constitution Pipeline Company, LLC (Constitution). WGL Midstream will invest an estimated $72.0 million in the project for a 10% share in the pipeline venture. WGL Midstream joins Williams Partners L.P. (41% share), Cabot Oil and Gas Corporation (25% share) and Piedmont Natural Gas (24% share) in the project. This natural gas pipeline venture will transport natural gas per day from the Marcellus region in northern Pennsylvania to major northeastern markets. At September 30, 2014, WGL Midstream had invested $22.2 million. Constitution is accounted for under the equity method of accounting; any profits and losses are included in “Equity in earnings of unconsolidated affiliates” in the accompanying Consolidated Statement of Income and are added to or subtracted from the carrying amount of WGL’s investment balance. The equity method is considered appropriate because Constitution is an LLC with specific ownership accounts and ownership between five and fifty percent resulting in WGL Midstream maintaining a more than minor influence over the partnership operating and financing policies.

The balance sheet location of the investments discussed in this footnote at September 30, 2014 and 2013 are as follows:

WGL Holdings, Inc Balance Sheet Location of Other Investments
As of September 30, 2014 (in millions)	VIEs		Non-VIEs		Total
Assets
Investments in unconsolidated affiliates	$	72.6	$	27.9	$	100.5
Investments in direct financing leases, capital leases		18.2		-		18.2
Accounts receivable		1.7		-		1.7
Total assets	$	92.5	$	27.9	$	120.4

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Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

WGL Holdings, Inc. Balance Sheet Location of Other Investments
As of September 30, 2013 (in millions)	VIEs		Non-VIEs		Total
Assets
Investments in unconsolidated affiliates	$	55.4	$	12.1	$	67.5
Investments in direct financing leases, capital leases		23.4		-		23.4
Deferred charges and other assets - derivatives		-		1.1		1.1
Accounts receivable		5.8		-		5.8
Total assets	$	84.6	$	13.2	$	97.8
Liabilities
Other	$	8.5	$	-	$	8.5
Total liabilities	$	8.5	$	-	$	8.5

The income statement location of the investments discussed in this footnote for the fiscal year September 30, 2014 and 2013 are as follows:

WGL Holdings, Inc.

Income Statement Location of Other Investments

	Fiscal year ended
	September 30, 2014
(in millions)	VIEs		Non-VIEs		Total
Equity in earnings of unconsolidated affiliates	$	2.2	$	1.0	$	3.2
Depreciation and amortization	$	0.2	$	-	$	0.2
Other income - net	$	2.6		-		2.6
Net Income	$	4.6	$	1.0	$	5.6
WGL Holdings, Inc. Income Statement Location of Other Investments
	Fiscal year ended
	September 30, 2013
(in millions)	VIEs		Non-VIEs		Total
Equity in earnings of unconsolidated affiliates	$	1.0	$	0.5	$	1.5
Depreciation and amortization	$	0.1	$	-	$	0.1
Other income - net	$	1.4	$	-	$	1.4
Net Income	$	2.3	$	0.5	$	2.8

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Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

NOTE 18. RELATED PARTY TRANSACTIONS

WGL and its subsidiaries engage in transactions during the ordinary course of business. Inter-company transactions and balances have been eliminated from the consolidated financial statements of WGL, except as described below. Washington Gas provides accounting, treasury, legal and other administrative and general support to affiliates, and files consolidated tax returns that include affiliated taxable transactions. Washington Gas bills its affiliates in accordance with regulatory requirements for the actual cost of providing these services, which approximates their market value. To the extent such billings are not yet paid, they are reflected in “Receivables from associated companies” on Washington Gas’ balance sheets. Washington Gas assigns or allocates these costs directly to its affiliates and, therefore, does not recognize revenues or expenses associated with providing these services.

In connection with billing for unregulated third party marketers and with other miscellaneous billing processes, Washington Gas collects cash on behalf of affiliates and transfers the cash in a reasonable time period. Cash collected by Washington Gas on behalf of its affiliates but not yet transferred is recorded in “Payables to associated companies” on Washington Gas’ balance sheets. The following table presents the receivables and payables from associated companies for the fiscal years ended September 30, 2014 and 2013.

Washington Gas Light Company Receivables / Payables from Associated Companies
(In millions)	September 30, 2014		September 30, 2013
Receivables from Associated Companies	$	4.8	$	7.2
Payables to Associated Companies	$	54.7	$	20.6

Washington Gas provides gas balancing services related to storage, injections, withdrawals and deliveries to all energy marketers participating in the sale of natural gas on an unregulated basis through the customer choice programs that operate in its service territory. These balancing services include the sale of natural gas supply commodities related to various peaking arrangements contractually supplied to Washington Gas and then partially allocated and assigned by Washington Gas to the energy marketers, including WGEServices. Washington Gas records revenues for these balancing services pursuant to tariffs approved by the appropriate regulatory bodies. These related party amounts have been eliminated in the consolidated financial statements of WGL. The following table shows the amounts Washington Gas charged WGEServices for balance services.

Washington Gas - Gas Balancing Service Charges
	Years Ended September 30,
(In millions)	2014		2013		2012
Gas balancing service charge	$	26.6	$	25.0	$	26.8

As a result of these balancing services, an imbalance is created for volumes of natural gas received by Washington Gas that are not equal to the volumes of natural gas delivered to customers of the energy marketers. WGEServices recognized an accounts receivable from Washington Gas of $0.02 million and $1.0 million at September 30, 2014 and 2013, respectively, related to an imbalance in gas volumes. Due to regulatory treatment, these receivables and payables are not eliminated in the consolidated financial statements of WGL. Refer to Note 1—Accounting Policies for further discussion of these imbalance transactions.

Washington Gas participates in a POR program as approved by the PSC of MD, whereby it purchases receivables from participating energy marketers at approved discount rates. In addition, WGEServices participates in POR programs with certain Maryland and Pennsylvania utilities, whereby it sells its receivables to various utilities, including Washington Gas, at approved discount rates. The receivables purchased by Washington Gas are included in “Accounts receivable” in the accompanying balance sheet. Any activity between Washington Gas and WGEServices related to the POR program has been eliminated in the accompanying financial statements for WGL. At September 30, 2014 and 2013, Washington Gas had balances of $7.7 million and $106.6 million, respectively, of purchased receivables from WGEServices.

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Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

NOTE 19. ACCUMULATED OTHER COMPREHENSIVE INCOME

The following tables show the changes in accumulated other comprehensive income for WGL and Washington Gas by component for the fiscal years ended September 30, 2014 and 2013.

WGL Holdings, Inc. Changes in Accumulated Other Comprehensive Income by Component
	September 30,
(In thousands)	2014			2013
Beginning Balance	$	(11,048	)	$	(12,201	)
Qualified cash flow hedging instruments(c)		(1,548	)		-
Change in prior service cost (credit) (a) (b)		6,095			(1,671	)
Amortization of actuarial gain (a)		1,594			3,399
Amortization of transition obligation (a)		-			238
Current-period other comprehensive income		6,141			1,966
Income tax expense related to other comprehensive income (b)		3,054			813
Ending Balance	$	(7,961	)	$	(11,048	)

^(a) These accumulated other comprehensive income components are included in the computation of net periodic benefit cost. Refer to Note 10-Pension and other post-retirement benefit plans for additional details.

^(b) The majority of the 2014 change to the prior service cost component of other comprehensive income is related to the impact of the OPEB plan amendment and re-measurement. Refer to Note 10-Pension and other post-retirement benefit plans for additional details.

^(c) Cash flow hedging instruments represent interest rate swap agreements on debt issuances. Refer to Note 14—Derivative and Weather-related Instruments for further discussion of the interest rate swap agreements.

Washington Gas Light Company Changes in Accumulated Other Comprehensive Income by Component
	September 30,
(In thousands)	2014			2013
Beginning Balance	$	(11,048	)	$	(12,201	)
Change in prior service cost (credit) (a) (b)		6,095			(1,671	)
Amortization of actuarial gain (a)		1,594			3,399
Amortization of transition obligation (a)		-			238
Current-period other comprehensive income		7,689			1,966
Income tax expense related to other comprehensive income (b)		3,054			813
Ending Balance	$	(6,413	)	$	(11,048	)

^(a) These accumulated other comprehensive income components are included in the computation of net periodic benefit cost. Refer to Note 10-Pension and other post-retirement benefit plans for additional details.

^(b) The majority of the 2014 change to the prior service cost component of other comprehensive income is related to the impact of the OPEB plan amendment and re-measurement. Refer to Note 10-Pension and other post-retirement benefit plans for additional details.

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Item 8. Financial Statements and Supplementary Data (continued)

Notes to Consolidated Financial Statements

NOTE 20. SUBSEQUENT EVENTS

Debt Issuances

On October 24, 2014, WGL issued $100.0 million of 2.25% notes due November 1, 2019 (“2019 Notes”) and $125.0 million of 4.60% notes due November 1, 2044 (“2044 Notes”). The notes were priced at 99.792% and 99.226% of par, respectively. The first semiannual coupon payment date is May 1, 2015. These issuances will be recorded at cost.

The 2019 Notes have a make whole call provision that WGL may exercise at any time on or after October 24, 2014 and prior to October 1, 2019. At any time on or after October 1, 2019, the 2019 Notes may be called at 100% of the principal of such notes, plus accrued and unpaid interest. The 2044 Notes have a make whole call provision that WGL may exercise at any time on or after October 24, 2014 and prior to May 1, 2044. At any time on or after May 1, 2044, the 2044 Notes may be called at 100% of the principal of such notes, plus accrued and unpaid interest.

In connection with the issuance of the 2044 Notes, WGL settled two forward starting swap hedges for $75.0 million and $50.0 million, both of which resulted in payments to the counterparties of $4.6 million and $3.1 million, respectively.

Proceeds from the sale of these notes will be used by WGL to primarily fund the repurchase of outstanding securities of WGL and capital investments of its non-utility subsidiaries.

These transactions were executed with Wells Fargo Securities, LLC, BB&T Capital Markets, TD Securities and CIBC World Markets as underwriters.

Security Ratings

On October 15, 2014, Fitch Ratings downgraded WGL’s credit rating for its senior unsecured debt to “A” from “A+.” On October 22, 2014, Moody’s assigned an issue credit rating for WGL’s senior unsecured debt of “A3” and S&P assigned an issue credit rating for WGL’s senior unsecured debt of “A.”

Legal Matters

As previously disclosed, WGL has been cooperating with a Department of Justice (“the Department”) investigation of some of the federal contracting activities of one of its non-utility subsidiaries, WGESystems. The Department’s investigation concerned certain American Recovery and Reinvestment Act projects bid out by the General Services Administration in 2010, in which WGESystems participated as a subcontractor to an 8(a) prime contractor under the Small Business Administration’s 8(a) Business Development Program. On November 18, 2014, WGESystems entered into a deferred prosecution agreement with the Department, which will resolve the investigation. The agreement is for a two-year period, and the Department will not pursue the prosecution of WGESystems if WGESystems discharges its obligations under the agreement during the two-year term of the agreement. Pursuant to the agreement, WGESystems will pay fines and monetary penalties totaling $2,587,261 to the Department and implement and maintain certain remedial measures specified in the agreement.

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Item 8. Financial Statements and Supplementary Data (continued)

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders of WGL Holdings, Inc.

We have audited the accompanying consolidated balance sheets and consolidated statements of capitalization of WGL Holdings, Inc. and subsidiaries (the “Company”) as of September 30, 2014 and 2013, and the related consolidated statements of income, comprehensive income, common shareholders’ equity, and cash flows for each of the three years in the period ended September 30, 2014. Our audits also included the financial statement schedule of the Company listed in the Index at Item 15 under Schedule II. These financial statements and financial statement schedule are the responsibility of the Company’s management. Our responsibility is to express an opinion on the financial statements and financial statement schedule 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, such consolidated financial statements present fairly, in all material respects, the financial position of WGL Holdings, Inc. and subsidiaries as of September 30, 2014 and 2013, and the results of their operations and their cash flows for each of the three years in the period ended September 30, 2014, in conformity with accounting principles generally accepted in the United States of America. Also, 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.

We have also 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 September 30, 2014, based on the criteria established in Internal Control—Integrated Framework (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated November 21, 2014 expressed an unqualified opinion on the Company’s internal control over financial reporting.

/s/ DELOITTE & TOUCHE LLP

McLean, Virginia

November 21, 2014

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Item 8. Financial Statements and Supplementary Data (continued)

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholder of Washington Gas Light Company

We have audited the accompanying balance sheets and statements of capitalization of Washington Gas Light Company (the “Company”) as of September 30, 2014 and 2013, and the related statements of income, comprehensive income, common shareholder’s equity, and cash flows for each of the three years in the period ended September 30, 2014. Our audits also included the financial statement schedule of the Company listed in the Index at Item 15 under Schedule II. These financial statements and financial statement schedule are the responsibility of the Company’s management. Our responsibility is to express an opinion on the financial statements and financial statement schedule 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. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audits 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 audits provide a reasonable basis for our opinion.

In our opinion, such financial statements present fairly, in all material respects, the financial position of Washington Gas Light Company as of September 30, 2014 and 2013, and the results of their operations and their cash flows for each of the three years in the period ended September 30, 2014, in conformity with accounting principles generally accepted in the United States of America. Also, in our opinion, such financial statement schedule, when considered in relation to the basic financial statements taken as a whole, presents fairly in all material respects the information set forth therein.

/s/ DELOITTE & TOUCHE LLP

McLean, Virginia

November 21, 2014

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Washington Gas Light Company

Part II

Item 8. Financial Statements and Supplementary Data (concluded)

SUPPLEMENTARY FINANCIAL INFORMATION (Unaudited)

QUARTERLY FINANCIAL DATA

All adjustments necessary for a fair presentation have been included in the quarterly information provided below. Due to the seasonal nature of our business, we report substantial variations in operations on a quarterly basis.

Quarter Ended
(In thousands, except per share data)	December 31		March 31		June 30			September 30
Fiscal Year 2014
WGL Holdings, Inc.
Operating revenues	$	680,297	$	1,174,250	$	467,500		$	458,900
Operating income (loss)	$	32,712	$	104,733	$	(9,489	)	$	69,566
Net income (loss) applicable to common stock	$	18,629	$	61,213	$	(11,940	)	$	38,038
Earnings (loss) per average share of common stock:
Basic	$	0.36	$	1.18	$	(0.23	)	$	0.74
Diluted	$	0.36	$	1.18	$	(0.23	)	$	0.74
Washington Gas Light Company
Operating revenues	$	390,415	$	716,808	$	197,752		$	138,825
Operating income	$	65,229	$	88,038	$	4,326		$	24,530
Net income (loss) applicable to common stock	$	38,477	$	49,176	$	(521	)	$	9,872
Fiscal Year 2013
WGL Holdings, Inc.
Operating revenues	$	686,736	$	891,383	$	478,118		$	409,901
Operating income (loss)	$	94,616	$	155,584	$	(9,111	)	$	(75,270)
Net income (loss) applicable to common stock	$	52,388	$	89,505	$	(10,015	)	$	(51,625)
Earnings (loss) per average share of common stock:
Basic	$	1.01	$	1.73	$	(0.19	)	$	(1.00)
Diluted	$	1.01	$	1.73	$	(0.19	)	$	(1.00)
Washington Gas Light Company
Operating revenues	$	355,817	$	535,950	$	180,882		$	127,708
Operating income (loss)	$	72,037	$	134,358	$	(368	)	$	(55,421	)
Net income (loss) applicable to common stock	$	38,387	$	76,935	$	(4,531	)	$	(39,789	)

During the first quarter of fiscal year 2014, Washington Gas recorded an impairment charge of $0.8 million related to the Springfield Operations Center. During the third quarter of fiscal year 2014, Washington Gas recorded a $1.9 million impairment charge on an abandoned LNG storage facility. During the fourth quarter of fiscal year 2013, Washington Gas recorded an impairment charge of $2.6 million related to the Springfield Operations Center and a $0.5 million impairment charge on an abandoned LNG storage facility. Refer to Note 1—Accounting Policies of the Notes to Consolidated Financial Statements for further discussion of the impairments.

144

WGL Holdings, Inc.

Washington Gas Light Company

Part II

ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE

None.

ITEM 9A. CONTROLS AND PROCEDURES—WGL Holdings, Inc.

EVALUATION OF DISCLOSURE CONTROLS AND PROCEDURES

Senior management, including the Chairman and Chief Executive Officer and the Senior Vice President and Chief Financial Officer of WGL, evaluated the effectiveness of WGL’s disclosure controls and procedures as of September 30, 2014. Based on this evaluation, the Chairman and Chief Executive Officer and the Senior Vice President and Chief Financial Officer have concluded that WGL’s disclosure controls and procedures were effective as of September 30, 2014.

MANAGEMENT’S REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING

Management of WGL is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934. WGL’s internal control over financial reporting is 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 in the United States of America.

Because of the inherent limitations of internal control over financial reporting, including the possibility of human error and the circumvention or overriding of controls, material misstatements may not be prevented or detected on a timely basis. Accordingly, even internal controls determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation. Furthermore, projections of any evaluation of the effectiveness to future periods are subject to the risk that such controls may become inadequate due to changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

Management has assessed the effectiveness of WGL’s internal control over financial reporting as of September 30, 2014 based upon the criteria set forth in the original report entitled Internal Control—Integrated Framework (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on its assessment, management has concluded that WGL maintained effective internal control over financial reporting as of September 30, 2014.

Deloitte & Touche LLP, the independent registered public accounting firm of WGL, has audited the effectiveness of WGL’s internal control over financial reporting as of September 30, 2014. Deloitte & Touche LLP’s report on the audit of WGL’s internal control over financial reporting is included in Item 9A of this Form 10-K.

CHANGES IN INTERNAL CONTROL OVER FINANCIAL REPORTING

There have been no changes in the internal control over financial reporting of WGL during the quarter ended September 30, 2014 that have materially affected, or are reasonably likely to materially affect, the internal control over financial reporting of WGL.

145

WGL Holdings, Inc.

Washington Gas Light Company

Part II

ITEM 9A. CONTROLS AND PROCEDURES—Washington Gas Light Company

EVALUATION OF DISCLOSURE CONTROLS AND PROCEDURES

Senior management, including the Chairman and Chief Executive Officer and the Senior Vice President and Chief Financial Officer of Washington Gas, evaluated the effectiveness of Washington Gas’ disclosure controls and procedures as of September 30, 2014. Based on this evaluation, the Chairman and Chief Executive Officer and the Senior Vice President and Chief Financial Officer have concluded that Washington Gas’ disclosure controls and procedures were effective as of September 30, 2014.

MANAGEMENT’S REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING

Management of Washington Gas is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934. Washington Gas’ internal control over financial reporting is 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 in the United States of America.

Because of the inherent limitations of internal control over financial reporting, including the possibility of human error and the circumvention or overriding of controls, material misstatements may not be prevented or detected on a timely basis. Accordingly, even internal controls determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation. Furthermore, projections of any evaluation of the effectiveness to future periods are subject to the risk that such controls may become inadequate due to changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

Management has assessed the effectiveness of Washington Gas’ internal control over financial reporting as of September 30, 2014 based upon the criteria set forth in the original report entitled Internal Control—Integrated Framework (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on its assessment, management has concluded that Washington Gas maintained effective internal control over financial reporting as of September 30, 2014.

This annual report on Form 10-K does not include an attestation report of Washington Gas’ registered public accounting firm regarding internal control over financial reporting pursuant to rules of the Securities and Exchange Commission that permit Washington Gas to provide only this management’s report in this annual report on Form 10-K.

CHANGES IN INTERNAL CONTROL OVER FINANCIAL REPORTING

There have been no changes in the internal control over financial reporting of Washington Gas during the quarter ended September 30, 2014 that have materially affected, or are reasonably likely to materially affect, the internal control over financial reporting of Washington Gas.

146

WGL Holdings, Inc.

Washington Gas Light Company

Part II

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders of WGL Holdings, Inc.

We have audited the internal control over financial reporting of WGL Holdings. Inc. and subsidiaries (the “Company”) as of September 30, 2014, based on criteria established in Internal Control — Integrated Framework (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission. 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 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, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and 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 by, or under the supervision of, the company’s principal executive and principal financial officers, or persons performing similar functions, and effected by the company’s board of directors, management, and other personnel 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 the inherent limitations of internal control over financial reporting, including the possibility of collusion or improper management override of controls, material misstatements due to error or fraud may not be prevented or detected on a timely basis. Also, projections of any evaluation of the effectiveness of the internal control over financial reporting to future periods are subject to the risk that the 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, the Company maintained, in all material respects, effective internal control over financial reporting as of September 30, 2014, based on the criteria established in Internal Control — Integrated Framework (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated financial statements and financial statement schedule as of and for the year ended September 30, 2014 of the Company and our report dated November 21, 2014 expressed an unqualified opinion on those financial statements and financial statement schedule.

/s/ DELOITTE & TOUCHE LLP

McLean, Virginia

November 21, 2014

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Washington Gas Light Company

Part II

ITEM 9B. OTHER INFORMATION

None.

148

WGL Holdings, Inc.

Washington Gas Light Company

Part III

ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE OF THE REGISTRANTS

Information concerning WGL’s and Washington Gas’ Board of Directors and the audit committee financial expert contained in WGL’s definitive Proxy Statement and Washington Gas’ definitive Information Statement for the March 3, 2015 Annual Meeting of Shareholders is hereby incorporated by reference. Information related to Executive Officers is reflected in Part I hereof.

ITEM 11. EXECUTIVE COMPENSATION

Information concerning Executive Compensation contained in WGL’s definitive Proxy Statement and Washington Gas’ definitive Information Statement for the March 3, 2015 Annual Meeting of Shareholders is hereby incorporated by reference. Information related to Executive Officers as of September 30, 2014 is reflected in Part I hereof.

ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS

The information captioned Security Ownership of Management and Certain Beneficial Owners and the information captioned Equity Compensation Plan Information in WGL’s definitive Proxy Statement and Washington Gas’ definitive Information Statement for the March 3, 2015 Annual Meeting of Shareholders is hereby incorporated by reference.

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE

The information captioned Related Person Transactions During Fiscal Year 2014 in WGL’s definitive Proxy Statement and Washington Gas’ definitive Information Statement for the March 3, 2015 Annual Meeting of Shareholders is hereby incorporated by reference.

ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES

The information captioned Fiscal Years 2014 and 2013 Audit Firm Fee Summary in WGL’s definitive Proxy Statement and Washington Gas’ definitive Information Statement for the March 3, 2015 Annual Meeting of Shareholders is hereby incorporated by reference.

149

WGL Holdings, Inc.

Washington Gas Light Company

Part IV

Item 15. Exhibits and Financial Statement Schedules

ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES

Financial Statement Schedules

(a)(1)

All of the financial statements and financial statement schedules filed as a part of the annual report on Form 10-K are included in Item 8.

(a)(2)

Schedule II should be read in conjunction with the financial statements in this report. Schedules not included herein have been omitted because they are not applicable or the required information is shown in the financial statements or notes thereto.

Schedule/ Exhibit	Description
II	Valuation and Qualifying Accounts and Reserves for the years ended September 30, 2014, 2013 and 2012—WGL Holdings, Inc.
	Valuation and Qualifying Accounts and Reserves for the years ended September 30, 2014, 2013 and 2012—Washington Gas Light Company.
(a)(3)	Exhibits
	Exhibits Filed Herewith:
3	Bylaws of Washington Gas Light Company, as amended on September 24, 2014.
10.1	Form of Performance Share Award Agreement, as amended on October 21, 2014.*
10.2	Form of Performance Units Award Agreement, as amended on October 21, 2014.*
12.1	Computation of Ratio of Earnings to Fixed Charges and Preferred Stock Dividends—WGL Holdings, Inc.
12.2	Computation of Ratio of Earnings to Fixed Charges and Preferred Stock Dividends—Washington Gas Light Company.
21	Subsidiaries of WGL Holdings, Inc.
23	Consent of Deloitte & Touche LLP.
24	Power of Attorney
31.1	Certification of Terry D. McCallister, the Chairman and Chief Executive Officer of WGL Holdings, Inc., pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2	Certification of Vincent L. Ammann, Jr., the Senior Vice President and Chief Financial Officer of WGL Holdings, Inc., pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.3	Certification of Terry D. McCallister, the Chairman and Chief Executive Officer of Washington Gas Light Company, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.4	Certification of Vincent L. Ammann, Jr., the Senior Vice President and Chief Financial Officer of Washington Gas Light Company, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32	Certification of Terry D. McCallister, the Chairman and Chief Executive Officer, and Vincent L. Ammann, Jr., the Senior Vice President and Chief Financial Officer, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS	XBRL Instance Document:
101.SCH	XBRL Schema Document:
101.CAL	XBRL Calculation Linkbase Document:
101.LAB	XBRL Labels Linkbase Document:
101.PRE	XBRL Presentation Linkbase Document:
101.DEF	XBRL Definition Linkbase Document:

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Washington Gas Light Company

Part IV

Item 15. Exhibits and Financial Statement Schedules (continued)

Schedule/ Exhibit	Description
	Exhibits Incorporated by Reference:
2	Plan of Merger between WGL Holdings, Inc. and Washington Gas Light Company, filed on Form S-4 dated February 2, 2000.
3	Articles of Incorporation & Bylaws:
	Washington Gas Light Company Charter, filed on Form S-3 dated July 21, 1995.
	WGL Holdings, Inc. Charter, filed on Form S-4 dated February 2, 2000.
	Bylaws of WGL Holdings, Inc. as amended on March 7, 2013, filed as Exhibit 3.1 to Form 8-K on March 13, 2013.
	Code of Conduct of WGL Holdings, Inc. as amended on September 25, 2013, filed as Exhibit 14.1 to Form 8-K on October 1, 2013.
	Code of Conduct of Washington Gas Light Company as amended on September 25, 2013, filed as Exhibit 14.1 to Form 8-K on October 1, 2013.
4	Instruments Defining the Rights of Security Holders including Indentures:
	Indenture, dated September 1, 1991 between Washington Gas Light Company and The Bank of New York, as Trustee, regarding issuance of unsecured notes, filed as an exhibit to Form 8-K on September 19, 1991.
	Supplemental Indenture, dated September 1, 1993 between Washington Gas Light Company and The Bank of New York, as Trustee, regarding the addition of a new section to the Indenture dated September 1, 1991, filed as an exhibit to Form 8-K on September 10, 1993.
10	Material Contracts
	Limited Liability Company Agreement of Meade Pipeline Co. LLC entered into on February 14, 2014, by and between WGL Midstream, Inc., COG Holdings LLC, Vega Midstream MPC LLC, River Road Interests LLC, and VED NPI I, LLC, filed as an exhibit to Form 10-Q for the quarter ended March 31, 2014.
	Construction and Ownership Agreement entered into on February 14, 2014, by and between Transcontinental Gas Pipe Line Company, LLC and Meade Pipeline Co. LLC, filed as an exhibit to Form 10-Q for the quarter ended March 31, 2014.
	Lease Agreement between Transcontinental Gas Pipe Line Company, LLC and Meade Pipeline Co. LLC, filed as an exhibit to Form 10-Q for the quarter ended March 31, 2014.
	Other Services Contracts
	Master Services Agreement, effective June 19, 2007, with Accenture LLP, related to business process outsourcing, and service technology enhancements, filed as Exhibit 10.1 to Form 10-Q for the quarter ended June 30, 2007. Portions of this exhibit were omitted pursuant to a request for confidential treatment submitted to the Securities and Exchange Commission.
	Gas transportation and storage contracts
	Amended Service Agreement, effective October 31, 2008, with Columbia Gas Transmission Company related to Firm Transportation Service, filed as Exhibit 10.1 to Form 10-K for the year ended September 30, 2010.
	Service Agreement, effective October 31, 2008, with Columbia Gas Transmission Company related to Firm Storage Service, filed as Exhibit 10.1 to Form 10-Q for the quarter ended June 30, 2009.
	Service Agreement, effective October 31, 2008, with Columbia Gas Transmission Company related to Firm Transportation Service, filed as Exhibit 10.2 to Form 10-Q for the quarter ended June 30, 2009.
	Service Agreement, effective October 31, 2008, with Columbia Gas Transmission Company related to Firm Transportation Service, filed as Exhibit 10.3 to Form 10-Q for the quarter ended June 30, 2009.
	Service Agreement, effective October 31, 2008, with Columbia Gas Transmission Company related to Firm Transportation Service, filed as Exhibit 10.4 to Form 10-Q for the quarter ended June 30, 2009.

151

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Washington Gas Light Company

Part IV

Item 15. Exhibits and Financial Statement Schedules (continued)

Schedule/ Exhibit	Description
	Service Agreement, effective April 1, 2007, with Hardy Storage Company related to Firm Storage Service, filed as Exhibit 10.1 to Form 10-K for the fiscal year ended September 30, 2007.
	Service Agreement, effective November 1, 2007, with Columbia Gas Transmission Company related to Firm Transportation Service, filed as Exhibit 10.2 to Form 10-K for the fiscal year ended September 30, 2007.
	Service Agreement, effective November 1, 2007, with Transcontinental Gas Pipe Line Corporation related to Firm Transportation Service, filed as Exhibit 10.3 to Form 10-K for the fiscal year ended September 30, 2007.
	Service Agreement, effective November 1, 2005, with Columbia Gulf Transmission Company related to Firm Transportation Service, filed as Exhibit 10.1 to Form 10-K for the fiscal year ended September 30, 2005.
	Service Agreement, effective November 1, 2005, with Columbia Gas Transmission Corporation related to Firm Storage Service (Agreement 85037), filed as Exhibit 10.2 to Form 10-K for the fiscal year ended September 30, 2005.
	Service Agreement, effective November 1, 2005, with Columbia Gas Transmission Corporation related to Storage Service (Agreement 85038), filed as Exhibit 10.3 to Form 10-K for the fiscal year ended September 30, 2005.
	Service Agreement, effective November 1, 2005, with Columbia Gas Transmission Corporation related to Firm Transportation Service (Agreement 85036), filed as Exhibit 10.4 to Form 10-K for the fiscal year ended September 30, 2005.
	Service Agreement, effective November 1, 2005, with Cove Point LNG FPS—2 related to Peaking Service, filed as Exhibit 10.5 to Form 10-K for the fiscal year ended September 30, 2005.
	Service Agreement, effective November 1, 2005, with Cove Point LNG FPS—3 related to Peaking Service, filed as Exhibit 10.6 to Form 10-K for the fiscal year ended September 30, 2005.
	Service Agreement, effective May 1, 2005, as amended, with Dominion Cove Point LNG, LP related to Firm Transportation Service, filed as Exhibit 10.2 to Form 10-K for the fiscal year ended September 30, 2004.
	Service Agreement, effective November 1, 2004, with Dominion Transmission Inc. related to Firm Transportation Service from the Mid Atlantic project, filed as Exhibit 10.5 to Form 10-K for the fiscal year ended September 30, 2004.
	Service Agreement, renegotiated and effective June 1, 2004, as amended, with Columbia Gas Transmission Corporation related to Firm Storage Service, filed as Exhibit 10.7 to Form 10-K for the fiscal year ended September 30, 2004. (Agreement 78844)
	Service Agreement, renegotiated and effective June 1, 2004, as amended, with Columbia Gas Transmission Corporation related to Firm Storage Service, filed as Exhibit 10.7 to Form 10-K for the fiscal year ended September 30, 2004. (Agreement 78845)
	Service Agreement, renegotiated and effective June 1, 2004, as amended, with Columbia Gas Transmission Corporation related to Firm Storage Service, filed as Exhibit 10.7 to Form 10-K for the fiscal year ended September 30, 2004. (Agreement 78846)
	Service Agreement, renegotiated and effective June 1, 2004, as amended, with Columbia Gas Transmission Corporation related to Storage Service filed as Exhibit 10.8 to Form 10-K for the fiscal year ended September 30, 2004. (Agreement 78838)
	Service Agreement, renegotiated and effective June 1, 2004, as amended, with Columbia Gas Transmission Corporation related to Storage Service filed as Exhibit 10.8 to Form 10-K for the fiscal year ended September 30, 2004. (Agreement 78839)
	Service Agreement, renegotiated and effective June 1, 2004, as amended, with Columbia Gas Transmission Corporation related to Storage Service filed as Exhibit 10.8 to Form 10-K for the fiscal year ended September 30, 2004. (Agreement 78840)

152

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Part IV

Item 15. Exhibits and Financial Statement Schedules (continued)

Schedule/ Exhibit	Description
	Service Agreement, renegotiated and effective June 1, 2004, as amended, with Columbia Gas Transmission Corporation related to Firm Transportation Service, filed as Exhibit 10.9 to Form 10-K for the fiscal year ended September 30, 2004. (Agreement 78834)
	Service Agreement, renegotiated and effective June 1, 2004, as amended, with Columbia Gas Transmission Corporation related to Firm Transportation Service, filed as Exhibit 10.9 to Form 10-K for the fiscal year ended September 30, 2004. (Agreement 78835)
	Service Agreement, renegotiated and effective June 1, 2004, as amended, with Columbia Gas Transmission Corporation related to Firm Transportation Service, filed as Exhibit 10.9 to Form 10-K for the fiscal year ended September 30, 2004. (Agreement 78836)
	Service Agreement, effective January 1, 1996, with Transcontinental Gas Pipe Line Corporation related to Firm Transportation Service, filed as Exhibit 10.11 to Form 10-K for the fiscal year ended September 30, 2004.
	Service Agreement effective November 1, 2002 with the Transcontinental Gas Pipe Line Corporation for the MarketLink Firm Transportation Capacity, filed as Exhibit 10.1 to Form 10-K for the fiscal year ended September 30, 2003.
	Service Agreement effective October 1, 1993 with Transcontinental Gas Pipe Line Corporation related to General Storage Service filed as Exhibit 10.3 to Form 10-K for the fiscal year ended September 30, 1993.
	Service Agreement effective October 1, 1993 with Dominion Transmission, Inc. related to Firm Transportation Service, filed as Exhibit 10.11 to Form 10-K for the fiscal year ended September 30, 1993.
	Service Agreement effective October 1, 1993 with Dominion Transmission, Inc. related to General Storage Service, filed as Exhibit 10.13 to Form 10-K for the fiscal year ended September 30, 1993.
	Service Agreement effective August 1, 1991 with Transcontinental Gas Pipe Line Corporation related to Washington Storage Service, filed as Exhibit 10.16 to Form 10-K for the fiscal year ended September 30, 1993.
	Management Contracts, Compensatory Plans or Arrangements with Executive Officers and Directors
	Washington Gas Light Company Form of Defined Contribution Supplemental Executive Retirement Plan filed as Exhibit 10.1 to Form 10-Q for the quarter ended December 31, 2009.*
	Washington Gas Light Company Form of Defined Contribution Restoration Plan filed as Exhibit 10.2 to Form 10-Q for the quarter ended December 31, 2009.*
	Washington Gas Light Company Form of Defined Benefit Restoration Plan filed as Exhibit 10.3 to Form 10-Q for the quarter ended December 31, 2009.*
	WGL Holdings, Inc. and Washington Gas Light Company Change in Control Severance Plan for Certain Executives, as amended on September 24, 2008, filed as Exhibit 10.1 to Form 10-K for the fiscal year ended September 30, 2008.*
	WGL Holdings, Inc. and Washington Gas Light Company Deferred Compensation Plan for Outside Directors, amended and restated effective January 1, 2005, as further amended on September 24, 2008, filed as Exhibit 10.1 to Form 10-K for the fiscal year ended September 30, 2008.*
	Washington Gas Light Company Supplemental Executive Retirement Plan, amended and restated effective January 1, 2005, as further amended on September 24, 2008, filed as Exhibit 10.1 to Form 10-K for the fiscal year ended September 30, 2008.*
	WGL Holdings, Inc. Omnibus Incentive Compensation Plan, filed as Exhibit 10.2 to Form 8-K dated December 21, 2006.*
	WGL Holdings, Inc. 1999 Incentive Compensation Plan, as amended and restated as of March 5, 2003, filed as Exhibit 10.15 to Form 10-K for the fiscal year ended September 30, 2004.*
	Form of Nonqualified Stock Option Award Agreement, filed as Exhibit 10.01 to Form 8-K dated October 5, 2004.*

WGL Holdings, Inc. and Washington Gas Light Company Deferred Compensation Plan for Outside Directors, adopted December 18, 1985, and amended as of November 1, 2000, filed as Exhibit 10.2 to Form 10-K in the fiscal year ended September 30, 2001.*

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Part IV

Item 15. Exhibits and Financial Statement Schedules (concluded)

Schedule/ Exhibit	Description
	Debt and Credit Agreements
	Indenture Agreement dated August 28, 2014, entered into by and between WGL Holdings, Inc. and The Bank of New York Mellon, as Trustee. Filed as Exhibit 4.1 to Form 8-K dated October 15, 2014.
	Form of Note Purchase Agreement dated November 2, 2009, entered into by and among Washington Gas Light Company and certain purchasers, for the issuance and sale by Washington Gas Light Company of $50 million of unsecured fixed rate notes due November 1, 2019. Filed as Exhibit 4.1 to Form 8-K dated November 5, 2009.
	Form of Note issued in connection with the Note Purchase Agreement dated November 2, 2009, by and among Washington Gas Light Company and certain purchasers, regarding the issuance and sale by Washington Gas Light Company of $50 million of unsecured fixed rate notes due November 1, 2019. Filed as Exhibit 4.2 to Form 8-K dated November 5, 2009.
	Form of Distribution Agreement, dated June 6, 2012, entered into by and among Washington Gas Light Company and BB&T Capital Markets, a division of Scott & Stringfellow, LLC, Mitsubishi UFJ Securities (USA), Inc., PNC Capital Markets LLC, TD Securities (USA) LLC, Wells Fargo Securities, LLC, The Williams Capital Group, L.P. and US Bancorp Investments, Inc. regarding the issuance and sale by Washington Gas Light Company of up to $450,000,000 of Medium-Term Notes, Series J. Filed as Exhibit 9.01 to Form 8-K dated June 13, 2012.
	Credit Agreement dated as of April 3, 2012 among WGL Holdings, Inc., the Lenders Parties Hereto, Wells Fargo Bank, National Association, as administrative agent; The Bank of Tokyo-Mitsubishi UFJ, Ltd. as syndication agent; Branch Banking and Trust Company and TD Bank, N.A., as documentation agents; and Wells Fargo Securities, LLC, The Bank of Tokyo-Mitsubishi UFJ, Ltd., BB&T Capital Markets and TD Bank, N.A. as joint lead arrangers and joint book runners, filed as Exhibit 10.1 to Form 10-Q for the quarter ended March 31, 2012.
	Credit Agreement dated as of April 3, 2012 among Washington Gas Light Company, the Lenders Parties Hereto, Wells Fargo Bank, National Association, as administrative agent; The Bank of Tokyo-Mitsubishi UFJ, Ltd. as syndication agent; Branch Banking and Trust Company and TD Bank, N.A., as documentation agents; and Wells Fargo Securities, LLC, The Bank of Tokyo-Mitsubishi UFJ, Ltd., BB&T Capital Markets and TD Bank, N.A. as joint lead arrangers and joint book runners, filed as Exhibit 10.2 to Form 10-Q for the quarter ended March 31, 2012.
	* This asterisk designates an agreement that is a compensatory plan or arrangement.

154

WGL Holdings, Inc. and Subsidiaries
Schedule II—Valuation and Qualifying Accounts and Reserves
Years Ended September 30, 2014, 2013 and 2012
	Balance at		Additions Charged To						Balance
	Beginning		Costs and		Other				at End of
(In thousands)	of Period		Expenses		Accounts(a)		Deductions(b)		Period
2014
Valuation and Qualifying Accounts Deducted from Assets in the Balance Sheet: Allowance for Doubtful Accounts	$	20,433	$	15,874	$	4,341	$	17,307	$     23,341
2013
Valuation and Qualifying Accounts Deducted from Assets in the Balance Sheet: Allowance for Doubtful Accounts	$	19,792	$	9,527	$	4,217	$	13,103	$     20,433
2012
Valuation and Qualifying Accounts Deducted from Assets in the Balance Sheet: Allowance for Doubtful Accounts	$	17,969	$	18,316	$	4,774	$	21,267	$     19,792
Notes:
(a) Recoveries on receivables previously written off as uncollectible and unclaimed customer deposits, overpayments, etc., not refundable.
(b) Includes deductions for purposes for which reserves were provided or revisions made of estimated exposure.

Washington Gas Light Company Schedule II—Valuation and Qualifying Accounts and Reserves Years Ended September 30, 2014, 2013 and 2012
	Balance at		Additions Charged To						Balance at
	Beginning		Costs and		Other				End of
(In thousands)	of Period		Expenses		Accounts(a)		Deductions(b)		Period
2014
Valuation and Qualifying Accounts Deducted from Assets in the Balance Sheet: Allowance for Doubtful Accounts	$	17,498	$	12,004	$	4,198	$	14,491	$     19,209
2013
Valuation and Qualifying Accounts Deducted from Assets in the Balance Sheet: Allowance for Doubtful Accounts	$	17,129	$	7,024	$	3,978	$	10,633	$     17,498
2012
Valuation and Qualifying Accounts Deducted from Assets in the Balance Sheet: Allowance for Doubtful Accounts	$	15,863	$	12,794	$	4,300	$	15,828	$     17,129
Notes:
(a) Recoveries on receivables previously written off as uncollectible and unclaimed customer deposits, overpayments, etc., not refundable.
(b) Includes deductions for purposes for which reserves were provided or revisions made of estimated exposure.

155

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrants have duly caused this report to be signed on their behalf by the undersigned, thereunto duly authorized.

WGL HOLDINGS, INC.
and
WASHINGTON GAS LIGHT COMPANY
(Co-registrants)
	/s/ Vincent L. Ammann, Jr.
Vincent L. Ammann, Jr.
Senior Vice President and
Chief Financial Officer

Date: November 21, 2014

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 registrants and in the capacities and on the dates indicated.

Signature		Title	Date
/s/ Terry D. McCallister		Chairman of the Board and Chief Executive Officer	November 21, 2014
(Terry D. McCallister)
/s/ Adrian P. Chapman		President and Chief Operating Officer	November 21, 2014
(Adrian P. Chapman)
/s/ Vincent L. Ammann, Jr.		Senior Vice President and Chief Financial Officer	November 21, 2014
(Vincent L. Ammann, Jr.)		(Principal Financial Officer)
/s/ William R. Ford		Vice President and Chief Accounting Officer	November 21, 2014
(William R. Ford)		(Principal Accounting Officer)
*		Director	November 21, 2014
(Michael D. Barnes)
*		Director	November 21, 2014
(George P. Clancy, Jr.)
*		Director	November 21, 2014
(James W. Dyke, Jr.)
*		Director	November 21, 2014
(Dale S. Rosenthal)
*		Director	November 21, 2014
(Nancy C. Floyd)
*		Director	November 21, 2014
(Linda R. Gooden)
*		Director	November 21, 2014
(James F. Lafond)
*		Director	November 21, 2014
(Debra L. Lee)
*By:	/s/ Vincent L. Ammann, Jr.		November 21, 2014
	(Vincent L. Ammann, Jr.)
	Attorney-in-Fact

156

WGL HOLDINGS, INC. and WASHINGTON GAS LIGHT COMPANY 2014 Form 10-K

Exhibit Index

Exhibit	Description
3	Bylaws of Washington Gas Light Company, as amended on September 24, 2014.
10.1	Form of Performance Share Award Agreement, as amended on October 21, 2014.
10.2	Form of Performance Units Award Agreement, as amended on October 21, 2014.
12.1	Computation of Ratio of Earnings to Fixed Charges and Preferred Stock Dividends—WGL Holdings, Inc.
12.2	Computation of Ratio of Earnings to Fixed Charges and Preferred Stock Dividends—Washington Gas Light Company.
21	Subsidiaries of WGL Holdings, Inc.
23	Consent of Deloitte & Touche LLP.
24	Power of Attorney
31.1	Certification of Terry D. McCallister, the Chairman and Chief Executive Officer of WGL Holdings, Inc., pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2	Certification of Vincent L. Ammann, Jr., the Senior Vice President and Chief Financial Officer of WGL Holdings, Inc., pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.3	Certification of Terry D. McCallister, the Chairman and Chief Executive Officer of Washington Gas Light Company, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.4	Certification of Vincent L. Ammann, Jr., the Senior Vice President and Chief Financial Officer of Washington Gas Light Company, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32	Certification of Terry D. McCallister, the Chairman and Chief Executive Officer, and Vincent L. Ammann, Jr., the Senior Vice President and Chief Financial Officer, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS	XBRL Instance Document:
101.SCH	XBRL Schema Document:
101.CAL	XBRL Calculation Linkbase Document:
101.LAB	XBRL Labels Linkbase Document:
101.PRE	XBRL Presentation Linkbase Document:
101.DEF	XBRL Definition Linkbase Document:

157

EX-3

Exhibit 3

WASHINGTON GAS LIGHT COMPANY

BYLAWS

ARTICLE I

Stockholders.

SECTION 1.   Annual Meeting.  The annual meeting of stockholders of Washington Gas Light Company (the Company) shall be held at such time and place within or without the District of Columbia as shall be determined by the Board of Directors and as shall be stated in the notice of the meeting. The meeting shall be held for the purpose of electing directors and for the transaction of such other business as properly may come before such meeting.

SECTION 2.   Special Meetings.  Special meetings of stockholders may be held upon call by the Chairman of the Board, the President, the Secretary, a majority of the Board of Directors, or a majority of the Executive Committee, and shall be called by the Chairman of the Board, the President or Secretary upon the request in writing of the holders of record of not less than one-tenth of all the outstanding shares of stock entitled by its terms to vote at such meeting, at such time and at such place within the District of Columbia as may be fixed in the call and stated in the notice setting forth such call. Such request by the stockholders and such notice shall state the purpose of the proposed meeting.

SECTION 3.   Notice of Meetings.   Notice of the time, place and purpose of every meeting of the stockholders, shall, except as otherwise required by law, be delivered personally or mailed at least ten (10) but not more than sixty (60) days prior to the date of such meeting to each stockholder of record entitled to vote at the meeting at his address as it appears on the records of the Company. Any meeting may be held without notice if all of the stockholders entitled to vote thereat are present in person or by proxy at the meeting, or if notice is waived by those not so present in person or by proxy.

Without limiting the manner by which notice otherwise may be given effectively to stockholders, any notice to stockholders given by the Company under any provision of the Virginia Stock Corporation Act (the “Virginia Act”) or the Business Corporation Act of the District of Columbia (the “D.C. Act”), the articles of incorporation, or these Bylaws shall be effective if given, either by a form of electronic transmission consented to by the stockholder to whom the notice is given, or by mail. Any such consent shall be revocable by the stockholder by written notice to the Company. Any such consent shall be deemed revoked if (i) the Company is unable to deliver by electronic transmission two consecutive notices given by the Company in accordance with such consent, and (ii) such inability becomes known to the Secretary or an Assistant Secretary of the Company or to the transfer agent or other person responsible for the giving of notice; provided, however, the inadvertent failure to treat such inability as a revocation shall not invalidate any meeting or other action.

Washington Gas Light Company Bylaws – effective September 24, 2014

Notice given pursuant to this Section 3 shall be deemed given: (1) if by facsimile telecommunication, when directed to a number at which the stockholder has consented to receive notice; (2) if by electronic mail, when directed to an electronic mail address at which the stockholder has consented to receive notice; (3) if by a posting on an electronic network together with separate notice to the stockholder of such specific posting, upon the later of (A) such posting and (B) the giving of such separate notice; or (4) if by any other form of electronic transmission, when directed to the stockholder. An affidavit of the Secretary or an Assistant Secretary or of the transfer agent or other agent of the Company that the notice has been given by a form of electronic transmission shall, in the absence of fraud, be prima facie evidence of the facts stated therein.

For purposes of these Bylaws, “electronic transmission” means any form of communication, not directly involving the physical transmission of paper, that creates a record that may be retained, retrieved and reviewed by a recipient thereof, and that may be directly reproduced in paper form by such a recipient through an automated process. If mailed, notice is given three (3) days after deposited in the United States mail, postage prepaid, directed to the stockholder at his address as it appears on the records of the Company.

Except as otherwise prohibited under the Virginia Act or D.C. Act and without limiting the manner by which notice otherwise may be given to stockholders, any notice to stockholders given by the Company under any provision of the Virginia Act or D.C. Act, the articles of incorporation or these Bylaws may be given by a single written notice to stockholders who share an address if consented to by the stockholders at the address to whom such notice is given. Such consent shall have been deemed to have been given if a stockholder fails to object in writing to the Company within sixty (60) days of having been given written notice by the Company of its intention to send the single notice in accordance with this paragraph. Any such consent shall be revocable by the stockholders by written notice to the Company.

SECTION 4.   Quorum.  At every meeting of the stockholders, the holders of record of a majority of the shares entitled to vote at the meeting, represented in person or by proxy, shall constitute a quorum. The vote of the majority of such quorum shall be necessary for the transaction of any business, unless otherwise provided by law or the articles of incorporation. If the meeting cannot be organized because a quorum has not attended, those present in person or by proxy may adjourn the meeting from time to time by vote of the holders of a majority of the shares represented thereat, but no other business shall be transacted at such meeting. At such adjourned meeting at which a quorum is present or represented, any business may be transacted that might have been transacted at the meeting as originally called.

SECTION 5.   Voting.  Unless otherwise provided by law or the articles of incorporation, every stockholder of record entitled to vote at any meeting of stockholders shall be entitled to one vote for every share of stock standing in the stockholder’s name on the records of the Company on the record date fixed as provided in these Bylaws. In the election of directors, all votes shall be cast by ballot and the persons having the greatest number of votes shall be the directors. On matters other than election of directors, votes may be cast in such manner as the Chairman of the meeting may designate.

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SECTION 6.   Inspectors.  The Board of Directors shall annually appoint two or more persons to act as inspectors or judges at any election of directors or vote conducted by ballot at any meeting of stockholders. Such inspectors or judges of election shall take charge of the polls and after the balloting shall make a certificate of the result of the vote taken. In case of a failure to appoint inspectors, or in case an inspector shall fail to attend, or refuse or be unable to serve, the Chairman of the meeting may appoint, or the stockholders may elect, an inspector or inspectors to act at such meeting. Such inspector or inspectors shall make a certificate of the result of the vote taken.

SECTION 7.   Conduct of Stockholders’ Meeting.  The following persons, in the order named, shall be named chair of the stockholders’ meeting and shall be entitled to call the meeting to order: (1) the Chairman of the Board, (2) the President of the Company, (3) the Lead Director, or (4) a Vice President of the Company. The chair shall determine the order of business and may establish rules for the conduct of the meeting. The Secretary of the Company, or in his absence any person appointed by the Chairman, shall act as Secretary of the meeting for organization purposes.

SECTION 8.   Record Date.   In lieu of closing the stock transfer books, the Board of Directors, in order to make a determination of stockholders entitled to notice of or to vote at any meeting, or to receive payment of any dividends or for any other proper purpose, may fix in advance a date, but not more than seventy (70) days in advance, as a record date for such determination, and in such case only stockholders of record on the date so fixed shall be entitled to notice of, and to vote at, such meeting, or to receive payment of such dividend, or to exercise such other rights, as the case may be, notwithstanding any transfer of stock on the books of the Company after such date. A determination of stockholders of record entitled to notice of or to vote at a meeting of stockholders shall apply to any adjournment of the meeting; provided, however, that the Board of Directors may fix a new record date for the adjourned meeting. If the Board of Directors does not fix a record date as aforesaid, such date shall be as provided by law.

SECTION 9.   Notice of Business.   At any meeting of the stockholders, only such business shall be conducted as shall have been brought before the meeting (1) by or at the direction of the Board of Directors or (2) by any stockholder of the Company who is a stockholder of record at the time of giving of the notice as provided for in this Section 9, who shall be entitled to vote at such meeting and who complies with the following procedures:

Requirement of Timely Notice.  At any meeting of the stockholders, only such business shall be conducted as shall have been properly brought before the meeting. To be properly brought before a meeting, business must be: (1) specified in the notice of meeting (or any supplement thereto) given by or at the direction of the Board of Directors, (2) otherwise properly brought before the meeting by or at the direction of the Board of Directors, or (3) otherwise properly brought before the meeting by a stockholder. The foregoing clause (3) shall be the exclusive means for a stockholder to propose business at an annual meeting of stockholders. In addition to any other applicable requirements for business to be properly brought before a meeting by a stockholder, the

Washington Gas Light Company Bylaws – effective September 24, 2014

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stockholder must have given timely notice thereof in writing to the Secretary. To be timely, a stockholder’s notice must be delivered to or mailed and received by the Secretary at the principal executive office of the Company not less than sixty (60) days prior to the scheduled date of the meeting; provided, however, if no notice is given and no public announcement is made to the stockholders regarding the date of the meeting at least 75 days prior to the meeting, the stockholder’s notice shall be valid if delivered to or mailed and received by the Secretary at the principal executive office of the Company not more than fifteen (15) days following the day on which the notice or public announcement of the date of the meeting was given or made.

In the case of a special meeting, to be timely, a stockholder’s notice to the secretary must be so received at the principal executive offices of the Company not later than the close of business on the tenth (10th) day following the day on which such notice of the date of the special meeting was mailed or such public disclosure of the date of the special meeting was made, whichever first occurs. In no event shall any postponement, deferral or adjournment of an annual meeting or special meeting or the announcement thereof commence a new time period for the giving of timely notice as described above.

Contents of Notice.  Other than with respect to stockholder proposals relating to director nomination(s), which requirements are set forth in Section 2 of Article II, a stockholder’s notice to the Secretary shall set forth as to each item of business that the stockholder proposes to bring before the meeting: (1) a brief description of the business desired to be brought before the meeting, the reasons for conducting such business at the meeting and, in the event that such business includes a proposal to amend either the articles of incorporation or these Bylaws, the language of the proposed amendment, (2) the name and record address, as they appear on the Company’s books, of the stockholder proposing such business, (3) the class and number of shares of capital stock of the Company that are beneficially owned by such stockholder, (4) any material interest (financial or other) of such stockholder in such business, and (5) whether and the extent to which such stockholder or Stockholder Associated Person (as defined below) has direct or indirect beneficial ownership of any option, warrant, convertible security, stock appreciation right or similar right with an exercise or conversion privilege or a settlement payment or mechanism at a price related to any class or series of shares of the Company, whether or not such instrument or right shall be subject to settlement in the underlying class or series of capital stock of the Company or otherwise, or any other direct or indirect opportunity to profit or share in any profit derived from any increase or decrease in the value of shares of the Company (a “Derivative Instrument”), if any, as of the date of such notice, including without limitation any such interests held by members of such stockholder’s immediate family sharing the same household (which information shall be supplemented as of the record date by such stockholder and beneficial owner, if any, and delivered to and received by the Secretary not later than ten (10) days after the record date for the meeting). For purposes of this Section 9 and Section 2 of Article II, “Stockholder Associated Person” of any stockholder shall mean: (i) any person controlling or controlled by, directly or indirectly, or acting in concert with, such stockholder, (ii) any beneficial owner of shares of stock of the Company owned of record or beneficially by such stockholder and (iii) any person controlling, controlled by or under common control with such Stockholder Associated Person.

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Updates and Supplements to Notices. Any stockholder providing notice under this Section 9 shall further update and supplement such notice, if necessary, so that the information provided or required to be provided in such notice pursuant to this Section 9 shall be true and correct as of the record date for the meeting and as of the date that is ten (10) business days prior to the meeting or any postponement, deferral or adjournment thereof, and such update and supplement shall be delivered to, or mailed and received by, the Secretary at the principal executive offices of the Company not later than five (5) business days after the record date for the meeting (in the case of the update and supplement required to be made as of the record date), and not later than eight (8) business days prior to the date for the meeting, if practicable (or, if not practicable, on the first practicable date prior to any postponement, deferral or adjournment thereof) (in the case of the update and supplement required to be made as of ten (10) business days prior to the meeting or any postponement, deferral or adjournment thereof).

Compliance with Bylaws.   Notwithstanding anything in these Bylaws to the contrary, no business shall be conducted at a stockholders’ meeting except in accordance with the procedures set forth in this Section 9. The chairman of the meeting shall, if the facts warrant, determine and declare to the meeting that the business was not properly brought before the meeting and in accordance with the provisions of these Bylaws, and if he should so determine, he shall so declare to the meeting and any such business not properly brought before the meeting shall not be transacted at the meeting. Notwithstanding the foregoing provisions of this Section 9, a stockholder shall also comply with all applicable requirements of the Securities Exchange Act of 1934, as amended (the Exchange Act), and the rules and regulations thereunder with respect to the matters set forth in this Section 9.

Effective Date of Stockholder Business.   Notwithstanding anything in these Bylaws to the contrary, no business brought before a meeting of the stockholders by a stockholder shall become effective until the final termination of any proceeding which may have been commenced in any court of competent jurisdiction for an adjudication of any legal issues incident to determining the validity of such business and the procedure pursuant to which it was brought before the stockholders, unless and until such court shall have determined that such proceedings are not being pursued expeditiously and in good faith.

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ARTICLE II

Board of Directors.

SECTION 1.   Number, Powers, Term of Office, Quorum, Lead Director.  The Board of Directors of the Company shall consist of nine persons. The Board of Directors may exercise all the powers of the Company and do all acts and things which are proper to be done by the Company which are not by law or by these Bylaws directed or required to be exercised or done by the stockholders. The members of the Board of Directors shall be elected at the annual meeting of stockholders and shall hold office until the next succeeding annual meeting, or until their successors shall be elected and shall qualify. A majority of the number of directors fixed by the Bylaws shall constitute a quorum for the transaction of business. The action of a majority of the directors present at any lawful meeting at which there is a quorum shall, except as otherwise provided by law or by these Bylaws, be the action of the Board. The Board of Directors shall have a Lead Director, who shall be an independent director, not an employee of the Company. The powers and responsibilities of the Lead Director shall be established by the Board of Directors and shall be set forth in the Corporate Governance Guidelines of the Company. The powers and responsibilities of the Lead Director may be modified from time to time in the discretion of the Board of Directors.

SECTION 2.   Election.  Except as provided in Section 3 of Article II, directors shall be elected by the stockholders of the Company pursuant to the procedures enumerated below:

Eligible Persons.  In addition to any other applicable requirements, only persons who are nominated in accordance with the following procedures shall be eligible for election by the stockholders as directors of the Company.

Nominations.  Nominations of persons for election as directors of the Company may be made at a meeting of stockholders (1) by or at the direction of the Board of Directors, (2) by any nominating committee or person appointed by the Board of Directors or (3) by any stockholder of the Company entitled to vote for the election of directors at the meeting who complies with the notice procedures set forth in this Section 2.

Nomination by Directors or Nominating Committee.  Nominations made by or at the direction of the Board of Directors or the nominating committee or person appointed by the Board of Directors may be made at any time prior to the stockholders’ meeting. The Board of Directors must send notice of nominations to the stockholders together with the notice of the meeting of the stockholders; provided, however, if the nominations are made after the notice of the meeting has been mailed, the Board of Directors must send notice of its nominations to the stockholders as soon as practicable.

Nomination by Stockholders.  Nominations, other than those made by or at the direction of the Board of Directors or the nominating committee or person appointed by

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the Board of Directors, shall be made pursuant to timely notice in writing to the Secretary, which shall be the exclusive means for a stockholder to make nominations. In order for a stockholder to nominate a candidate to the Board of Directors at an annual or special meeting, he or she must comply with the procedures set forth in this Section 2; provided, however, that the stockholder must also comply with all applicable requirements of the Exchange Act and the rules and regulations thereunder with respect to the matters set forth in these Bylaws. To be timely, a stockholder’s notice must be delivered to or mailed and received by the Secretary at the principal executive office of the Company not less than sixty (60) days prior to the scheduled date of the meeting; provided, however, if no notice is given and no public announcement is made to the stockholders regarding the date of the meeting at least 75 days prior to the meeting, the stockholder’s notice shall be valid if delivered to or mailed and received by the Secretary at the principal executive office of the Company not more than fifteen (15) days following the day on which the notice or public announcement of the date of the meeting was given or made. In no event shall any postponements, deferrals or adjournments of an annual meeting or special meeting or the announcement thereof commence a new time period for the giving of a stockholder’s notice as described above.

Contents of Notice.  Nominations, other than those made by or at the direction of the Board of Directors or the nominating committee or person appointed by the Board of Directors, shall set forth:

(1) as to each person whom the stockholder proposes to nominate for election or reelection as a director, (a) the name, age, business address and residential address of the person, (b) the principal occupation or employment of the person (c) the class and number of shares of capital stock of the Company that are beneficially owned by the person, (d) written consent by the person, agreeing to serve as director if elected, (e) a description of all arrangements or understandings between the person and the stockholder regarding the nomination, (f) a description of all arrangements or understandings between the person and any other person or persons (naming such persons) regarding the nomination, (g) all information relating to the person that is required to be disclosed in solicitations for proxies for election of directors pursuant to Regulation 14A under the Exchange Act, and (h) such other information as the Company may reasonably request to determine the eligibility of such proposed nominee to serve as director of the Company;

(2) as to the stockholder giving the notice, (a) the name, business address and residential address of the stockholder giving the notice, (b) the class and number of shares of capital stock of the Company that are beneficially owned by such stockholder, (c) a description of all arrangements or understandings between the stockholder and the nominee regarding the nomination, and (d) a description of all arrangements or understandings between the stockholder and any other person or persons (naming such persons) regarding the nomination; and

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(3) as to the stockholder giving the notice and any Stockholder Associated Person (as defined in Section 9 of Article I), whether and to the extent to which any Derivative Instrument (as defined in Section 9 of Article I) is directly or indirectly beneficially owned, as of the date of such notice, including without limitation any such interests held by members of such stockholder’s immediate family sharing the same household (which information shall be supplemented as of the record date by such stockholder and beneficial owner, if any, and delivered to and received by the Secretary not later than ten (10) days after the record date for the meeting).

  Updates and Supplements to Notices.  The Company may require any proposed nominee to furnish such other information as may reasonably be required by the Company to determine the eligibility of such proposed nominee to serve as a director of the Company. Any stockholder providing notice under this Section 2 shall further update and supplement such notice, if necessary, so that the information provided or required to be provided in such notice pursuant to this Section 2 shall be true and correct as of the record date for the meeting and as of the date that is ten (10) business days prior to the meeting or any postponement, deferral or adjournment thereof, and such update and supplement shall be delivered to, or mailed and received by, the Secretary at the principal executive offices of the Company not later than five (5) business days after the record date for the meeting (in the case of the update and supplement required to be made as of the record date), and not later than eight (8) business days prior to the date for the meeting, if practicable (or, if not practicable, on the first practicable date prior to any postponement, deferral or adjournment thereof) (in the case of the update and supplement required to be made as of ten (10) business days prior to the meeting or any postponement, deferral or adjournment thereof).

  Compliance with Bylaws.   No person shall be eligible for election by the stockholders as a director of the Company unless nominated in accordance with the procedures set forth in this Section 2 of the Bylaws. The Chairman of the Board of Directors shall, if the facts warrant, determine and declare prior to the meeting of stockholders that the nomination was not made in accordance with the foregoing procedure, and if he should so determine, he shall so inform the nominee and the stockholder who nominated the nominee as soon as practicable and the defective nomination shall be disregarded.

  Effective Date of Election of Director.  Notwithstanding anything in these Bylaws to the contrary, no election of a director nominated by a stockholder shall become effective until the final termination of any proceeding which may have been commenced in any court of competent jurisdiction for an adjudication of any legal issues incident to determining the procedure pursuant to which the nomination of such director was brought before the stockholders, unless and until such court shall have determined that such proceedings are not being pursued expeditiously and in good faith.

SECTION 3. Vacancies.  If a vacancy occurs on the board of directors, including a vacancy resulting from an increase in the number of directors:

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(a) the stockholders may fill the vacancy;

(b) the board of directors may fill the vacancy; or

(c) if the directors remaining in office constitute fewer than a quorum of the board, they may fill the vacancy by the affirmative vote of a majority of directors remaining in office.

A vacancy that will occur at a specific later date, by reason of a resignation effective at a later date, may be filled before the vacancy occurs but the new director may not take office until the vacancy occurs.

A director elected to fill a vacancy shall be elected for the unexpired term of his or her predecessor in office. A director filling a position resulting from an increase in the number of directors shall hold office until the next annual meeting of stockholders and until his or her successor is elected and qualified.

SECTION 4.  Meetings.  Regular meetings of the Board shall be held at the office of the Company in the District of Columbia at times fixed by resolution of the Board of Directors. Notice of such meetings need not be given.

Special meetings of the Board may be called by the Chairman of the Board, the President of the Company, the Lead Director or by any two directors. The Lead Director may call meetings of the independent directors, who shall not be employees of the Company. At least two days’ notice of all special meetings of the Board shall be given to each director personally by telegraphic or written notice. Any meeting may be held without notice if all of the directors are present, or if those not present waive notice of the meeting by telegram or in writing. Special meetings of the Board of Directors may be held within or without the District of Columbia.

SECTION 5.  Committees.  The Board of Directors shall, by resolution or resolutions passed by a majority of the whole Board, designate an Executive Committee, to consist of the Chief Executive Officer of the Company who may be the Chairman of the Board, or the President and three additional members, and not fewer than three alternates to serve at the call of the Chief Executive Officer in case of the unavoidable absence of one of the regular members, to be elected from the Board of Directors. The Executive Committee shall, when the Board is not in session, have and may exercise all of the authority of the Board of Directors in the management of the business and affairs of the Company.

The Board of Directors may appoint other committees, standing or special, from time to time, from among their own number, or otherwise, and confer powers on such committees, and revoke such powers and terminate the existence of such committees at its pleasure.

A majority of the members of any such committee shall constitute a quorum for the purpose of fixing the time and place of its meetings, unless the Board shall otherwise provide. All action taken by any such committee shall be reported to the Board at its meeting next succeeding such action.

Washington Gas Light Company Bylaws – effective September 24, 2014

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SECTION 6.  Compensation of Directors. The Board of Directors shall fix the fee to be paid to each director for attendance at any meeting of the Board or of any committee thereof, and may, in its discretion, authorize payment to directors of traveling expenses incurred in attending any such meeting.

SECTION 7.  Removal. Any directors may be removed from office at any time, with or without cause, and another be elected in his place, by the vote of the holders of record of a majority of the outstanding shares of stock of the Company (of the class or classes by which such director was elected) entitled to vote thereon, at a special meeting of stockholders called for such purpose.

ARTICLE III

Officers.

SECTION 1.  Officers. The officers of the Company shall be elected by the Board of Directors and shall consist of a Chairman of the Board, a President, a Secretary, a Treasurer, and one or more Vice Presidents, and such other officers as the Board from time to time shall elect, with such duties as the Board shall deem necessary to conduct the business of the Company. Any officer may hold two or more offices (including those of the Chairman of the Board and President) except that the offices of President and Secretary may not be held by the same person. The Chairman of the Board shall be a director; other officers, including any Vice Chairman and the President, may be, but are not required to be, Directors.

SECTION 2.  Term of Office; Removal. In the absence of a special contract, all officers shall hold their respective offices for one year or until their successors shall have been duly elected and qualified, but they or any of them may be removed from their respective offices on a vote by a majority of the Board.

SECTION 3.  Powers and Duties. The officers of the Company shall have such powers and duties as generally pertain to their offices, respectively, as well as such powers and duties as from time to time shall be conferred by the Board of Directors and/or by the Executive Committee. In the absence of the Chairman of the Board, if any, the Lead Director shall preside at the meetings of the Board of Directors. In the absence of both the Chairman of the Board and the Lead Director, and provided a quorum is present, the senior member of the Board present, in terms of service on the Board, shall serve as Chairman pro tem of the meeting.

SECTION 4.  Salaries. The salaries of all executive officers of the Company shall be determined and fixed by the Board of Directors, or pursuant to such authority as the Board may from time to time prescribe.

Washington Gas Light Company Bylaws – effective September 24, 2014

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ARTICLE III-A

Indemnification of Directors and Officers.

SECTION 1.  With respect to a Company officer, director, or employee, the Company shall indemnify, and with respect to any other individual the Company may indemnify, any person who was or is a party or is threatened to be made a party to any threatened, pending or completed action, suit or proceeding (an “Action”), whether civil, criminal, administrative, arbitrative or investigative (including an action by or in the right of the Company) by reason of the fact the person is or was a director, officer, employee, or agent of the Company, or is or was serving at the request of the Company as a director, officer, employee, or agent of another corporation, partnership, joint venture, trust or other enterprise, against expenses (including attorneys’ fees), judgments, fines and amounts paid in settlement actually and reasonably incurred by that person in connection with such Action; except in relation to matters as to which the person shall be finally adjudged in such Action to have knowingly violated the criminal law or be liable for willful misconduct in the performance of the person’s duty to the Company. The termination of any Action by judgment, order, settlement, conviction, or upon a plea of nolo contendere or its equivalent, shall not of itself create a presumption that the person was guilty of willful misconduct.

Any indemnification (unless ordered by a court) shall be made by the Company only as authorized in the specific case upon a determination that indemnification of the director, officer, employee or agent is proper in the circumstance because the person has met the applicable standard of conduct set forth above. In the case of any director, such determination shall be made: (1) by the Board of Directors by a majority vote of a quorum consisting of directors who were not parties to such Action; or (2) if such a quorum is not obtainable, by majority vote of a committee duly designated by the Board of Directors (in which designation directors who are parties may participate) consisting solely of two or more directors not at the time parties to the proceeding; or (3) by special legal counsel selected by the Board of Directors or its committee in the manner prescribed by clause (1) or (2) of this paragraph, or if such a quorum is not obtainable and such a committee cannot be designated, by majority vote of the Board of Directors, in which selection directors who are parties may participate; or (4) by vote of the stockholders, in which vote shares owned by or voted under the control of directors, officers and employees who are at the time parties to the Action may not be voted. In the case of any officer, employee, or agent other than a director, such determination may be made (i) by the Board of Directors or a committee thereof; (ii) by the Chairman of the Board of the Company or, if the Chairman is a party to such Action, the President of the Company, or (iii) such other officer of the Company, not a party to such Action, as such person specified in clause (i) or (ii) of this paragraph may designate. Authorization of indemnification and evaluation as to reasonableness of expenses shall be made in the same manner as the determination that indemnification is permissible, except that if the determination is made by special legal counsel, authorization of indemnification and evaluation as to reasonableness of expenses shall be made by those entitled hereunder to select such legal counsel.

Washington Gas Light Company Bylaws – effective September 24, 2014

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Expenses incurred in defending an Action for which indemnification may be available hereunder shall be paid by the Company in advance of the final disposition of such Action as authorized in the manner provided in the preceding paragraph, subject to execution by the person being indemnified of a written undertaking to repay such amount if and to the extent that it shall ultimately be determined by a court that such indemnification by the Company is not permitted under applicable law.

It is the intention of the Company that the indemnification set forth in this Section of Article III-A, shall be applied to no less extent than the maximum indemnification permitted by law. In the event that any right to indemnification or other right hereunder may be deemed to be unenforceable or invalid, in whole or in part, such unenforceability or invalidity shall not affect any other right hereunder, or any right to the extent that is not deemed to be unenforceable. The indemnification provided herein shall be in addition to, and not exclusive of, any other rights to which those indemnified may be entitled under any Bylaw, agreement, vote of stockholders, or otherwise, and shall continue as to a person who has ceased to be a director, officer, employee, or agent and inure to the benefit of such person’s heirs, executors, and administrators.

SECTION 2.  In any proceeding brought by a stockholder in the right of the Company or brought by or on behalf of the stockholders of the Company, no monetary damages shall be assessed against an officer or director. The liability of an officer or director shall not be limited as provided in this section if the officer or director engaged in willful misconduct or a knowing violation of the criminal law or of any federal or state securities law.

ARTICLE IV

Checks, Notes, Etc.

SECTION 1.  All checks and drafts on the Company’s bank accounts and all bills of exchange and promissory notes, and all acceptances, obligations and other instruments for the payment of money, shall be signed by such officer or officers, agent or agents, as shall be thereunto authorized from time to time by the Board of Directors.

SECTION 2.  Shares of stock and other interests in other corporations or associations shall be voted by such officer or officers as the Board of Directors may designate.

SECTION 3.  Except as the Board of Directors shall otherwise provide, all contracts expressly approved by the Board shall be signed on behalf of the Company by the Chairman of the Board, the President, or a Vice President.

Washington Gas Light Company Bylaws – effective September 24, 2014

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ARTICLE V

Capital Stock.

SECTION 1.  Certificates for shares.    Unless otherwise authorized by the Board of Directors, the interest of each stockholder of the Company shall be evidenced by a certificate or certificates for shares of stock in such form as required by law and as the Board of Directors may from time to time prescribe. The Board of Directors may authorize the issue of some or all of the shares of any or all of its classes or series without certificates. The certificates of stock shall be signed by the President or a Vice President and the Secretary or an Assistant Secretary and sealed with the seal of the Company. Such seal may be a facsimile.

Where any such certificate is countersigned by a transfer agent other than the Company, or an employee of the Company, or is countersigned by a transfer clerk and is registered by a registrar, the signatures of the President or Vice President and the Secretary or Assistant Secretary may be facsimiles.

In case any officer who has signed, or whose facsimile signature has been placed upon such certificate, shall have ceased to be such officer before such certificate is issued, it may nevertheless be issued by the Company with the same effect as if such officer had not ceased to hold such office at the date of its issue.

SECTION 2.  Transfer of Shares.    The shares of stock of the Company shall be transferable on the books of the Company by the holders thereof in person or by duly authorized attorney, upon surrender and cancellation of certificates for a like number of shares, with duly executed assignment and power of transfer endorsed thereon or attached thereto, and with such proof of the authenticity of the signatures as the Company or its agents may reasonably require.

SECTION 3.  Lost, Stolen or Destroyed Certificates.  No certificate of stock claimed to have been lost, destroyed or stolen shall be replaced by the Company with a new certificate of stock until the holder thereof has produced evidence of such loss, destruction or theft, and has furnished indemnification to the Company and its agents to such extent and in such manner as the proper officers or the Board of Directors may from time to time prescribe.

ARTICLE VI

Corporate Records.

SECTION 1.  Where Kept.  The books, records and papers belonging to the business of the Company, and the corporate seal, shall be kept at the office of the Company in the District of Columbia.

Washington Gas Light Company Bylaws – effective September 24, 2014

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SECTION 2.  Inspection.  Any stockholder or stockholders, who shall have been such for at least six months, or who shall be the holder or holders of record of at least five percent of all the outstanding shares of stock of the Company, desiring to inspect the books or records of the Company, shall present to the Board of Directors or the Executive Committee an application for such inspection, specifying the particular books or records to be inspected and the purpose for which such inspection is desired. If, upon such application, the Board of Directors or Executive Committee deems such inspection is sought for a legitimate purpose connected with the interest of the applicant as a stockholder of the Company, such application shall be granted and a time and place for the inspection shall be specified. The stock and transfer books of the Company shall at all times, during business hours, be open to the inspection of stockholders. The Board of Directors shall have the power from time to time to establish general regulations conferring upon stockholders such further rights with respect to inspection of books and records of the Company as the Board shall deem proper.

ARTICLE VII

Fiscal Year.

The fiscal year of the Company shall begin on the 1st day of October in each year and shall end on the 30th day of September following.

ARTICLE VIII

General Provisions.

SECTION 1.  Corporate Seal.    The seal of the Company shall be circular in form and there shall be inscribed thereon -- Washington Gas Light Company -- a Corporation of the District of Columbia and Virginia -- Originally Chartered by Congress in 1848.

SECTION 2.  Severability.  Any determination that any provision of these Bylaws is for any reason inapplicable, illegal or ineffective shall not affect or invalidate any other provision of these Bylaws.

ARTICLE IX

Amendments.

SECTION 1.  By the Board of Directors.  The Board of Directors shall have power to make and alter (unless the stockholders shall in any particular instance have otherwise prescribed) any Bylaws of the Company. Such action may be taken at any meeting of the Board by the affirmative vote of a majority of the total number of directors, provided that notice of the proposed change shall have been given to all directors prior to the meeting, or that all of the directors shall be present at the meeting.

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SECTION 2.  By the Stockholders. Any Bylaws made or altered by the Board of Directors may be altered or repealed at any regular meeting of the stockholders, or at any special meeting of the stockholders, provided notice of such action shall have been properly brought before such meeting in a manner provided in these Bylaws.

Washington Gas Light Company Bylaws – effective September 24, 2014

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EX-10.1

Exhibit 10.1

 EXHIBIT A  

 PERFORMANCE SHARE GRANT #18  

WGL Holdings, Inc.

Omnibus Incentive Compensation Plan

Performance Shares (Series #18) Award

Terms and Conditions

This document sets forth the terms and conditions related to the Series #18 grant of performance share awards under the WGL Holdings, Inc. Omnibus Incentive Compensation Plan (the “Plan”). The following terms have the meanings ascribed below:

“Award Agreement” means the agreement between an award recipient and WGL Holdings, Inc. relating to the grant of performance shares subject to the terms of the WGL Holdings, Inc. Omnibus Incentive Compensation Plan and this document.

“Company” means WGL Holdings, Inc., a Virginia corporation.

“Participant” means a person that has been awarded Performance Shares subject to the terms and conditions set forth in this document and the WGL Holdings, Inc. Omnibus Incentive Compensation Plan.

“Performance Shares” means the target number of performance shares awarded pursuant to an Award Agreement.

“Performance Period” means October 1, 2014 through September 30, 2017.

“Performance Measure” means the annualized total shareholder return (as determined below) compared to the peer group shown on Schedule 1 attached hereto (the “Performance Measure”).

“Plan” means the WGL Holdings, Inc. Omnibus Incentive Compensation Plan.

The Plan provides a complete description of the terms and conditions governing the Performance Shares. If there is any inconsistency between the terms of this document and the terms of the Plan, the Plan’s terms shall completely supersede and replace the conflicting terms of this document. All capitalized terms have the meanings ascribed to them in the Plan, unless otherwise indicated herein.

1.        Value of Performance Shares.  Each Performance Share represents and has a value equal to one share of common stock (“Stock”) of the Company.

This document constitutes part of a prospectus covering securities which have been registered under the Securities Act of 1933.                                                                                                  October 1, 2014

2.        Performance Shares Payout and Total Shareholder Return Performance Measure.

The number of Performance Shares to be earned pursuant to an Award Agreement is based upon the Company’s Total Shareholder Return (as defined below) as compared to the Total Shareholder Return of the Company’s peer group (the peer group is identified on Schedule 1 attached hereto) during the Performance Period. The determination of Total Shareholder Return is described below.

Total Shareholder             Return	=	Change in Stock Price + Dividends Paid
		Beginning Stock Price

“Beginning Stock Price” means the average closing prices as reported on the New York Stock Exchange (the “NYSE”) of one share of the Stock for the thirty (30) trading days ending immediately prior to the first calendar day of the Performance Period. “Ending Stock Price” means the price of one share of Stock as determined at a particular date during the Performance Period. “Change in Stock Price” means the difference between the Beginning Stock Price and the Ending Stock Price. “Dividends Paid” means the total of all dividends paid on one share of stock during the Performance Period, provided that dividends shall be treated as though they are reinvested at the end of each calendar quarter. The Company’s Total Shareholder Return will be calculated at the end of each of the four fiscal quarters of the third fiscal year of the Performance Period and a hypothetical payout calculated for each quarter. The results of the four quarterly payouts will be averaged to determine the final payout for the Performance Period.

In connection with the Total Shareholder Return determination (as described above), the Company’s “Percentile Rank” shall be determined as follows:

Percentile         Rank	=	Company Rank (from the bottom)
		Total number of companies in peer group including the Company

“Company Rank” shall be determined by listing from highest Total Shareholder Return to lowest Total Shareholder Return each company in the peer group (including the Company) and counting up from the company with the lowest Total Shareholder Return. The percent of Performance Shares earned is determined based on the following chart:

Company’s Percentile Rank	Percent of     Target Award     Earned
90th		200%
70th		150%
50th		100%
25th		50%
Below 25th percentile and WGL dividend increases at least 9% over 3-year period		25%
Below 25th percentile and dividend test not met		0%

Interpolation shall be used to determine the percent of target award earned in the event the Company’s Percentile Rank does not fall directly on one of the ranks listed in the foregoing chart.

3.        Change or Termination of Employment or Service: For purposes of this Section 3, the term “Employer” means the Company or the Company’s subsidiary that employs the Participant, or to which the Participant provides services, on the effective date of the grant. Except as provided below, and subject to the provisions of Section 4 relating to a Change of Control, a Participant is eligible for payment of earned Performance Shares, as specified in paragraph 2, only if the Participant’s employment or service with the Employer continues through the end of the Performance Period, provided however that, a Participant that is an employee of the Company will not be eligible for the payment of earned Performance Shares if the Participant has been demoted from the position he or she held at the date of grant to a position that is below the management level of “director”. Further, a Participant will not be eligible for payment of earned Performance Shares if he or she is suspended from employment with the Employer as of the date of the end of the Performance Period.

Subject to the provisions of Section 4 of this Agreement, if a Participant terminates employment or services with the Employer prior to the end of the Performance Period for any reason, including voluntary or involuntary termination, death, disability or retirement, the Human Resources Committee of the Board of Directors of the Company (the “Committee”), in its sole discretion, may determine that the Participant shall be eligible for that proportion of the number of Performance Shares earned under Section 2 for such Performance Period that his or her number of full months of participation during the Performance Period bears to the total number of months in the Performance Period. In the event of the death of the Participant, the Participant’s designated beneficiary or estate shall be entitled to the Performance Shares under the same conditions as would have been applicable to the Participant.

4.        Change of Control.   In the event of a Change of Control, as defined in the Plan, the number of Performance Shares shall vest pursuant to the terms of the Company’s Change in Control Policy.

5.        Dividends.     The Participant has no right to any dividends with respect to the Performance Shares until the Performance Shares are issued by the Company and delivered to the Participant following the completion of the Performance Period and achievement of the Performance Measure.

6.        Rights as a Stockholder.      The Participant shall have no rights as a stockholder of the Company with respect to the Performance Shares until the Performance Shares have been issued and delivered to the Participant.

7.        Form and Timing of Delivery of Performance Shares.    Delivery of earned Performance Shares to the Participant shall be made in shares of Company Stock. Performance Shares shall be issued to the Participant as promptly as practicable following the close of the Performance Period.

8.        Adjustments.  Subject to Section 4(d) and 8(e) of the Plan, if the Committee determines that any recapitalization, forward or reverse split, reorganization, merger, consolidation, spin-off, combination, repurchase, exchange of stock, stock or cash dividend, other distribution, liquidation, dissolution or other similar corporate transaction or event affects the Stock such that an adjustment is appropriate in order to prevent dilution or enlargement of the rights of Participants, then the Committee shall, in such manner as it may deem equitable, adjust any of all of the certain specified terms of any Award Agreement. These adjustments may include, among other adjustments, adjustments to the number and kind of shares of stock relating to an Award Agreement (or, if deemed appropriate, the Committee may make provisions for a cash payment with respect to an Award Agreement). In addition, the Committee is authorized to make adjustments in the terms and conditions of, and the criteria of any grant or award under the Plan (including, without limitation, cancellation of outstanding awards or substitution of awards using stock of a successor or other entity) in recognition of unusual or nonrecurring events (including, among other matters, events constituting a Change of Control) affecting the Company or any subsidiary of the Company or the financial statements of the Company or any of its subsidiaries, or in response to changes in applicable laws, regulations or accounting principles.

9.        Tax Withholding.    The Company may deduct or withhold, or require the Participant or the Participant’s beneficiary to remit to the Company or its affiliates, an amount sufficient to satisfy federal, state, and local taxes, domestic or foreign, required by law or regulation to be withheld with respect to any taxable event arising as a result of an award of Performance Shares.

10.        Share Withholding.  At the discretion of the Company, Participants may be able to elect to satisfy the tax withholding requirement, in whole or in part, by having the Company or any of its subsidiaries withhold Shares having a fair market value equal to taxes required to be withheld on the transaction. All such elections shall be irrevocable, made in writing, signed by the Participant, and shall be subject to any restrictions or limitations that the Committee, in its sole discretion, deems appropriate.

11.        Limitations on Transferability.      Except as otherwise provided by the Plan or by the Committee, the Participant’s rights to Performance Shares may not be sold, transferred, pledged, assigned, or otherwise alienated or hypothecated, other than by will or by the laws of descent and distribution. The Participant’s rights under an Award Agreement shall be exercisable during the Participant’s lifetime only by the Participant or the Participant’s legal representative.

12.        Beneficiary Designation.     The Participant may, from time to time, name any beneficiary or beneficiaries (who may be named contingently or successively) to whom any benefit under an Award Agreement is to be distributed in case of his or her death before he or she receives any or all of such benefit. Each such designation shall revoke all prior designations by the Participant, shall be in a form prescribed by the Company, and will be effective only when filed by the Participant in writing with the Secretary of the Company during the Participant’s lifetime. In the absence of any such designation, benefits remaining unpaid at the Participant’s death shall be paid to the Participant’s estate.

13.        No Right to Continued Employment or Service.  Neither the Plan nor an Award Agreement shall be construed as giving the Participant or any employee or any person the

right to be retained in the employ or service of the Company or any of its subsidiaries nor shall it interfere in any way with the right of the Company or any of its subsidiaries to terminate the Participant’s employment or service at any time.

14.      Successors and Assigns.      All obligations of the Company and any of its subsidiaries under the Plan and an Award Agreement, with respect to an award of Performance Units, shall be binding on any successor to the Company, whether the existence of such successor is the result of a direct or indirect purchase, merger, consolidation or otherwise of all of the business and/or assets of the Company.

15.      Administration.       Award Agreements and the rights of Participants are subject to all the terms and conditions of the Plan, as the Plan may be amended from time to time, as well as to such rules and regulations as the Committee may adopt for administration of the Plan. The Committee is authorized to administer, construe, and make all determinations necessary or appropriate to the administration of the Plan and any Award Agreement, all of which shall be binding upon the Participant. Any inconsistency between Award Agreements and the Plan shall be resolved in favor of the Plan.

16.      Amendment and Termination of the Plan.  The Plan may be amended or terminated by the Board of Directors of the Company without stockholder approval unless the Board seeks to increase the number of shares of common stock subject to the Plan or stockholder approved is required by law or regulation or under the rules of any stock exchange or automated quotation system on which the common stock is then listed or quoted. Stockholder approval will not be deemed to be required under laws or regulations that condition favorable tax treatment on such approval, although the Board may, in its discretion, seek stockholder approval in any circumstances in which it deems such approval advisable.

17.      Severability.  If any portion of the Award Agreement or the terms and conditions set forth in this document are declared invalid or unenforceable by a court or governmental authority of competent jurisdiction, this shall not affect the validity or enforceability of any remaining portion, which such remaining portion(s) shall remain in full force and effect as if the Award Agreement and/or this document had been agreed to with the invalid or unenforceable portion(s) eliminated.

18.      Miscellaneous.  If the Performance Period ends on a non-trading day, the Performance Period will be deemed to end on the immediately preceding trading day. If the day for any other action to be taken falls on a non-business day for the Company, the period for taking such action will extend through the Company’s next business day.

[Schedule 1 is the provided on the following page]

Schedule 1

Peer Group

Consolidated Edison Inc.

Northeast Utilities

Centerpoint Energy Inc.

AGL Resources Inc.

Pepco Holdings Inc.

Integrys Energy Group Inc.

Atmos Energy Corp.

Vectren Corp.

Piedmont Natural Gas Co.

WGL Holdings Inc.

Southwest Gas Corp.

UIL Holdings Inc.

South Jersey Industries

New Jersey Resources

Northwestern Corp.

Laclede Group Inc.

MGE Energy Inc.

Northwest Natural Gas Co.

Chesapeake Utilities Corp.

EX-10.2

Exhibit 10.2

EXHIBIT B

PERFORMANCE UNITS GRANT #8      

WGL Holdings, Inc.

Omnibus Incentive Compensation Plan

Performance Units (Series #8) Award

Terms and Conditions

This document sets forth the terms and conditions related to the Series #8 grant of performance unit awards under the WGL Holdings, Inc. Omnibus Incentive Compensation Plan (the “Plan”). The following terms have the meanings ascribed below:

“Award Agreement” means the agreement between an award recipient and WGL Holdings, Inc. relating to the grant of performance units subject to the terms of the WGL Holdings, Inc. Omnibus Incentive Compensation Plan and this document.

“Company” means WGL Holdings, Inc., a Virginia corporation.

“Participant” means a person that has been awarded Performance Units subject to the terms and conditions set forth in this document and the WGL Holdings, Inc. Omnibus Incentive Compensation Plan.

“Performance Units” means the target number of performance units awarded pursuant to an Award Agreement.

“Performance Period” means October 1, 2014 through September 30, 2017.

“Performance Measure” means the annualized total shareholder return (as determined below) compared to the peer group shown on Schedule 1 attached hereto (the “Performance Measure”).

“Plan” means the WGL Holdings, Inc. Omnibus Incentive Compensation Plan.

The Plan provides a complete description of the terms and conditions governing the Performance Units. If there is any inconsistency between the terms of this document and the terms of the Plan, the Plan’s terms shall completely supersede and replace the conflicting terms of this document. All capitalized terms have the meanings ascribed to them in the Plan, unless otherwise indicated herein.

1.        Value of Performance Units. Each Performance Unit represents and has a value equal to one dollar.

2.        Performance Units Payout and Total Shareholder Return Performance Measure. The number of Performance Units to be earned pursuant to an Award Agreement is based upon the Company’s Total Shareholder Return (as defined below) as compared to the

Total Shareholder Return of the Company’s peer group (the peer group is identified on Schedule 1 attached hereto) during the Performance Period. The determination of Total Shareholder Return is described below.

Total Shareholder Return = Change in Stock Price + Dividends Paid Beginning Stock Price

“Beginning Stock Price” means the average closing prices as reported on the New York Stock Exchange (the “NYSE”) of one share of the Stock for the thirty (30) trading days ending immediately prior to the first calendar day of the Performance Period. “Ending Stock Price” means the price of one share of Stock as determined at a particular date during the Performance Period. “Change in Stock Price” means the difference between the Beginning Stock Price and the Ending Stock Price. “Dividends Paid” means the total of all dividends paid on one share of stock during the Performance Period, provided that dividends shall be treated as though they are reinvested at the end of each calendar quarter. The Company’s Total Shareholder Return will be calculated at the end of each of the four fiscal quarters of the third fiscal year of the Performance Period and a hypothetical payout calculated for each quarter. The results of the four quarterly payouts will be averaged to determine the final payout for the Performance Period.

In connection with the Total Shareholder Return determination (as described above), the Company’s “Percentile Rank” shall be determined as follows:

Percentile Rank		Company Rank (from the bottom)
	=	Total number of companies in peer group including the Company

“Company Rank” shall be determined by listing, from highest Total Shareholder Return to lowest Total Shareholder Return, each company in the peer group (including the Company) and counting up from the company with the lowest Total Shareholder Return. The percent of Performance Units earned is determined based on the following chart:

Company’s Percentile Rank	Percent of Target Award     Earned
90th		200%
70th		150%
50th		100%
25th		50%
Below 25th percentile and WGL dividend increases at least 9% over 3-year period		25%
Below 25th percentile and dividend test not met		0%

Interpolation shall be used to determine the percent of target award earned in the event the Company’s Percentile Rank does not fall directly on one of the ranks listed in the foregoing chart.

3.        Change or Termination of Employment or Service: For purposes of this Section 3, the term “Employer” means the Company or the Company’s subsidiary that employs the Participant, or to which the Participant provides services, on the effective date of the grant. Except as provided below, and subject to the provisions of Section 4 relating to a Change of Control, a Participant is eligible for payment of earned Performance Units, as specified in Section 2, only if the Participant’s employment or service with the Employer continues through the end of the Performance Period provided however that, a Participant that is an employee of the Company will not be eligible for the payment of earned Performance Units if the Participant has been demoted from the position he or she held at the date of grant to a position that is below the management level of “director”. Further, a Participant will not be eligible for payment of earned Performance Units if he or she is suspended from employment with the Employer as of the date of the end of the Performance Period.

Subject to the provisions of Section 4 of this Agreement, if a Participant terminates employment or services with the Employer prior to the end of the Performance Period for any reason, including voluntary or involuntary termination, death, disability or retirement, the Human Resources Committee of the Board of Directors of the Company (the “Committee”), in its sole discretion, may determine that the Participant shall be eligible for that proportion of the number of Performance Units earned under Section 2 for such Performance Period that his or her number of full months of participation during the Performance Period bears to the total number of months in the Performance Period. In the event of the death of the Participant, the Participant’s designated beneficiary or estate shall be entitled to the Performance Units under the same conditions as would have been applicable to the Participant.

4.        Change of Control.  In the event of a Change of Control, as defined in the Plan, the number of Performance Units shall vest pursuant to the terms of the Company’s Change in Control Policy.

5.        Form and Timing of Payment for Performance Units.    Any Performance Units earned at the end of the Performance Period will be paid out in cash. Payment for any earned Performance Units shall be made to the Participant as promptly as practicable following the close of the Performance Period.

6.        Tax Withholding.    The Company may deduct or withhold, or require the Participant or the Participant’s beneficiary to remit to the Company or its affiliates, an amount sufficient to satisfy federal, state, and local taxes, domestic or foreign, required by law or regulation to be withheld with respect to any taxable event arising as a result of the award of Performance Units.

7.        Limitations on Transferability.  Except as otherwise provided by the Plan or by the Committee, the Participant’s rights to Performance Units may not be sold, transferred, pledged, assigned, or otherwise alienated or hypothecated, other than by will or by the laws of descent and distribution. The Participant’s rights under an Award Agreement shall be exercisable during the Participant’s lifetime only by the Participant or the Participant’s legal representative.

8.        Beneficiary Designation.  The Participant may, from time to time, name any beneficiary or beneficiaries (who may be named contingently or successively) to whom any benefit under an Award Agreement is to be distributed in case of his or her death before he or she receives any or all of such benefit. Each such designation shall revoke all prior designations by the Participant, shall be in a form prescribed by the Company, and will be effective only when filed by the Participant in writing with the Secretary of the Company during the Participant’s lifetime. In the absence of any such designation, benefits remaining unpaid at the Participant’s death shall be paid to the Participant’s estate.

9.        No Right to Continued Employment or Service.  Neither the Plan nor an Award Agreement shall be construed as giving the Participant or any employee or any person the right to be retained in the employ or service of the Company or any of its subsidiaries nor shall it interfere in any way with the right of the Company or any of its subsidiaries to terminate the Participant’s employment or service at any time.

10.      Successors and Assigns.      All obligations of the Company and any of its subsidiaries under the Plan and an Award Agreement, with respect to an award of Performance Units, shall be binding on any successor to the Company, whether the existence of such successor is the result of a direct or indirect purchase, merger, consolidation or otherwise of all of the business and/or assets of the Company.

11.      Administration. Award Agreements and the rights of Participants are subject to all the terms and conditions of the Plan, as the Plan may be amended from time to time, as well as to such rules and regulations as the Committee may adopt for administration of the Plan. The Committee is authorized to administer, construe, and make all determinations necessary or appropriate to the administration of the Plan and any Award Agreement, all of which shall be binding upon the Participant. Any inconsistency between Award Agreements and the Plan shall be resolved in favor of the Plan.

12.      Amendment and Termination of the Plan.  The Plan may be amended or terminated by the Board of Directors of the Company without stockholder approval unless the Board seeks to increase the number of shares of common stock subject to the Plan or stockholder approved is required by law or regulation or under the rules of any stock exchange or automated quotation system on which the common stock is then listed or quoted. Stockholder approval will not be deemed to be required under laws or regulations that condition favorable tax treatment on such approval, although the Board may, in its discretion, seek stockholder approval in any circumstances in which it deems such approval advisable.

13.      Severability.  If any portion of the Award Agreement or the terms and conditions set forth in this document are declared invalid or unenforceable by a court or governmental

authority of competent jurisdiction, this shall not affect the validity or enforceability of any remaining portion, which such remaining portion(s) shall remain in full force and effect as if the Award Agreement and/or this document had been agreed to with the invalid or unenforceable portion(s) eliminated.

14.      Miscellaneous. If the Performance Period ends on a non trading day, the Performance Period will be deemed to end on the immediately preceding trading day. If the day for any other action to be taken under this Agreement falls on a non-business day for the Company, the period for taking such action will extend through the Company’s next business day.

[Schedule 1 is the provided on the following page]

Schedule 1

Peer Group

Consolidated Edison Inc.

Northeast Utilities

Centerpoint Energy Inc.

AGL Resources Inc.

Pepco Holdings Inc.

Integrys Energy Group Inc.

Atmos Energy Corp.

Vectren Corp.

Piedmont Natural Gas Co.

WGL Holdings Inc.

Southwest Gas Corp.

UIL Holdings Inc.

South Jersey Industries

New Jersey Resources

Northwestern Corp.

Laclede Group Inc.

MGE Energy Inc.

Northwest Natural Gas Co.

Chesapeake Utilities Corp.

EX-12.1

Exhibit 12.1

WGL HOLDINGS, INC. AND SUBSIDIARIES

Computation of Ratio of Earnings to Fixed Charges and

Ratio of Earnings to Fixed Charges and Preferred Stock Dividends

	Twelve Months Ended September 30,
($ in thousands)	2014		2013		2012		2011			2010
EARNINGS:
Pre-Tax Net Income(a)	$	161,320	$	132,355	$	233,247	$	206,069		$	184,477
Add:
Distributed Income (Loss) of Equity Investees		3,194		1,510		1,240		(549	)		284
Total Fixed Charges		39,484		37,893		38,583		42,619			41,218
Total Earnings	$	203,998	$	171,758	$	273,070	$	248,139		$	225,979
FIXED CHARGES:
Interest on long term debt	$	36,383	$	34,512	$	36,275	$	39,097		$	38,474
Other Interest (excluding AFUDC)		918		905		229		1,447			869
Amortization of Debt Premium, Discount and Expense		345		337		352		414			434
One-third of Rental Expense(b)		1,838		2,139		1,727		1,661			1,441
Total Fixed Charges	$	39,484	$	37,893	$	38,583	$	42,619		$	41,218
Ratio of Earnings to Fixed Charges		5.2		4.5		7.1		5.8			5.5
FIXED CHARGES AND PRE-TAX PREFERRED STOCK DIVIDENDS:
Pre-Tax Preferred Dividend Requirement	$	1,320	$	1,320	$	1,320	$	1,320		$	1,320
Effective Income Tax Rate		0.3480		0.3906		0.3981		0.4241			0.3981
Complement of Effective Income Tax Rate (1-Tax Rate)		0.6520		0.6094		0.6019		0.5759			0.6019
Preferred Dividend Requirement	$	2,025	$	2,166	$	2,193	$	2,292		$	2,193
Combined Fixed Charges and Preferred Dividends	$	41,509	$	40,059	$	40,776	$	44,911		$	43,411
Ratio of Earnings to Fixed Charges and Preferred Dividends		4.9		4.3		6.7		5.5			5.2

^(a) Excludes amounts attributable to income or loss from equity investees.

^(b) Management believes one-third of the total rental expense gives a reasonable estimate of total interest on rentals.

EX-12.2

Exhibit 12.2

WASHINGTON GAS LIGHT COMPANY

Computation of Ratio of Earnings to Fixed Charges and

Ratio of Earnings to Fixed Charges and Preferred Stock Dividends

	Twelve Months Ended September 30,
($ in thousands)	2014		2013		2012			2011		2010
EARNINGS:
Pre-Tax Net Income(a)	$	145,858	$	116,519	$	181,793		$	125,376	$	169,430
Add:
Total Fixed Charges		38,415		37,081		37,886			42,141		40,735
Total Earnings	$	184,273	$	153,600	$	219,679		$	167,517	$	210,165
FIXED CHARGES:
Interest on long term debt	$	36,233	$	34,512	$	36,275		$	39,097	$	38,474
Other Interest (excluding AFUDC)		458		525		(101	)		1,363		726
Amortization of Debt Premium, Discount and Expense		345		337		352			414		434
One-third of Rental Expense(b)		1,379		1,707		1,360			1,267		1,101
Total Fixed Charges	$	38,415	$	37,081	$	37,886		$	42,141	$	40,735
Ratio of Earnings to Fixed Charges		4.8		4.1		5.8			4.0		5.2
FIXED CHARGES AND PRE-TAX PREFERRED STOCK DIVIDENDS:
Pre-Tax Preferred Dividend Requirement	$	1,320	$	1,320	$	1,320		$	1,320	$	1,320
Effective Income Tax Rate		0.3258		0.3793		0.3947			0.4449		0.3959
Complement of Effective Income Tax Rate (1-Tax Rate)		0.6742		0.6207		0.6053			0.5551		0.6041
Preferred Dividend Requirement	$	1,958	$	2,127	$	2,181		$	2,378	$	2,185
Combined Fixed Charges and Preferred Dividends	$	40,373	$	39,208	$	40,067		$	44,519	$	42,920
Ratio of Earnings to Fixed Charges and Preferred Stock Dividends		4.6		3.9		5.5			3.8		4.9

^(a) Excludes amounts attributable to income or loss from equity investees.

^(b) Management believes one-third of the total rental expense gives a reasonable estimate of total interest on rentals.

EX-21

Exhibit 21

WGL HOLDINGS, INC.

Subsidiaries of the above registrant as of September 30, 2014

Subsidiary Relationship Denoted by Indentation	Percent of Voting Securities Owned		State of Incorporation
WGL Holdings, Inc. (Parent)			Virginia
Washington Gas Light Company	100	%	Virginia and the District of Columbia
Hampshire Gas Company	100	%	West Virginia
Crab Run Gas Company	100	%	Virginia
Washington Gas Resources Corp.	100	%	Delaware
WGL Midstream, Inc.	100	%	Delaware
Washington Gas Energy Services, Inc.	100	%	Delaware
Washington Gas Energy Systems, Inc.	100	%	Delaware
WGSW, Inc.	100	%	Delaware

EX-23

Exhibit 23

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We consent to the incorporation by reference in the following Registration Statements of WGL Holdings, Inc. and Washington Gas Light Company (collectively, “the Companies”) of our reports dated November 21, 2014, relating to the consolidated financial statements and financial statement schedule of WGL Holdings, Inc. and subsidiaries and the financial statements and financial statement schedule of Washington Gas Light Company, and the effectiveness of WGL Holdings, Inc. and subsidiaries’ internal control over financial reporting, appearing in this Annual Report on Form 10-K of WGL Holdings, Inc. and Washington Gas Light Company for the year ended September 30, 2014:

WGL Holdings, Inc.

Form S-3 No. 333-126620

Form S-8 No. 333-104571

Form S-8 No. 333-104572

Form S-8 No. 333-104573

Form S-8 No. 333-142983

Form S-8 No. 333-171160

Form S-3 No. 333-192731

Form S-3 No. 333-198218

Washington Gas Light Company

Form S-3 No. 333-159243

Form S-3 No. 333-181528

/s/ DELOITTE & TOUCHE LLP

McLean, Virginia

November 21, 2014

EX-24

Exhibit 24

POWER OF ATTORNEY

Each person whose signature appears below does hereby constitute and appoint Terry D. McCallister, Adrian P. Chapman, Leslie T. Thornton, Vincent L. Ammann, Jr. and William R. Ford, or any of them singly, as such person’s true and lawful attorney-in-fact and agent, with full power of substitution, resubstitution and revocation to execute, deliver and file with the Securities and Exchange Commission, for and on such person’s behalf, and in any and all capacities, Form 10-K for the fiscal year ended September 30, 2014, of WGL Holdings, Inc. and Washington Gas Light Company any and all amendments thereto, under the Securities Exchange Act of 1934, with all exhibits thereto and other documents in connection therewith, granting unto said attorneys-in-fact and agents full power and authority to do and perform each and every act and thing requisite and necessary to be done as fully to all intents and purposes as such person might or could do in person, hereby ratifying and confirming all that said attorney-in-fact and agent or such person’s substitute or substitutes may lawfully do or cause to be done by virtue hereof.

Name	Title	Date
/s/  Michael D. Barnes	Director	November 17, 2014
(Michael D. Barnes)
/s/  George P. Clancy, Jr.	Director	November 17, 2014
(George P. Clancy, Jr.)
/s/  James W. Dyke, Jr.	Director	November 17, 2014
(James W. Dyke, Jr.)
/s/  Dale S. Rosenthal	Director	November 17, 2014
(Dale S. Rosenthal)
/s/  Nancy C. Floyd	Director	November 17, 2014
(Nancy C. Floyd)
/s/  Linda R. Gooden	Director	November 17, 2014
(Linda R. Gooden)
/s/  James F. Lafond	Director	November 17, 2014
(James F. Lafond)
/s/  Debra L. Lee	Director	November 17, 2014
(Debra L. Lee)

EX-31.1

Exhibit 31.1

CERTIFICATION OF WGL HOLDINGS, INC.

I, Terry D. McCallister, certify that:

1. I have reviewed this annual report on Form 10-K of WGL Holdings, 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 fourth fiscal quarter that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

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

a) All significant deficiencies and material weaknesses in the design or operation of internal control 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: November 21, 2014

/s/ Terry D. McCallister

Terry D. McCallister

Chairman and Chief Executive Officer

EX-31.2

Exhibit 31.2

CERTIFICATION OF WGL HOLDINGS, INC.

I, Vincent L. Ammann, Jr., certify that:

1. I have reviewed this annual report on Form 10-K of WGL Holdings, 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 fourth fiscal quarter that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

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

a) All significant deficiencies and material weaknesses in the design or operation of internal control 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: November 21, 2014

/s/ Vincent L. Ammann, Jr.

Vincent L. Ammann, Jr.

Senior Vice President and Chief Financial Officer

EX-31.3

Exhibit 31.3

CERTIFICATION OF WASHINGTON GAS LIGHT COMPANY

I, Terry D. McCallister, certify that:

1. I have reviewed this annual report on Form 10-K of Washington Gas Light Company;

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

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

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

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

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

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

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

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

a) All significant deficiencies and material weaknesses in the design or operation of internal control 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: November 21, 2014

/s/ Terry D. McCallister

Terry D. McCallister

Chairman and Chief Executive Officer

EX-31.4

Exhibit 31.4

CERTIFICATION OF WASHINGTON GAS LIGHT COMPANY

I, Vincent L. Ammann, Jr., certify that:

1. I have reviewed this annual report on Form 10-K of Washington Gas Light Company;

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

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

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

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

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

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

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

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

a) All significant deficiencies and material weaknesses in the design or operation of internal control 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: November 21, 2014

/s/ Vincent L. Ammann, Jr.

Vincent L. Ammann, Jr.

Senior Vice President and Chief Financial Officer

EX-32

Exhibit 32

CERTIFICATION OF THE CHAIRMAN AND CHIEF EXECUTIVE OFFICER

AND THE SENIOR VICE PRESIDENT AND CHIEF FINANCIAL OFFICER

PURSUANT TO 18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the combined annual report of WGL Holdings, Inc. and Washington Gas Light Company (the “Companies”) on Form 10-K for the annual period ended September 30, 2014 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), Terry D. McCallister, Chairman and Chief Executive Officer of the Companies, and Vincent L. Ammann, Jr., Senior Vice President and Chief Financial Officer of the Companies, each hereby certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, to the best of their knowledge, that:

(1) The Report fully complies with the requirements of Section 13(a) of the Securities Exchange Act of 1934; and

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

This certification is being made for the exclusive purpose of compliance by the Chairman and Chief Executive Officer and the Senior Vice President and Chief Financial Officer of the Companies with the requirements of Section 906 of the Sarbanes-Oxley Act of 2002, and may not be disclosed, distributed, or used by any person for any reason other than as specifically required by law.

/s/ Terry D. McCallister

Terry D. McCallister

Chairman and Chief Executive Officer

/s/ Vincent L. Ammann, Jr.

Vincent L. Ammann, Jr.

Senior Vice President and Chief Financial Officer

November 21, 2014

XML

Short-Term Debt (Tables)

12 Months Ended

Sep. 30, 2014

Short Term Debt Tables [Abstract]

Commited Credit Available

Committed Credit Available (In millions)
September 30, 2014	WGL Holdings, Inc.(b)		Washington Gas		Total Consolidated
Committed credit agreements
Unsecured revolving credit facility, expires April 3, 2017(a)	$	450.0	$	350.0	$	800.0
Less: Commercial Paper		(364.5)		(89.0)		(453.5)
Net committed credit available	$	85.5	$	261.0	$	346.5
Weighted average interest rate		0.20%		0.13%		0.19%
September 30, 2013
Committed credit agreements
Unsecured revolving credit facility, expires April 3, 2017(a)	$	450.0	$	350.0	$	800.0
Less: Commercial Paper		(248.6)		(124.5)		(373.1)
Net committed credit available	$	201.4	$	225.5	$	426.9
Weighted average interest rate		0.21%		0.13%		0.19%
(a)Both WGL and Washington Gas have the right to request extensions with the banks’ approval. WGL’s revolving credit facility permits it to borrow an additional $100 million, with the banks’ approval, for a total of $550 million. Washington Gas’ revolving credit facility permits it to borrow an additional $100 million, with the banks’ approval, for a total of $450 million.
(b)WGL Holdings includes all subsidiaries other than Washington Gas Light Company.

XML

Quarterly Financial Information (Tables)

12 Months Ended

Sep. 30, 2014

Quarterly Financial Information Disclosure [Abstract]

Schedule Of Quarterly Financial Information [Table Text Block]

##XSQuarter Ended
(In thousands, except per share data)	December 31			March 31		June 30	September 30
Fiscal Year 2014
WGL Holdings, Inc.
Operating revenues	$	680,297	$	1,174,250	$	467,500	$	458,900
Operating income (loss)	$	32,712	$	104,733	$	(9,489)	$	69,566
Net income (loss) applicable to common stock	$	18,629	$	61,213	$	(11,940)	$	38,038
Earnings (loss) per average share of common stock:
Basic	$	0.36	$	1.18	$	(0.23)	$	0.74
Diluted	$	0.36	$	1.18	$	(0.23)	$	0.74
Washington Gas Light Company
Operating revenues	$	390,415	$	716,808	$	197,752	$	138,825
Operating income	$	65,229	$	88,038	$	4,326	$	24,530
Net income (loss) applicable to common stock	$	38,477	$	49,176	$	(521)	$	9,872
Fiscal Year 2013
WGL Holdings, Inc.
Operating revenues	$	686,736	$	891,383	$	478,118	$	409,901
Operating income (loss)	$	94,616	$	155,584	$	(9,111)	$	(75,270)
Net income (loss) applicable to common stock	$	52,388	$	89,505	$	(10,015)	$	(51,625)
Earnings (loss) per average share of common stock:
Basic	$	1.01	$	1.73	$	(0.19)	$	(1.00)
Diluted	$	1.01	$	1.73	$	(0.19)	$	(1.00)
Washington Gas Light Company
Operating revenues	$	355,817	$	535,950	$	180,882	$	127,708
Operating income (loss)	$	72,037	$	134,358	$	(368)	$	(55,421)
Net income (loss) applicable to common stock	$	38,387	$	76,935	$	(4,531)	$	(39,789)

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Committments and Contingencies (Tables)

12 Months Ended

Sep. 30, 2014

Commitments and Contingencies [Line Items]

Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block]

Minimum Payments Under Operating Leases
(In millions)
2015	$	7.8
2016		6.3
2017		4.9
2018		4.3
2019		1.0
Thereafter		10.5
Total	$	34.8

Washington Gas Light Company

Commitments and Contingencies [Line Items]

Long-term Purchase Commitment [Table Text Block]

Washington Gas Contract Minimums
(In millions)	Pipeline Contracts(a)		Gas Purchase Commitments(b)
2015	$	195.4	$	280.0
2016		224.7		288.9
2017		217.7		336.7
2018		211.1		323.2
2019		201.3		303.5
Thereafter		1,205.3		2,990.2
Total	$	2,255.5	$	4,522.5
(a) Represents minimum payments for natural gas transportation, storage and peaking contracts that have expiration dates through fiscal year 2032.
(b) The contracts referenced above are estimated based on market prices at September 30, 2014.

Non Utility [Member]

Commitments and Contingencies [Line Items]

Long-term Purchase Commitment [Table Text Block]

	Contract Minimums
	WGEServices						WGL Midstream
(In millions)	Gas Purchase Commitments(a)		Pipeline Contracts(b)		Electric Purchase Commitments(c)		Gas Purchase Commitments(d)		Pipeline Contracts(e)			Total
2015	$	167.5	$	2.4	$	359.4	$	29.2	$	15.3	$	573.8
2016		49.2		0.6		171.7		24.4		19.4		265.3
2017		13.8		0.6		65.0		80.2		17.7		177.3
2018		0.6		0.6		3.6		906.0		26.5		937.3
2019		-		0.6		-		933.4		24.6		958.6
Thereafter		-		1.3		-		13,479.8		260.9		13,742.0
Total	$	231.1	$	6.1	$	599.7	$	15,453.0	$	364.4	$	16,654.3
(a)Represents fixed price commitments with city gate equivalent deliveries.
(b)Represents minimum payments for natural gas transportation, storage and peaking contracts that have expiration dates through fiscal year 2025.
(c)Represents electric purchase commitments that are based on existing fixed price and fixed volume contracts. Includes $15.3 million of commitments related to renewable energy credits.
(d)Includes short-term commitments to purchase fixed volumes of natural gas, as well as long-term gas purchase commitments that contain fixed volume purchase requirements. Cost estimates are based on forward market prices for purchases under these purchase commitments.
(e)Represents minimum payments for natural gas transportation, storage and peaking contracts that have expiration dates through fiscal year 2044.

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Income Taxes (Components of Deferred Tax Assets) (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Current [Member] | WGL Holdings, Inc.
Deferred Income Tax Assets:
Pensions	$ 0	$ 0
Other post-retirement benefits	0	0
Uncollectible accounts	9,268	8,127
Inventory overheads	6,591	6,431
Capital gains/losses-net	0	2
Valuation allowance	0	(2)
Employee compensation and benefits	6,306	5,876
Customer advances	0	0
Derivatives	6,503	0
Deferred gas costs	0	4,911
Other	814	816
Solar grant/ investment tax credit	0	0
Total assets	29,482	26,161
Deferred Income Tax Liabilities:
Other post-retirement benefits	0	0
Accelerated depreciation and other plant related items	0	0
Losses/gains on reacquired debt	0	0
Income taxes recoverable through future rates	0	0
Deferred gas costs	2,818	0
Derivatives	0	1,639
Partnership basis difference	0	0
Total liabilities	2,818	1,639
Net accumulated deferred income tax assets (liabilities)	26,664	24,522
Current [Member] | Washington Gas Light Company
Deferred Income Tax Assets:
Pensions	0	0
Other post-retirement benefits	0	0
Uncollectible accounts	7,618	6,948
Inventory overheads	6,591	6,431
Employee compensation and benefits	5,902	5,756
Customer advances	0	0
Derivatives	4,809	2,138
Deferred gas costs	0	4,911
Other	814	816
Solar grant/ investment tax credit	0	0
Total assets	25,734	27,000
Deferred Income Tax Liabilities:
Other post-retirement benefits	0	0
Accelerated depreciation and other plant related items	0	0
Losses/gains on reacquired debt	0	0
Income taxes recoverable through future rates	0	0
Deferred gas costs	2,818	0
Derivatives	0	0
Other	0	0
Total liabilities	2,818	0
Net accumulated deferred income tax assets (liabilities)	22,916	27,000
Non-current [Member] | WGL Holdings, Inc.
Deferred Income Tax Assets:
Pensions	24,349	17,362
Other post-retirement benefits	0	18,510
Uncollectible accounts	0	0
Inventory overheads	0	0
Capital gains/losses-net	0	0
Valuation allowance	0	0
Employee compensation and benefits	37,873	37,301
Customer advances	197	197
Derivatives	31,555	7,872
Deferred gas costs	4,218	0
Other	1,225	2,530
Solar grant/ investment tax credit	39,184	17,415
Total assets	138,601	101,187
Deferred Income Tax Liabilities:
Other post-retirement benefits	38,299	0
Accelerated depreciation and other plant related items	669,040	596,754
Losses/gains on reacquired debt	1,426	1,567
Income taxes recoverable through future rates	65,374	112,222
Deferred gas costs	0	4,667
Derivatives	0	0
Partnership basis difference	25,370	15,784
Total liabilities	799,509	730,994
Net accumulated deferred income tax assets (liabilities)	(660,908)	(629,807)
Non-current [Member] | Washington Gas Light Company
Deferred Income Tax Assets:
Pensions	23,738	16,768
Other post-retirement benefits	0	18,474
Uncollectible accounts	0	0
Inventory overheads	0	0
Employee compensation and benefits	27,961	27,125
Customer advances	197	197
Derivatives	31,555	7,872
Deferred gas costs	4,218	0
Other	0	1,727
Solar grant/ investment tax credit	312	312
Total assets	87,981	72,475
Deferred Income Tax Liabilities:
Other post-retirement benefits	38,065	0
Accelerated depreciation and other plant related items	602,376	565,996
Losses/gains on reacquired debt	1,426	1,567
Income taxes recoverable through future rates	65,128	111,698
Deferred gas costs	0	4,667
Derivatives	0	0
Other	932	0
Total liabilities	707,927	683,928
Net accumulated deferred income tax assets (liabilities)	$ (619,946)	$ (611,453)

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Accounting Policies (Narrative) (Details) (USD $)	12 Months Ended																3 Months Ended		12 Months Ended		3 Months Ended		12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2014 WGL Holdings, Inc.	Sep. 30, 2013 WGL Holdings, Inc.	Sep. 30, 2012 WGL Holdings, Inc.	Sep. 30, 2014 Washington Gas Light Company	Sep. 30, 2013 Washington Gas Light Company	Sep. 30, 2012 Washington Gas Light Company	Sep. 30, 2014 WGEServices	Sep. 30, 2013 WGEServices	Sep. 30, 2012 WGEServices	Sep. 30, 2014 WGL Midstream	Sep. 30, 2013 WGL Midstream	Sep. 30, 2012 WGL Midstream	Sep. 30, 2014 Natural Gas Customers WGEServices Customers	Jun. 30, 2014 Abandoned LNG storage project	Sep. 30, 2013 Abandoned LNG storage project	Sep. 30, 2014 Abandoned LNG storage project	Sep. 30, 2013 Abandoned LNG storage project	Dec. 31, 2013 Springfield Operations Center	Sep. 30, 2013 Springfield Operations Center	Sep. 30, 2014 Springfield Operations Center Washington Gas Light Company	Sep. 30, 2013 Springfield Operations Center Washington Gas Light Company	Sep. 30, 2012 Springfield Operations Center Washington Gas Light Company	Sep. 30, 2014 Interruptible Customers [Member] Washington Gas Light Company	Sep. 30, 2014 Firm Customer [Member] Washington Gas Light Company	Sep. 30, 2014 Electric Generation Customers [Member] Washington Gas Light Company	Sep. 30, 2014 Electricity Customers [Member] WGEServices Customers
Accounting Policies Details Narrative [Abstract]
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service	2.77%	2.86%	2.87%
Pretax AFUDC Rate	3.36%	5.43%	7.40%
Impairment loss				$ 2,639,000	$ 2,600,000	$ 5,015,000	$ 2,639,000	$ 2,600,000	$ 5,015,000								$ 1,900,000	$ 500,000	$ 1,900,000	$ 500,000	$ 800,000	$ 2,600,000	$ 800,000	$ 2,600,000	$ 5,000,000
Duration Of Cost Of Gas Recovered Or Refunded	12 months
Indexed Or Fixed Rate Customer Contracts Terms	Customer contracts, which typically have terms less than 24 months, but may extend up to five years, allow WGEServices to bill customers based upon metered gas and electricity usage.
Number of states with commercial energy systems segment activity	15
Customer Related Information [Abstract]
Percentage Of Total Gas Deliveries																										14.30%	78.10%	7.60%
Number of Customers																157,000													162,000
Inventory Adjustments [Abstract]
Lower Of Cost Or Market Adjustment Storage Gas Inventory							$ (200,000)	$ 0	$ (1,400,000)	$ 0	$ 0	$ 0	$ (3,000,000)	$ (10,100,000)	$ (22,400,000)

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Pension and Other Post-retirement Benefit Plans (Table 6) (Details)	12 Months Ended
	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2012
Pension Plans Defined Benefit [Member]
Net Periodic Benefit Cost Assumptions [Abstract]
Discount rate			4.00%	[1]	5.30%	[1]
Expected long-term return on plan assets	6.50%		6.75%		7.50%
Pension Plans Defined Benefit [Member] | Maximum [Member]
Benefit Obligations Assumptions [Abstract]
Discount rate	4.40%	[2]	5.00%	[2]
Rate of compensation increase	4.10%		5.15%
Net Periodic Benefit Cost Assumptions [Abstract]
Discount rate	5.00%	[1]
Rate of compensation increase	5.15%	[3]	5.15%	[3]	5.15%	[3]
Pension Plans Defined Benefit [Member] | Minimum [Member]
Benefit Obligations Assumptions [Abstract]
Discount rate	4.00%	[2]	4.50%	[2]
Rate of compensation increase	3.50%		3.85%
Net Periodic Benefit Cost Assumptions [Abstract]
Discount rate	4.50%	[1]
Rate of compensation increase	3.85%	[3]	3.85%	[3]	3.85%	[3]
Other PostretirementBenefit Plans Defined Benefit [Member]
Benefit Obligations Assumptions [Abstract]
Discount rate	4.40%	[2]	5.10%	[2]
Rate of compensation increase	4.10%		3.85%
Net Periodic Benefit Cost Assumptions [Abstract]
Discount rate			4.00%	[1]	5.10%	[1]
Expected long-term return on plan assets	6.25%	[4]	6.75%	[4]	7.40%	[4]
Rate of compensation increase	3.85%	[3]	3.85%	[3]
Other PostretirementBenefit Plans Defined Benefit [Member] | Maximum [Member]
Net Periodic Benefit Cost Assumptions [Abstract]
Discount rate	5.10%	[1]
Rate of compensation increase					5.15%	[3]
Other PostretirementBenefit Plans Defined Benefit [Member] | Minimum [Member]
Net Periodic Benefit Cost Assumptions [Abstract]
Discount rate	4.60%	[1]
Rate of compensation increase					3.85%	[3]

[1] The changes in the discount rates over the last two fiscal years primarily reflects the changes in long-term interest rates.

[2] The decrease in the discount rate in fiscal year 2014 compared to prior years primarily reflects the decrease in long-term interest rates.

[3] The changes in the rate of compensation reflects the best estimates of actual future compensation levels including consideration of general price levels, productivity, seniority, promotion, and other factors such as inflation rates.

[4] For health and life benefits, the expected returns for certain funds may be lower due to certain portions of income that are subject to an assumed income tax rate of 41.5%.

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Other Investments - Financing Leases Table (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014
Capital Leases Future Minimum Payments Receivable [Abstract]
2015	$ 2.3
2016	2.0
2017	1.9
2018	1.8
2019	1.7
Thereafter	12.3
Total	22.0
Direct Financing Leases - Unearned Income	10.2
Direct Financing Leases - Residual Value	5.1
Direct Financing Leases - Initial Direct Costs	0.7
Direct Financing Leases - Tax Credits	$ 3.0

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Pension and Other Post-Retirement Benefit Plans (Tables)

12 Months Ended

Sep. 30, 2014

Pension And Other Post Retirement Benefit Plans Tables [Line Items]

Components of Net Periodic Benefit Costs (Income)

Components of Net Periodic Benefit Costs (Income)
(In millions)		Pension Benefits						Health and Life Benefits
Year Ended September 30,		2014		2013		2012		2014		2013		2012
Service cost	$	14.0	$	17.0	$	12.9	$	7.6	$	9.6	$	8.0
Interest cost		40.4		36.6		40.5		18.7		18.8		25.1
Expected return on plan assets		(41.0)		(41.9)		(43.5)		(19.3)		(18.3)		(18.8)
Recognized prior service cost		0.3		1.0		1.0		(9.6)		(3.9)		(3.9)
Recognized actuarial loss		16.8		28.7		16.1		5.0		9.2		13.3
Amortization of transition obligation		-		-		-		-		1.1		1.1
Net periodic benefit cost		30.5		41.4		27.0		2.4		16.5		24.8
Amount allocated to construction projects		(4.3)		(5.7)		(3.4)		(0.4)		(2.8)		(3.7)
Amount deferred as regulatory asset (liability)-net		7.0		(3.7)		(7.5)		(2.3)		2.4		1.5
Amount charged (credited) to expense	$	33.2	$	32.0	$	16.1	$	(0.3)	$	16.1	$	22.6

Unrecognized Costs Income Recorded On Balance Sheet [Table Text Block]

Unrecognized Costs/Income Recorded on the Balance Sheet
(In millions)		Pension Benefits				Health and Life Benefits
September 30,	2014		2013		2014		2013
Actuarial net loss	$	162.6	$	171.1	$	50.1	$	55.3
Prior service cost (credit)		1.2		1.3		(149.3)		(22.4)
Total	$	163.8	$	172.4	$	(99.2)	$	32.9
Regulatory asset (liability)	$	147.9	$	155.1	$	(94.6)	$	31.3
Pre-tax accumulated other comprehensive loss (gain)(a)		15.9		17.3		(4.6)		1.6
Total	$	163.8	$	172.4	$	(99.2)	$	32.9
(a)The total amount of accumulated other comprehensive loss recorded on our balance sheets at September 30, 2014 and 2013 is net of an income tax benefit of $4.9 million and $7.9 million, respectively.

Amount Recognized During Current Year [Table Text Block]

Amounts Recognized During Fiscal Year 2014
	Regulatory assets/liabilities				Accumulated other comprehensive loss
(In millions)	Pension Benefits		Health and Life Benefits		Pension Benefits		Health and Life Benefits
Actuarial net loss	$	15.5	$	4.8	$	1.3	$	0.3
Prior service cost (credit)		0.2		(9.1)		0.1		(0.5)
Total	$	15.7	$	(4.3)	$	1.4	$	(0.2)

Post Retirement Benefits

Post-Retirement Benefits
						Health and Life
(In millions)		Pension Benefits(a)				Benefits
Year Ended September 30,		2014		2013		2014		2013
Change in projected benefit obligation(b)
Benefit obligation at beginning of year	$	837.4	$	937.2	$	429.8	$	480.1
Service cost		14.0		17.0		7.6		9.6
Interest cost		40.4		36.6		18.7		18.8
Change in plan benefits		-		-		(136.5)		-
Actuarial loss (gain)		68.6		(110.0)		38.2		(62.3)
Retiree contributions		-		-		4.4		3.9
Medicare Part D reimbursements		-		-		0.5		0.7
Benefits paid		(43.3)		(43.4)		(19.5)		(21.0)
Projected benefit obligation at end of year(b)	$	917.1	$	837.4	$	343.2	$	429.8
Change in plan assets
Fair value of plan assets at beginning of year	$	745.2	$	750.6	$	380.9	$	358.3
Actual return on plan assets		103.3		38.6		57.8		19.9
Company contributions		1.7		1.8		16.0		18.0
Retiree contributions and Medicare Part D reimbursements		-		-		4.4		5.7
Expenses		(2.2)		(2.4)		-		-
Benefits paid		(43.3)		(43.4)		(19.5)		(21.0)
Fair value of plan assets at end of year	$	804.7	$	745.2	$	439.6	$	380.9
Funded status at end of year	$	(112.4)	$	(92.2)	$	96.4	$	(48.9)
Total amounts recognized on balance sheet
Non-current asset	$	-	$	-	$	96.4	$	-
Current liability		(4.2)		(3.5)		-		-
Non-current liability		(108.2)		(88.7)		-		(48.9)
Total recognized	$	(112.4)	$	(92.2)	$	96.4	$	(48.9)
(a)The DB SERP and DB Restoration, included in pension benefits in the table above, have no assets.
(b)For the Health and Life Benefits, the change in projected benefit obligation represents the accumulated benefit obligation.

Amount Recognized During Next Fiscal Year

Amounts to be Recognized During Fiscal Year 2015
	Regulatory assets/liabilities				Accumulated other comprehensive loss
(In millions)	Pension Benefits		Health and Life Benefits		Pension Benefits		Health and Life Benefits
Actuarial net loss	$	17.1	$	4.2	$	1.7	$	0.2
Prior service cost (credit)		0.2		(14.5)		0.1		(0.7)
Total	$	17.3	$	(10.3)	$	1.8	$	(0.5)

Benefit Obligations Assumptions/Net Periodic Benefits Assumptions

Benefit Obligations Assumptions
	Pension Benefits		Health and Life Benefits
September 30,	2014	2013	2014	2013
Discount rate(a)	4.00%-4.40%	4.50%-5.00%	4.40%	5.10%
Rate of compensation increase	3.50%-4.10%	3.85%-5.15%	4.10%	3.85%
(a)The decrease in the discount rate in fiscal year 2014 compared to prior years primarily reflects the decrease in long-term interest rates.

Net Periodic Benefit Cost Assumptions
	Pension Benefits			Health and Life Benefits
Years Ended September 30,	2014	2013	2012	2014	2013	2012
Discount rate(a)	4.50%-5.00%	4.00%	5.30%	4.60%-5.10%	4.00%	5.10%
Expected long-term return on plan assets(b)	6.50%	6.75%	7.50%	6.25%	6.75%	7.40%
Rate of compensation increase(c)	3.85%-5.15%	3.85%-5.15%	3.85%-5.15%	3.85%	3.85%	3.85%-5.15%
(a) The changes in the discount rates over the last two fiscal years primarily reflects the changes in long-term interest rates.
(b) For health and life benefits, the expected returns for certain funds may be lower due to certain portions of income that are subject to an assumed income tax rate of 41.5%.
(c) The changes in the rate of compensation reflects the best estimates of actual future compensation levels including consideration of general price levels, productivity, seniority, promotion, and other factors such as inflation rates.

Healthcare Trends

Healthcare Trends
(In millions)	One Percentage-Point Increase		One Percentage-Point Decrease
Increase (decrease) total service and interest cost components	$	3.6	$	(2.7)
Increase (decrease) post-retirement benefit obligation	$	10.5	$	(9.2)

Valuation Methods Level 3 assets

(In millions)
Years Ended September 30,		2014		2013
Balance, beginning of year		$	21.1	$	18.7
Actual return on plan assets:
	Assets still held at year end		2.7		2.4
Balance, end of year		$	23.8	$	21.1

Expected Benefit Payments

Expected Benefit Payments
(In millions)	Pension Benefits		Health and Life Benefits
2015	$	48.9	$	17.9
2016		50.3		18.8
2017		51.9		19.4
2018		53.0		20.1
2019		54.7		20.6
2020—2024		286.5		105.3

Projected and accumulated benefit obligation

Projected and accumulated benefit obligation
(In millions)		Qualified Pension Plan				DB SERP				DB Restoration
September 30,	2014		2013		2014		2013		2014		2013
Projected benefit obligation	$	865.2	$	788.8	$	50.7	$	47.8	$	1.2	$	0.8
Accumulated benefit obligation	$	801.9	$	737.2	$	46.2	$	43.9	$	0.7	$	0.5

Pension Plans Defined Benefit [Member]

Pension And Other Post Retirement Benefit Plans Tables [Line Items]

Pension and OPEB Plan Assets

Pension Plan Assets
										% of
($ In millions)		Level 1		Level 2		Level 3		Total		Total
At September 30, 2014
Cash and cash equivalents		$	0.6	$	-	$	-	$	0.6	0.1	%
Equity securities
	U.S. Small Cap		32.3		-		-		32.3	4.0
	Preferred Securities		-		0.1		-		0.1	0.0
Fixed income securities
	U.S. Treasuries		-		110.6		-		110.6	13.8
	U.S. Corporate Debt		-		108.4		-		108.4	13.5
	U.S. Agency Obligations and Government Sponsored Entities		-		24.6		-		24.6	3.0
	Asset-Backed Securities and Collateralized Mortgage Obligations		-		1.8		-		1.8	0.2
	Municipalities		-		9.2		-		9.2	1.1
	Non-U.S. Corporate Debt		-		23.8		-		23.8	3.0
	Repurchase Agreements(a)		-		2.5		-		2.5	0.3
	Other(b)		-		7.0		-		7.0	0.8
Mutual Funds(c)			-		112.4		-		112.4	14.0
Commingled Funds and Pooled Separate Accounts(d)			-		316.2		23.8		340.0	42.3
Private Equity/Limited Partnerships(e)			-		30.5		-		30.5	3.8
Derivatives(f)			-		(0.1)		-		(0.1)	0.0
Total fair value of plan investments		$	32.9	$	747.0	$	23.8	$	803.7	99.9	%
Receivable (payable)(g)									1.0	0.1
Total plan assets at fair value								$	804.7	100.0	%

Pension Plan Assets
										% of
($ In millions)		Level 1		Level 2		Level 3		Total		Total
At September 30, 2013
Cash and cash equivalents		$	0.9	$	-	$	-	$	0.9	0.1	%
Equity securities
	U.S. Small Cap		31.5		-		-		31.5	4.2
	Preferred Securities		-		0.1		-		0.1	-
Fixed income securities
	U.S. Treasuries		-		124.5		-		124.5	16.7
	U.S. Corporate Debt		-		93.6		-		93.6	12.6
	U.S. Agency Obligations and Government Sponsored Entities		-		19.0		-		19.0	2.5
	Asset-Backed Securities and Collateralized Mortgage Obligations		-		1.9		-		1.9	0.2
	Municipalities		-		9.0		-		9.0	1.2
	Non-U.S. Corporate Debt		-		18.4		-		18.4	2.5
	Repurchase Agreements(a)		-		1.0		-		1.0	0.1
	Other(b)		-		5.7		-		5.7	0.8
Mutual Funds(c)			-		93.2		-		93.2	12.5
Commingled Funds and Pooled Separate Accounts(d)			-		295.5		21.1		316.6	42.5
Private Equity/Limited Partnerships(e)			-		33.3		-		33.3	4.5
Derivatives(f)			-		(0.3)		-		(0.3)	-
Total fair value of plan investments		$	32.4	$	694.9	$	21.1	$	748.4	100.4	%
Receivable (payable)(g)									(3.2)	(0.4)
Total plan assets at fair value								$	745.2	100.0	%
(a)	This category includes Treasury Bills with a pre-commitment from the counterparty to repurchase the same securities on the next business day at an agreed-upon price.
(b)	This category primarily includes Yankee bonds and non-U.S. government bonds.
(c)	At September 30, 2014 and September 30, 2013, investments in mutual funds consisted primarily of corporate fixed income instruments.
(d)	At September 30, 2014, investments in commingled funds and pooled separate accounts consisted primarily of 75% common stock of large-cap U.S. companies; 14% income producing properties located in the United States; 9% equity securities of non-U.S. companies; and 2% short-term money market investments. At September 30, 2013, investments in commingled funds and pooled separate accounts consisted primarily of 67% common stock of large-cap U.S. companies; 12% income producing properties located in the United States; 20% equity securities of non-U.S. companies; and 1% short-term money market investments.
(e)	At September 30, 2014, investments in private equity/limited partnership consisted of common stock of international companies.
(f)	At September 30, 2014, this category includes long-term U.S. Treasury interest rate futures contracts and interest rate put options.

Other PostretirementBenefit Plans Defined Benefit [Member]

Pension And Other Post Retirement Benefit Plans Tables [Line Items]

Pension and OPEB Plan Assets

Healthcare and Life Insurance Plan Assets
										% of
($ In millions)			Level 1		Level 2		Level 3		Total	Total
At September 30, 2014
Cash and Cash Equivalents		$	0.8	$	-	$	-	$	0.8	0.2	%
Mutual Funds(a)			-		1.9		-		1.9	0.4
Fixed Income Securities
	U.S Agency Obligations		-		2.0		-		2.0	0.5
	U.S. Treasuries		-		25.6		-		25.6	5.8
	U.S. Corporate Debt		-		34.0		-		34.0	7.7
	Municipalities		-		4.8		-		4.8	1.1
	Non-U.S. Corporate Debt		-		5.7		-		5.7	1.3
	Others(b)		-		5.3		-		5.3	1.2
Commingled Funds(c)			-		359.7		-		359.7	81.8
Total fair value of plan investments		$	0.8	$	439.0	$	-	$	439.8	100.0	%
Receivable (payable)									(0.2)	-
Total plan assets at fair value								$	439.6	100.0	%

At September 30, 2013
Cash and Cash Equivalents		$	0.6	$	-	$	-	$	0.6	0.2	%
Fixed Income Securities
	U.S Agency Obligations		-		1.7		-		1.7	0.4
	U.S. Treasuries		-		23.6		-		23.6	6.2
	U.S. Corporate Debt		-		28.7		-		28.7	7.5
	Municipalities		-		4.1		-		4.1	1.1
	Non-U.S. Corporate Debt		-		4.6		-		4.6	1.2
	Others(b)		-		5.3		-		5.3	1.4
Commingled Funds(c)			-		311.2		-		311.2	81.7
Total fair value of plan investments		$	0.6	$	379.2	$	-	$	379.8	99.7	%
Receivable (payable)									1.1	0.3
Total plan assets at fair value								$	380.9	100.0	%
(a)	At September 30, 2014, investments in mutual funds consisted primarily of 63% short-term obligations consisting of certificates of deposit and time deposits, 23% high-quality commercial paper, 6% repurchase agreements, 4% corporate notes of U.S. and foreign corporations and 4% U.S. governmental and U.S. agency securities.
(b)	At September 30, 2014 and 2013, this category consisted primarily of 82% non-U.S. government bonds and 18% Yankee bonds.
(c)	At September 30, 2014 and 2013, investments in commingled funds consisted primarily of 66% common stock of large-cap U.S. companies, 17% U.S. agency obligations and government sponsored entities and 17% corporate bonds.

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Schedule II

12 Months Ended

Sep. 30, 2014

Valuation and Qualifying Accounts [Abstract]

Schedule II - Valuation and Qualifying Accounts and Reserves

WGL Holdings, Inc. and Subsidiaries
Schedule II—Valuation and Qualifying Accounts and Reserves
Years Ended September 30, 2014, 2013 and 2012
		Balance at		Additions Charged To						Balance
		Beginning		Costs and		Other				at End of
(In thousands)		of Period		Expenses		Accounts(a)		Deductions(b)		Period
2014
Valuation and Qualifying Accounts
Deducted from Assets in the Balance Sheet:
Allowance for Doubtful Accounts	$	20,433	$	15,874	$	4,341	$	17,307	$	23,341
2013
Valuation and Qualifying Accounts
Deducted from Assets in the Balance Sheet:
Allowance for Doubtful Accounts	$	19,792	$	9,527	$	4,217	$	13,103	$	20,433
2012
Valuation and Qualifying Accounts
Deducted from Assets in the Balance Sheet:
Allowance for Doubtful Accounts	$	17,969	$	18,316	$	4,774	$	21,267	$	19,792
Notes:
(a) Recoveries on receivables previously written off as uncollectible and unclaimed customer deposits, overpayments, etc., not refundable.
(b) Includes deductions for purposes for which reserves were provided or revisions made of estimated exposure.
Washington Gas Light Company
Schedule II—Valuation and Qualifying Accounts and Reserves
Years Ended September 30, 2014, 2013 and 2012
		Balance at		Additions Charged To						Balance at
		Beginning		Costs and		Other				End of
(In thousands)		of Period		Expenses		Accounts(a)		Deductions(b)		Period
2014
Valuation and Qualifying Accounts
Deducted from Assets in the Balance Sheet:
Allowance for Doubtful Accounts	$	17,498	$	12,004	$	4,198	$	14,491	$	19,209
2013
Valuation and Qualifying Accounts
Deducted from Assets in the Balance Sheet:
Allowance for Doubtful Accounts	$	17,129	$	7,024	$	3,978	$	10,633	$	17,498
2012
Valuation and Qualifying Accounts
Deducted from Assets in the Balance Sheet:
Allowance for Doubtful Accounts	$	15,863	$	12,794	$	4,300	$	15,828	$	17,129
Notes:
(a) Recoveries on receivables previously written off as uncollectible and unclaimed customer deposits, overpayments, etc., not refundable.
(b)Includes deductions for purposes for which reserves were provided or revisions made of estimated exposure.

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Pension and Other Post-retirement Benefit Plans (Table 7) (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014
Defined Benefit Plan, Assumed Health Care Cost Trend Rates [Abstract]
Increase one percentage point total service and interest cost components	$ 3.6
Decrease one percentage point total service and interest cost components	(2.7)
Increase one percentage point post-retirement benefit obligation	10.5
Decrease one percentage point post-retirement benefit obligation	$ (9.2)

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Pension and Other Post-retirement Benefit Plans (Table 1) (Details) (USD $)	12 Months Ended
	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2012
Change in plan assets
Fair value of plan assets at end of year	$ 23,800,000		$ 21,100,000		$ 18,700,000
Pension Plans Defined Benefit [Member]
Change in projected benefit obligation
Benefit obligation at beginning of year	837,400,000	[1]	937,200,000	[1]
Service cost	14,000,000	[1]	17,000,000	[1]	12,900,000
Interest cost	40,400,000	[1]	36,600,000	[1]	40,500,000
Change in plan benefits	0	[1]	0	[1]
Actuarial loss (gain)	68,600,000	[1]	(110,000,000)	[1]
Retiree Contributions	0	[1]	0	[1]
Medicare part D reimbursements	0	[1]	0	[1]
Benefits Paid	(43,300,000)	[1]	(43,400,000)	[1]
Projected benefit obligation at end of year	917,100,000	[1]	837,400,000	[1]	937,200,000	[1]
Change in plan assets
Fair Value of plan assets at beginning of year	745,200,000	[1]	750,600,000	[1]
Actual return on plan assets	103,300,000	[1]	38,600,000	[1]
Company contributions	1,700,000	[1]	1,800,000	[1]
Retiree Contributions And Medicare Part D Reimbursements	0	[1]	0	[1]
Expenses	(2,200,000)	[1]	(2,400,000)	[1]
Benefits Paid	(43,300,000)	[1]	(43,400,000)	[1]
Fair value of plan assets at end of year	804,700,000	[1]	745,200,000	[1]	750,600,000	[1]
Funded status at end of year	(112,400,000)	[1]	(92,200,000)	[1]
Total Recognized
Non-current asset	0	[1]	0	[1]
Current liability	(4,200,000)	[1]	(3,500,000)	[1]
Non-current liability	(108,200,000)	[1]	(88,700,000)	[1]
Total Recognized	(112,400,000)	[1]	(92,200,000)	[1]
Other PostretirementBenefit Plans Defined Benefit [Member]
Change in projected benefit obligation
Benefit obligation at beginning of year	429,800,000	[2]	480,100,000
Service cost	7,600,000		9,600,000		8,000,000
Interest cost	18,700,000		18,800,000		25,100,000
Change in plan benefits	(136,500,000)		0
Actuarial loss (gain)	38,200,000		(62,300,000)
Retiree Contributions	4,400,000		3,900,000
Medicare part D reimbursements	500,000		700,000
Benefits Paid	(19,500,000)		(21,000,000)
Projected benefit obligation at end of year	343,200,000	[2]	429,800,000	[2]	480,100,000
Change in plan assets
Fair Value of plan assets at beginning of year	380,900,000		358,300,000
Actual return on plan assets	57,800,000		19,900,000
Company contributions	16,000,000		18,000,000
Retiree Contributions And Medicare Part D Reimbursements	4,400,000		5,700,000
Expenses	0		0
Benefits Paid	(19,500,000)		(21,000,000)
Fair value of plan assets at end of year	439,600,000		380,900,000		358,300,000
Funded status at end of year	96,400,000		(48,900,000)
Total Recognized
Non-current asset	96,400,000		0
Current liability	0		0
Non-current liability	0		(48,900,000)
Total Recognized	$ 96,400,000		$ (48,900,000)

[1] The DB SERP and DB Restoration, included in pension benefits in the table above, have no assets.

[2] For the Health and Life Benefits, the change in projected benefit obligation represents the accumulated benefit obligation.

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Environmentat Matters (Narrative) (Details) (Washington Gas Light Company, USD $)	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	$ 71,584,000	$ 65,984,000
Environmental Exit Costs, Reasonably Possible Additional Losses, High Estimate	19,300,000	20,500,000
Accrual For Environmental Costs
Schedule of Regulatory Assets and Liabilities [Line Items]
Accrual for Environmental Loss Contingencies	8,500,000	8,500,000
Environmental response costs
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	$ 600,000	$ 600,000

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Accounting Policies - Operating Leases (Details) (Leasehold Improvements [Member])	12 Months Ended
	Sep. 30, 2014
Leasehold Improvements [Member]
Property, Plant and Equipment [Line Items]
Property Plant And Equipment Depreciation Methods	straight-line over the non-cancelable period of the lease
Property Plant And Equipment Useful Life	15 years

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Quarterly Financial Information - Table (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended								12 Months Ended
	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2012
WGL Holdings, Inc.
Operating Revenues	$ 458,900	$ 467,500	$ 1,174,250	$ 680,297	$ 409,901	$ 478,118	$ 891,383	$ 686,736	$ 2,780,947	[1]	$ 2,466,138	[1]	$ 2,425,310	[1]
Operating Income (Loss)	69,566	(9,489)	104,733	32,712	(75,270)	(9,111)	155,584	94,616	197,522		165,818		265,521
NET INCOME (LOSS) APPLICABLE TO COMMON STOCK	38,038	(11,940)	61,213	18,629	(51,625)	(10,015)	89,505	52,388	105,940		80,253		139,818
Earnings Per Share [Abstract]
Basic	$ 0.74	$ (0.23)	$ 1.18	$ 0.36	$ (1.00)	$ (0.19)	$ 1.73	$ 1.01	$ 2.05		$ 1.55		$ 2.71
Diluted	$ 0.74	$ (0.23)	$ 1.18	$ 0.36	$ (1.00)	$ (0.19)	$ 1.73	$ 1.01	$ 2.05		$ 1.55		$ 2.71
Washington Gas Light Company
Operating Revenues	138,825	197,752	716,808	390,415	127,708	180,882	535,950	355,817	1,443,800		1,200,357		1,137,666
Operating Income (Loss)	24,530	4,326	88,038	65,229	(55,421)	(368)	134,358	72,037	182,123		150,606		214,756
NET INCOME (LOSS) APPLICABLE TO COMMON STOCK	$ 9,872	$ (521)	$ 49,176	$ 38,477	$ (39,789)	$ (4,531)	$ 76,935	$ 38,387	$ 97,004		$ 71,002		$ 108,726

[1] Operating revenues are reported gross of revenue taxes. Revenue taxes of both the regulated utility and the retail energy-marketing segments include gross receipt taxes. Revenue taxes of the regulated utility segment also include PSC fees, franchise fees and energy taxes. Operating revenue amounts in the "Eliminations" column represent total intersegment revenues associated with sales from the regulated utility segment to the retail energy-marketing segment. Midstream Energy Services' cost of energy related sales is netted with its gross revenues.

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Pension and Other Post-retirement Benefit Plans (Table 4) (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014
Pension Plans Defined Benefit [Member] | Regulatory Assets Liabilities [Member]
Amounts Recognized During Fiscal Year
Actuarial net loss	$ 15.5
Prior service cost (credit)	0.2
Total	15.7
Amounts to be Recognized During Fiscal Year
Actuarial net loss	17.1
Prior service cost (credit)	0.2
Total	17.3
Pension Plans Defined Benefit [Member] | Accumulated Other Comprehensive Loss
Amounts Recognized During Fiscal Year
Actuarial net loss	1.3
Prior service cost (credit)	0.1
Total	1.4
Amounts to be Recognized During Fiscal Year
Actuarial net loss	1.7
Prior service cost (credit)	0.1
Total	1.8
Other PostretirementBenefit Plans Defined Benefit [Member] | Regulatory Assets Liabilities [Member]
Amounts Recognized During Fiscal Year
Actuarial net loss	4.8
Prior service cost (credit)	(9.1)
Total	(4.3)
Amounts to be Recognized During Fiscal Year
Actuarial net loss	4.2
Prior service cost (credit)	(14.5)
Total	(10.3)
Other PostretirementBenefit Plans Defined Benefit [Member] | Accumulated Other Comprehensive Loss
Amounts Recognized During Fiscal Year
Actuarial net loss	0.3
Prior service cost (credit)	(0.5)
Total	(0.2)
Amounts to be Recognized During Fiscal Year
Actuarial net loss	0.2
Prior service cost (credit)	(0.7)
Total	$ (0.5)

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Stock Based Compensation (Table 2) (Details) (USD $)	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
Performances Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology [Abstract]
Expected stock-price volatility	19.10%	19.40%	27.80%
Dividend yield	3.93%	3.98%	3.97%
Weighted-average grant date fair value, granted	$ 42.88	$ 39.73	$ 38.99
Performance Units [Member] | Grant 2012 [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology [Abstract]
Expected stock-price volatility	19.50%
Performance Units [Member] | Grant 2013 [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology [Abstract]
Expected stock-price volatility	18.10%

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Pension and Other Post-retirement Benefit Plans (Table 8-Footnotes) (Details)	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Large Cap U.S. Companies Common Stock [Member]
Defined Benefit Plan Disclosure [Line Items]
Allocation of investments in comingled funds and pooled separate accounts	75.00%	67.00%
Allocation of investments in comingled funds	66.00%	66.00%
Income Producing Properties [Member]
Defined Benefit Plan Disclosure [Line Items]
Allocation of investments in comingled funds and pooled separate accounts	14.00%	12.00%
Foreign Company Stock [Member]
Defined Benefit Plan Disclosure [Line Items]
Allocation of investments in comingled funds and pooled separate accounts	9.00%	20.00%
Short-term money market investments [Member]
Defined Benefit Plan Disclosure [Line Items]
Allocation of investments in comingled funds and pooled separate accounts	2.00%	1.00%
Certificates of deposit and time deposits [Member]
Defined Benefit Plan Disclosure [Line Items]
Allocation of investments in mutual funds	63.00%
High-quality commercial paper [Member]
Defined Benefit Plan Disclosure [Line Items]
Allocation of investments in mutual funds	23.00%
Repurchase Agreements [Member]
Defined Benefit Plan Disclosure [Line Items]
Allocation of investments in mutual funds	6.00%
Corporate notes of U.S. and foreign corporations [Member]
Defined Benefit Plan Disclosure [Line Items]
Allocation of investments in mutual funds	4.00%
U.S. governmental and U.S. agency securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Allocation of investments in mutual funds	4.00%
Foreign Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Allocation of investments in other securities	82.00%	82.00%
Yankee Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Allocation of investments in other securities	18.00%	18.00%
U.S. agency obligations and government [Member]
Defined Benefit Plan Disclosure [Line Items]
Allocation of investments in comingled funds	17.00%	17.00%
Corporate Bonds
Defined Benefit Plan Disclosure [Line Items]
Allocation of investments in comingled funds	17.00%	17.00%

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Stock Based Compensation (Table 3) (Details) (USD $) In Thousands, except Share data, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock options outstanding, beginning	26,372
Stock options granted	0
Stock options exercised	(21,054)
Stock options exercisable	5,318
Stock options cancelled/forfeited	0
Stock options outstanding, end of year	5,318	26,372
Weighted-average exercise price, outstanding	$ 31.34	$ 31.34
Weighted-average exercise price, granted	$ 0
Weighted-average exercise price, exercised	$ 31.34
Weighted-average exercise price, cancelled/forfeited	$ 0
Weighted-average exercise price, exercisable	$ 31.34
Weighted-average remaining contractual term, outstanding	2 years	4 years 0 months
Weighted-average remaining contractual term, exercisable	2 years
Aggregate intrinsic value, outstanding	$ 57	$ 235
Aggregate intrinsic value, exercisable	57
Weighted Average Contractual Term - Granted	0 years
Weighted Average Contractual Term - Excercised	0 years
Weighted Average Contractual Term - Cancelled	0 years
Aggregate Intrinsic Value - Granted	0
Aggregate Intrinsic Value - Exercised	232
Aggregate Intrinsic Value - Cancelled	$ 0

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Pension and Other Post-retirement Benefit Plans (Table 5) (Details) (USD $)	12 Months Ended
	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2012
WGL Holdings, Inc.
Defined Benefit Plan Disclosure [Line Items]
Recognized prior service cost	$ 6,095,000	[1],[2]	$ (1,671,000)	[1]	$ (640,000)
Recognized actuarial loss	(1,594,000)	[1]	(3,399,000)	[1]	2,125,000
Change in transition obligation	0	[1]	238,000	[1]	239,000
Washington Gas Light Company
Defined Benefit Plan Disclosure [Line Items]
Recognized prior service cost	6,095,000	[1],[2]	(1,671,000)	[1]	(640,000)
Recognized actuarial loss	(1,594,000)	[1]	(3,399,000)	[1]	2,125,000
Change in transition obligation	0	[1]	238,000	[1]	239,000
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	14,000,000	[3]	17,000,000	[3]	12,900,000
Interest cost	40,400,000	[3]	36,600,000	[3]	40,500,000
Expected return on plan assets	(41,000,000)		(41,900,000)		(43,500,000)
Recognized prior service cost	300,000		1,000,000		1,000,000
Recognized actuarial loss	16,800,000		28,700,000		16,100,000
Change in transition obligation	0		0		0
Net periodic benefit cost	30,500,000		41,400,000		27,000,000
Amount allocated to construction projects	(4,300,000)		(5,700,000)		(3,400,000)
Amount deferred as regulatory asset (liability)-net	7,000,000		(3,700,000)		(7,500,000)
Amount charged (credited) to expense	33,200,000		32,000,000		16,100,000
Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	7,600,000		9,600,000		8,000,000
Interest cost	18,700,000		18,800,000		25,100,000
Expected return on plan assets	(19,300,000)		(18,300,000)		(18,800,000)
Recognized prior service cost	(9,600,000)		(3,900,000)		(3,900,000)
Recognized actuarial loss	5,000,000		9,200,000		13,300,000
Change in transition obligation	0		1,100,000		1,100,000
Net periodic benefit cost	2,400,000		16,500,000		24,800,000
Amount allocated to construction projects	(400,000)		(2,800,000)		(3,700,000)
Amount deferred as regulatory asset (liability)-net	(2,300,000)		2,400,000		1,500,000
Amount charged (credited) to expense	$ (300,000)		$ 16,100,000		$ 22,600,000

[1] (a) These accumulated other comprehensive income components are included in the computation of net periodic benefit cost. Refer to Note 10-Pension and other post-retirement benefit plans for additional details.

[2] (b) The majority of the 2014 change to the prior service cost component of other comprehensive income is related to the impact of the OPEB plan amendment and re-measurement. Refer to Note 10-Pension and other post-retirement benefit plans for additional details.

[3] The DB SERP and DB Restoration, included in pension benefits in the table above, have no assets.

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Income Taxes (Unrecognized Tax Benefits) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Total unrecognized tax benefits, beginning balance	$ 25,051	$ 22,082	$ 20,699
Increases resulting from current period tax positions	10,512	5,251	3,396
Decreases resulting from prior period tax positions	(2,950)	(2,282)	(2,013)
Total unrecognized tax benefits, ending balance	$ 32,613	$ 25,051	$ 22,082

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Commitments and Contingencies

12 Months Ended

Sep. 30, 2014

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

NOTE 13.COMMITMENTS AND CONTINGENCIES

OPERATING LEASES

Minimum future rental payments under operating leases over the next five years and thereafter are as follows:

Minimum Payments Under Operating Leases
(In millions)
2015	$	7.8
2016		6.3
2017		4.9
2018		4.3
2019		1.0
Thereafter		10.5
Total	$	34.8

Rent expense totaled $5.5 million,$5.6 million and $5.2million in fiscal years ended September 30, 2014, 2013 and 2012, respectively.

REGULATED UTILITY OPERATIONS

Natural Gas Contracts—Minimum Commitments

At September 30, 2014, Washington Gas had service agreements with fourpipeline companies that provide direct service for firm transportation and/or storage services. These agreements, which have expiration dates ranging from fiscal years 2015to 2032, require Washington Gas to pay fixed charges each month. Additionally, Washington Gas had agreements for other pipeline and peaking services with expiration dates ranging from 2015 to 2032. These agreements were entered into based on current estimates of growth of the Washington Gas system, together with other factors, such as current expectations of the timing and extent of unbundling initiatives in the Washington Gas service territory.

The following table summarizes the minimum contractual payments that Washington Gas will makeunder its pipeline transportation, storage and peaking contracts, as well as minimum contractual payments to purchase natural gas at prices based on market conditions during the next five fiscal years and thereafter. The gas purchase contracts noted below represent commitments to purchase natural gas based on market conditions at the time the natural gas is purchased.

Washington Gas Contract Minimums
(In millions)	Pipeline Contracts(a)		Gas Purchase Commitments(b)
2015	$	195.4	$	280.0
2016		224.7		288.9
2017		217.7		336.7
2018		211.1		323.2
2019		201.3		303.5
Thereafter		1,205.3		2,990.2
Total	$	2,255.5	$	4,522.5
(a) Represents minimum payments for natural gas transportation, storage and peaking contracts that have expiration dates through fiscal year 2032.
(b) The contracts referenced above are estimated based on market prices at September 30, 2014.

When a customer selects a third party marketer to provide supply, Washington Gas generally assigns pipeline and storage capacity to unregulated third party marketers to deliver gas to Washington Gas' city gate. In order to provide the gas commodity to customers who do not select an unregulated third party marketer, Washington Gas has a commodity acquisition plan to acquire the natural gas supply to serve the customers.

Currently, Washington Gas recovers its cost of gas to serve its customers through the purchased gas cost recovery mechanisms included in its retail rate schedules in each of its jurisdictions. However, the timing and extent of Washington Gas' initiatives or regulatory requirements to separate the purchase and sale of natural gas from the delivery of gas could cause its gas supply commitments to exceed its continued sales obligations.

Washington Gas has rate provisions in each of its jurisdictions that would allow it to continue to recover these commitments in rates. Washington Gas also actively manages its supply portfolio to ensure its sales and supply obligations remain balanced. This reduces the likelihood that the contracted supply commitments would exceed supply obligations. However, to the extent Washington Gas were to determine that changes in regulation would cause it to discontinue recovery of these costs in rates, Washington Gas would be required to charge these costs to expense without any corresponding revenue recovery. If this occurred, depending upon the timing of the occurrence, the related impact on our financial position, results of operations and cash flows would likely be significant.

Regulatory Contingencies

Certain legal and administrative proceedings incidental to our business, including regulatory contingencies, involve WGL and/or its subsidiaries. In our opinion, we have recorded an adequate provision for probable losses or refunds to customers for regulatory contingencies related to these proceedings.

NON-UTILITY OPERATIONS

WGEServices enters into contracts to purchase natural gas and electricity designed to match the duration of its sales commitments, and to effectively lock in a margin on estimated sales over the terms of existing sales contracts. As listed below, natural gas purchase commitments are based on existing fixed-price purchase contracts using city gate equivalent deliveries, the majority of which are for fixed volumes. Also listed below are electricity purchase commitments that are based on existing fixed-price purchase commitments, all of which are for fixed volumes.

WGL Midstream enters into contracts to acquire, invest in, manage and optimize natural gas storage and transportation assets. Gas purchase commitments increased during fiscal year 2014 due to purchase commitments related to investment pipeline infrastructure.

The following table summarizes the minimum commitments and contractual obligations of WGEServices and WGL Midstream for the next five fiscal years and thereafter:

	Contract Minimums
	WGEServices						WGL Midstream
(In millions)	Gas Purchase Commitments(a)		Pipeline Contracts(b)		Electric Purchase Commitments(c)		Gas Purchase Commitments(d)		Pipeline Contracts(e)			Total
2015	$	167.5	$	2.4	$	359.4	$	29.2	$	15.3	$	573.8
2016		49.2		0.6		171.7		24.4		19.4		265.3
2017		13.8		0.6		65.0		80.2		17.7		177.3
2018		0.6		0.6		3.6		906.0		26.5		937.3
2019		-		0.6		-		933.4		24.6		958.6
Thereafter		-		1.3		-		13,479.8		260.9		13,742.0
Total	$	231.1	$	6.1	$	599.7	$	15,453.0	$	364.4	$	16,654.3
(a)Represents fixed price commitments with city gate equivalent deliveries.
(b)Represents minimum payments for natural gas transportation, storage and peaking contracts that have expiration dates through fiscal year 2025.
(c)Represents electric purchase commitments that are based on existing fixed price and fixed volume contracts. Includes $15.3 million of commitments related to renewable energy credits.
(d)Includes short-term commitments to purchase fixed volumes of natural gas, as well as long-term gas purchase commitments that contain fixed volume purchase requirements. Cost estimates are based on forward market prices for purchases under these purchase commitments.
(e)Represents minimum payments for natural gas transportation, storage and peaking contracts that have expiration dates through fiscal year 2044.

Construction Project Financing

To fund certain of its construction projects, Washington Gas enters into financing arrangements with third party lenders. As part of these financing arrangements, Washington Gas' customers agree to make principal and interest payments over a period of time, typically beginning after the projects are completed. Washington Gas assigns these customer payment streams to the lender. As the lender funds the construction project, Washington Gas establishes a receivable representing its customers' obligations to remit principal and interest and a long-term payable to the lender. When these projects are formally “accepted” by the customer as completed, Washington Gas transfers the ownership of the receivable to the lender and removes both the receivable and the long-term financing from its financial statements. As of September 30, 2014 and 2013, work on these construction projects that was not completed or accepted by customers was valued at $8.3 million and $6.7 million, respectively, thatare recorded on the balance sheet as a receivable in “Deferred Charges and Other Assets—Other” with the corresponding long-term obligation to the lender in “Long-term debt.” At any time before these contracts are accepted by the customer, should there be a contract default, such as, among other things, a delay in completing the project, the lender may call on Washington Gas to fund the unpaid principal in exchange for which Washington Gas would receive the right to the stream of payments from the customer. Construction projects are financed primarily for government agencies, which Washington Gas considers to have minimal credit risk. Based on this assessment and previous collection experience, Washington Gas did not record a corresponding reserve for bad debts related to these receivables at September 30, 2014 or September 30, 2013.

Financial Guarantees

WGL has guaranteed payments primarily for certain purchases of natural gas and electricity on behalf of WGEServices and for certain purchase commitments on behalf of WGL Midstream. At September 30, 2014, these guarantees totaled $227.3 million and $276.5 million for WGEServices and WGL Midstream, respectively. At September 30, 2014, the guarantees relating to WGESystems totaled $6.0 million. The amount of such guarantees is periodically adjusted to reflect changes in the level of financial exposure related to these purchase commitments. For all of our financial guarantees, WGL may cancel any or all future obligations upon written notice to the counterparty, but WGL would continue to be responsible for the obligations created under the guarantees prior to the effective date of the cancellation. WGL also has guaranteed payments for certain of our other external partners. At September 30, 2014, these guarantees totaled $18.7 million.At September 30, 2014, WGL's guarantees for all its subsidiaries and external partners totaled $528.5 million. The fair value of these guarantees was insignificant at September 30, 2014.

Legal Matters

WGL has been cooperating with a Department of Justice (“the Department”) investigation of some of the federal contracting activities of one of its non-utility subsidiaries, WGESystems. The Department's investigation concerned certain American Recovery and Reinvestment Act projects bid out by the General Services Administration in 2010, in which WGESystems participated as a subcontractor to an 8(a) prime contractor under the Small Business Administration's 8(a) Business Development Program. As discussed in more detail in Note 20—Subsequent Events, on November 18, 2014, WGESystems entered into a deferred prosecution agreement with the Department, which will resolve the investigation.

We accrued approximately $2.6 million, representing the fine and monetary penalty to be paid to the Department in connection with this matter, in the fourth quarter of 2014.

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Operating Segment Reporting (Tables)

12 Months Ended

Sep. 30, 2014

Segment Reporting Information Operating Income Loss Table [Abstract]

Operating Segment Financial Information

Operating Segment Financial Information
						Non-Utility Operations
(In thousands)				Regulated Utility		Retail Energy-Marketing	Commercial Energy Systems		Midstream Energy Services		Other Activities		Eliminations(b)		Consolidated
Year Ended September 30, 2014
Operating Revenues (a)			$	1,443,800	$	1,310,279	$	40,679	$	16,555	$	-	$	(30,366)	$	2,780,947
Operating Expenses:
	Cost of Energy-Related Sales			726,879		1,238,970		20,348		-		-		(30,613)		1,955,584
	Operation			234,391		43,750		10,419		8,517		11,749		75		308,901
	Maintenance			56,972		-		-		-		-		-		56,972
	Depreciation and Amortization			104,064		756		6,178		124		-		(350)		110,772
	General Taxes and Other Assessments:
		Revenue Taxes		84,287		8,276		5		-		-		-		92,568
		Other		53,402		4,615		253		274		84		-		58,628
		Total Operating Expenses	$	1,259,995	$	1,296,367	$	37,203	$	8,915	$	11,833	$	(30,888)	$	2,583,425
Operating Income (Loss)				183,805		13,912		3,476		7,640		(11,833)		522		197,522
Equity in Earnings of Unconsolidated Affiliates				-		1		1,953		771		469		-		3,194
Other Income (Expense)—Net				863		103		1,007		(239)		(198)		-		1,536
Interest Expense				37,127		10		-		-		601		-		37,738
Dividends on Washington Gas Preferred Stock				1,320		-		-		-		-		-		1,320
Income Tax Expense				48,181		5,764		1,019		1,969		111		210		57,254
Net Income (Loss) Applicable to Common Stock			$	98,040	$	8,242	$	5,417	$	6,203	$	(12,274)	$	312	$	105,940
Total Assets at September 30, 2014			$	3,979,522	$	389,700	$	521,570	$	211,824	$	369,816	$	(615,933)	$	4,856,499
Capital Expenditures			$	286,323	$	76	$	108,363	$	-	$	-	$	-	$	394,762
Equity Method Investments at September 30, 2014			$	-	$	-	$	66,810	$	28,076	$	16	$	-	$	94,902
(a)Operating revenues are reported gross of revenue taxes. Revenue taxes of both the regulated utility and the retail energy-marketing segments include gross receipt taxes. Revenue taxes of the regulated utility segment also include PSC fees, franchise fees and energy taxes. Operating revenue amounts in the "Eliminations" column represent total intersegment revenues associated with sales from the regulated utility segment to the retail energy-marketing segment. Midstream Energy Services' cost of energy related sales is netted with its gross revenues.
(b)Intersegment eliminations net income includes a timing difference between Commercial Energy Systems' recognition of revenue for the sale of Solar Renewable Energy Credits (SRECs) to Retail Energy-Marketing and Retail Energy's Marketing's recognition of the associate expense. Retail Energy-Marketing has recorded a portion of the SREC's purchased as inventory to be used in future periods at which time they will be expensed.

Operating Segment Financial Information
						Non-Utility Operations
(In thousands)				Regulated Utility		Retail Energy-Marketing	Commercial Energy Systems		Midstream Energy Services		Other Activities		Eliminations(b)			Consolidated
Year Ended September 30, 2013
Operating Revenues(a)			$	1,200,357	$	1,279,364	$	35,217	$	(20,390)	$	-	$	(28,410)	$	2,466,138
Operating Expenses:
	Cost of Energy-Related Sales			521,508		1,164,831		24,450		-		-		(26,458)		1,684,331
	Operation			243,341		49,574		6,875		8,683		9,344		(197)		317,620
	Maintenance			49,269		-		-		-		-		-		49,269
	Depreciation and Amortization			100,438		726		2,411		124		-		(415)		103,284
	General Taxes and Other Assessments:
		Revenue Taxes		81,422		6,831		7		-		-		-		88,260
		Other		52,271		4,411		303		474		97		-		57,556
		Total Operating Expenses	$	1,048,249	$	1,226,373	$	34,046	$	9,281	$	9,441	$	(27,070)	$	2,300,320
Operating Income (Loss)				152,108		52,991		1,171		(29,671)		(9,441)		(1,340)		165,818
Equity in Earnings of Unconsolidated Affiliates				-		-		1,070		312		128		-		1,510
Other Income (Expense)—Net				1,539		273		778		-		644		(686)		2,548
Interest Expense				35,631		13		234		417		402		(686)		36,011
Dividends on Washington Gas Preferred Stock				1,320		-		-		-		-		-		1,320
Income Tax Expense (Benefit)				44,883		20,227		(206)		(10,951)		(1,124)		(537)		52,292
Net Income (Loss) Applicable to Common Stock			$	71,813	$	33,024	$	2,991	$	(18,825)	$	(7,947)	$	(803)	$	80,253
Total Assets at September 30, 2013			$	3,486,296	$	403,082	$	318,995	$	231,368	$	290,440	$	(470,121)	$	4,260,060
Capital Expenditures			$	227,948	$	730	$	83,667	$	-	$	-	$	-	$	312,345
Equity Method Investments at September 30, 2013			$	-	$	-	$	54,977	$	6,507	$	413	$	-	$	61,897
(a)Operating revenues are reported gross of revenue taxes. Revenue taxes of both the regulated utility and the retail energy-marketing segments include gross receipt taxes. Revenue taxes of the regulated utility segment also include PSC fees, franchise fees and energy taxes. Operating revenue amounts in the "Eliminations" column represent total intersegment revenues associated with sales from the regulated utility segment to the retail energy-marketing segment. Midstream Energy Services' cost of energy related sales is netted with its gross revenues.
(b)Intersegment eliminations net income includes a timing difference between Commercial Energy Systems' recognition of revenue for the sale of Solar Renewable Energy Credits (SRECs) to Retail Energy- Marketing and Retail Energy's Marketing's recognition of the associate expense. Retail Energy- Marketing has recorded a portion of the SREC's purchased as inventory to be used in future periods at which time will be expensed.

Operating Segment Financial Information
						Non-Utility Operations
(In thousands)				Regulated Utility		Retail Energy-Marketing	Commercial Energy Systems		Midstream Energy Services		Other Activities		Eliminations(b)			Consolidated
Year Ended September 30, 2012
Operating Revenues			$	1,137,666	$	1,267,070	$	60,325	$	(11,221)	$	-	$	(28,530)	$	2,425,310
Operating Expenses:
	Cost of Energy-Related Sales			421,539		1,139,162		51,149		-		-		(26,802)		1,585,048
	Operation			227,362		52,161		5,414		2,860		3,612		(1,093)		290,316
	Maintenance			52,494		-		-		-		-		-		52,494
	Depreciation and Amortization			94,998		735		1,261		116		-		(634)		96,476
	General Taxes and Other Assessments:
		Revenue Taxes		74,244		5,776		8		-		-		-		80,028
		Other		50,822		4,070		280		240		16		(1)		55,427
		Total Operating Expenses	$	921,459	$	1,201,904	$	58,112	$	3,216	$	3,628	$	(28,530)	$	2,159,789
Operating Income (Loss)				216,207		65,166		2,213		(14,437)		(3,628)		-		265,521
Equity in Earnings of Unconsolidated Affiliates				-		-		947		-		293		-		1,240
Other Income—Net				3,085		42		(32)		-		1,097		(38)		4,154
Interest Expense				36,098		1		1		-		366		(38)		36,428
Dividends on Washington Gas Preferred Stock				1,320		-		-		-		-		-		1,320
Income Tax Expense (Benefit)				72,178		25,876		760		(5,347)		(118)		-		93,349
Net Income (Loss) Applicable to Common Stock			$	109,696	$	39,331	$	2,367	$	(9,090)	$	(2,486)	$	-	$	139,818
Total Assets at September 30, 2012			$	3,516,046	$	361,801	$	148,407	$	169,456	$	211,038	$	(295,801)	$	4,110,947
Capital Expenditures			$	208,225	$	984	$	41,818	$	101	$	-	$	-	$	251,128
Equity Method Investments at September 30, 2012			$	-	$	-	$	23,346	$	-	$	-	$	-	$	23,346
(a)Operating revenues are reported gross of revenue taxes. Revenue taxes of both the regulated utility and the retail energy-marketing segments include gross receipt taxes. Revenue taxes of the regulated utility segment also include PSC fees, franchise fees and energy taxes. Operating revenue amounts in the "Eliminations" column represent total intersegment revenues associated with sales from the regulated utility segment to the retail energy-marketing segment. Midstream Energy Services' cost of energy related sales is netted with its gross revenues.
(b)Intersegment eliminations net income includes a timing difference between Commercial Energy Systems' recognition of revenue for the sale of Solar Renewable Energy Credits (SRECs) to Retail Energy-Marketing and Retail Energy's Marketing's recognition of the associate expense. Retail Energy-Marketing has recorded a portion of the SREC's purchased as inventory to be used in future periods at which time they will be expensed.

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Common Stock (Tables)

12 Months Ended

Sep. 30, 2014

Common Stock Tables [Abstract]

Common Stock Reserves

Common Stock Reserves
Reserve for:	Number of Shares
Omnibus incentive compensation plan(a)	999,443
Dividend reinvestment and common stock purchase plan	2,849,012
Employee savings plans	637,196
Directors’ stock compensation plan	96,650
Total common stock reserves	4,582,301
(a)In March 2007, WGL adopted a shareholder-approved Omnibus Incentive Compensation Plan to replace on a prospective basis the 1999 Incentive Compensation Plan. Included are shares that may be issued which would reduce the number of shares authorized under the Omnibus Incentive Compensation Plan. These shares include 301,378 shares dedicated to performance shares granted but not vested and include 5,318 shares dedicated to stock options issued but not exercised. Refer to Note 11 - Stock-Based Compensation for a discussion regarding our stock-based compensation plans.

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Pension and Other Post-retirement Benefit Plans (Table 3) (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013
Footnote Details [Abstract]
Accumulated Other Comprehensive Loss Tax Effect	$ 4.9		$ 7.9
Pension Plans Defined Benefit [Member]
Unrecognized Costs/Income Recorded on the Balance Sheet
Unrecognized actuarial net loss	162.6		171.1
Unrecognized prior service cost (credit)	1.2		1.3
Total	163.8		172.4
Regulatory asset	147.9		155.1
Defined Benefit Plan Recorded On Balance Sheet Before Tax	163.8		172.4
Footnote Details [Abstract]
Accumulated Other Comprehensive Loss Tax Effect	15.9	[1]	17.3	[1]
Other PostretirementBenefit Plans Defined Benefit [Member]
Unrecognized Costs/Income Recorded on the Balance Sheet
Unrecognized actuarial net loss	50.1		55.3
Unrecognized prior service cost (credit)	(149.3)		(22.4)
Total	(99.2)		32.9
Regulatory asset	(94.6)		31.3
Defined Benefit Plan Recorded On Balance Sheet Before Tax	(99.2)		32.9
Footnote Details [Abstract]
Accumulated Other Comprehensive Loss Tax Effect	$ (4.6)	[1]	$ 1.6	[1]

[1] The total amount of accumulated other comprehensive loss recorded on our balance sheets at September 30, 2014 and 2013 is net of an income tax benefit of $4.9 million and $7.9 million, respectively.

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Fair Value Measurements (Realized and Unrealized Gains and Losses with Level 3 Measurements) (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
WGL Holdings, Inc.
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	$ (79.4)	$ (94.8)	$ (16.8)
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to regulatory assets - gas costs	(109.9)	(111.6)	23.2
Total Unrealized Gains (Losses)	(176.7)	(175.3)	62.0
WGL Holdings, Inc. | Natural Gas Related Derivatives [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	(72.6)	(72.4)	22.1
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to regulatory assets - gas costs	(109.9)	(111.6)	23.2
Total Unrealized Gains (Losses)	(171.8)	(181.0)	42.1
WGL Holdings, Inc. | Electricity Related Derivatives [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	(5.7)	(23.8)	(47.7)
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to regulatory assets - gas costs	0	0	0
Total Unrealized Gains (Losses)	(3.8)	5.5	18.8
WGL Holdings, Inc. | Weather Instruments [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	1.2	7.9
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to regulatory assets - gas costs	0	0	0
Total Unrealized Gains (Losses)	0	0	0.2
WGL Holdings, Inc. | Warrant
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	(1.1)	0.2	0.9
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to regulatory assets - gas costs	0	0	0
Total Unrealized Gains (Losses)	(1.1)	0.2	0.9
WGL Holdings, Inc. | Operating Revenues Non Utility [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	(24.4)	(36.1)	(11.2)
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	(38.8)	(18.7)	9.1
WGL Holdings, Inc. | Operating Revenues Non Utility [Member] | Natural Gas Related Derivatives [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	(2.3)	(27.0)	3.0
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	(5.0)	(25.3)	4.3
WGL Holdings, Inc. | Operating Revenues Non Utility [Member] | Electricity Related Derivatives [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	(22.1)	(9.1)	(14.2)
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	(33.8)	6.6	4.8
WGL Holdings, Inc. | Operating Revenues Non Utility [Member] | Weather Instruments [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	0	0
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	0	0	0
WGL Holdings, Inc. | Operating Revenues Non Utility [Member] | Warrant
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	0	0
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	0	0	0
WGL Holdings, Inc. | Utility Cost Of Gas [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	(69.4)	(45.8)	14.3
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	(60.6)	(44.3)	13.8
WGL Holdings, Inc. | Utility Cost Of Gas [Member] | Natural Gas Related Derivatives [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	(69.4)	(45.8)	14.3
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	(60.6)	(44.3)	13.8
WGL Holdings, Inc. | Utility Cost Of Gas [Member] | Electricity Related Derivatives [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	0	0
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	0	0	0
WGL Holdings, Inc. | Utility Cost Of Gas [Member] | Weather Instruments [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	0	0
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	0	0	0
WGL Holdings, Inc. | Utility Cost Of Gas [Member] | Warrant
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	0	0
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	0	0	0
WGL Holdings, Inc. | OtherIncomeMember
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	(1.1)	0.2	0.9
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	(1.1)	0.2	0.9
WGL Holdings, Inc. | OtherIncomeMember | Natural Gas Related Derivatives [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	0	0
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	0	0	0
WGL Holdings, Inc. | OtherIncomeMember | Electricity Related Derivatives [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	0	0
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	0	0	0
WGL Holdings, Inc. | OtherIncomeMember | Weather Instruments [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	0	0
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	0	0	0
WGL Holdings, Inc. | OtherIncomeMember | Warrant
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	(1.1)	0.2	0.9
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	(1.1)	0.2	0.9
WGL Holdings, Inc. | Non Utility Cost Of Energy Related Sales [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	15.5	(14.3)	(28.7)
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	33.7	(0.9)	14.8
WGL Holdings, Inc. | Non Utility Cost Of Energy Related Sales [Member] | Natural Gas Related Derivatives [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	(0.9)	0.4	4.8
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	3.7	0.2	0.8
WGL Holdings, Inc. | Non Utility Cost Of Energy Related Sales [Member] | Electricity Related Derivatives [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	16.4	(14.7)	(33.5)
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	30.0	(1.1)	14.0
WGL Holdings, Inc. | Non Utility Cost Of Energy Related Sales [Member] | Weather Instruments [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	0	0
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	0	0	0
WGL Holdings, Inc. | Non Utility Cost Of Energy Related Sales [Member] | Warrant
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	0	0
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	0	0	0
WGL Holdings, Inc. | Operation And Maintenance Expense [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	1.2	7.9
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	0	0	0.2
WGL Holdings, Inc. | Operation And Maintenance Expense [Member] | Natural Gas Related Derivatives [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	0	0
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	0	0	0
WGL Holdings, Inc. | Operation And Maintenance Expense [Member] | Electricity Related Derivatives [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	0	0
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	0	0	0
WGL Holdings, Inc. | Operation And Maintenance Expense [Member] | Weather Instruments [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	1.2	7.9
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	0	0	0.2
WGL Holdings, Inc. | Operation And Maintenance Expense [Member] | Warrant
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	0	0
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	0	0	0
Washington Gas Light Company
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	(69.4)	(44.7)	22.2
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to regulatory assets - gas costs	(109.9)	(111.6)	23.2
Total Unrealized Gains (Losses)	(170.5)	(155.9)	37.2
Washington Gas Light Company | Natural Gas Related Derivatives [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	(69.4)	(45.9)	14.3
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to regulatory assets - gas costs	(109.9)	(111.6)	23.2
Total Unrealized Gains (Losses)	(170.5)	(155.9)	37.0
Washington Gas Light Company | Electricity Related Derivatives [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	0	0
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to regulatory assets - gas costs	0	0	0
Total Unrealized Gains (Losses)	0	0	0
Washington Gas Light Company | Weather Instruments [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	1.2	7.9
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to regulatory assets - gas costs	0	0	0
Total Unrealized Gains (Losses)	0	0	0.2
Washington Gas Light Company | Warrant
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	0	0
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to regulatory assets - gas costs	0	0	0
Total Unrealized Gains (Losses)	0	0	0
Washington Gas Light Company | Utility Cost Of Gas [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	(69.4)	(45.9)	14.3
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	(60.6)	(44.3)	13.8
Washington Gas Light Company | Utility Cost Of Gas [Member] | Natural Gas Related Derivatives [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	(69.4)	(45.9)	14.3
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	(60.6)	(44.3)	13.8
Washington Gas Light Company | Utility Cost Of Gas [Member] | Electricity Related Derivatives [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	0	0
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	0	0	0
Washington Gas Light Company | Utility Cost Of Gas [Member] | Weather Instruments [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	0	0
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	0	0	0
Washington Gas Light Company | Utility Cost Of Gas [Member] | Warrant
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	0	0
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	0	0	0
Washington Gas Light Company | Operation And Maintenance Expense [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	1.2	7.9
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	0	0	0.2
Washington Gas Light Company | Operation And Maintenance Expense [Member] | Natural Gas Related Derivatives [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	0	0
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	0	0	0
Washington Gas Light Company | Operation And Maintenance Expense [Member] | Electricity Related Derivatives [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	0	0
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	0	0	0
Washington Gas Light Company | Operation And Maintenance Expense [Member] | Weather Instruments [Member]
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	1.2	7.9
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	0	0	0.2
Washington Gas Light Company | Operation And Maintenance Expense [Member] | Warrant
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	0	0	0
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	$ 0	$ 0	$ 0

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Regulated Operations (Table)

12 Months Ended

Sep. 30, 2014

Regulatory Assets and Liabilities Disclosure [Abstract]

Schedule of Regulatory Assets and Liabilities [Text Block]

Regulatory Assets and Liabilities
		Regulatory				Regulatory
(In millions)		Assets				Liabilities
September 30,		2014		2013		2014		2013
Current:
Gas costs due from/to customers(a)	$	-	$	-	$	16.2	$	23.4
Interruptible sharing(a)		3.4		10.7		-		1.9
Revenue normalization mechanisms for Maryland and Virginia(a)		-		0.1		5.5		1.5
Plant recovery mechanisms		0.4		-		0.9		0.2
Total current	$	3.8	$	10.8	$	22.6	$	27.0
Deferred:
Accrued asset removal costs	$	-	$	-	$	327.4	$	321.3
Deferred gas costs(a)		191.3		94.0		-		-
Pension and other post-retirement benefits
Other post-retirement benefit costs—trackers(b)		-		0.7		-		-
Deferred pension costs/income—trackers(b)		45.1		51.0		-		-
ASC Topic 715 unrecognized costs/income(a)(c)
Pensions		147.9		155.1		-		-
Other post-retirement benefits		-		33.8		86.4		-
Total pension and other post-retirement benefits		193.0		240.6		86.4		-
Other
Income tax-related amounts due from/to customers(d)		30.4		24.9		4.8		4.5
Losses/gains on issuance and extinguishments of
debt and interest-rate derivative instruments(a)(e)		12.0		11.6		1.7		0.6
Deferred gain on sale of assets(a)		-		-		1.4		1.7
Rights-of-way fees(a)		1.5		-		-		1.6
Other costs—Business process outsourcing (a)		1.0		1.4		-		-
Nonretirement postemployment benefits(a)(f)		16.3		15.4		-		-
Deferred integrity management expenditures(a)(g)		2.7		-		-		-
Recoverable portion of abandoned LNG facility(a)		5.6		7.9		-		-
Other regulatory expenses(a)		2.1		4.8		9.7		5.1
Total other	$	71.6	$	66.0	$	17.6	$	13.5
Total deferred	$	455.9	$	400.6	$	431.4	$	334.8
Total	$	459.7	$	411.4	$	454.0	$	361.8
(a) Washington Gas does not earn its overall rate of return on these assets. Washington Gas is allowed to recover and required to pay, using short-term interest rates, the carrying costs related to billed gas costs due from and to its customers in the District of Columbia and Virginia jurisdictions.
(b) Relates to the District of Columbia jurisdiction.
(c) Refer to Note 10-Pension and Other Post-Retirement Benefit Plans for a further discussion of these amounts.
(d) This balance represents amounts due from customers for deferred tax liabilities related to tax benefits on deduction flowed directly to customers prior to the adoption of income tax normalization for ratemaking purposes.
(e) The losses or gains on the issuance and extinguishment of debt and interest-rate derivative instruments include unamortized balances from transactions executed in prior fiscal years. These transactions create gains and losses that are amortized over the remaining life of the debt as prescribed by regulatory accounting requirements.
(f) Represents the timing difference between the recognition of workers compensation and short-term disability costs in accordance with generally accepted accounting principles and the way these costs are recovered through rates.
(g)This balance represents amounts for deferred expenditures associated with Washington Gas' Distribution Integrity Management Program (DIMP) in Virginia.

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Other Investment (Tables)

12 Months Ended

Sep. 30, 2014

Other Investments [Abstract]

Minimum Payments Receivable for Direct Financing Leases

Minimum Payments Receivable for Direct Financing Leases
(In millions)
2015	$	2.3
2016		2.0
2017		1.9
2018		1.8
2019		1.7
Thereafter		12.3
Total	$	22.0

Location of Investments

WGL Holdings, Inc Balance Sheet Location of Other Investments
As of September 30, 2014 (in millions)		VIEs		Non-VIEs		Total
Assets
Investments in unconsolidated affiliates	$	72.6	$	27.9	$	100.5
Investments in direct financing leases, capital leases		18.2		-		18.2
Accounts receivable		1.7		-		1.7
Total assets	$	92.5	$	27.9	$	120.4

WGL Holdings, Inc. Balance Sheet Location of Other Investments
As of September 30, 2013 (in millions)		VIEs		Non-VIEs		Total
Assets
Investments in unconsolidated affiliates	$	55.4	$	12.1	$	67.5
Investments in direct financing leases, capital leases		23.4		-		23.4
Deferred charges and other assets- derivatives		-		1.1		1.1
Accounts receivable		5.8		-		5.8
Total assets	$	84.6	$	13.2	$	97.8
Liabilities
Other	$	8.5	$	-	$	8.5
Total liabilities	$	8.5	$	-	$	8.5

WGL Holdings, Inc.
Income Statement Location of Other Investments
	Fiscal year ended
	September 30, 2014
(in millions)	VIEs			Non-VIEs	Total
Equity in earnings of unconsolidated affiliates	$	2.2	$	1.0	$	3.2
Depreciation and amortization	$	0.2	$	-	$	0.2
Other income - net	$	2.6		-		2.6
Net Income	$	4.6	$	1.0	$	5.6

WGL Holdings, Inc.
Income Statement Location of Other Investments
	Fiscal year ended
	September 30, 2013
(in millions)	VIEs			Non-VIEs	Total
Equity in earnings of unconsolidated affiliates	$	1.0	$	0.5	$	1.5
Depreciation and amortization		0.1		-		0.1
Other income- net		1.4		-		1.4
Net Income	$	2.3	$	0.5	$	2.8

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Income Taxes (Narrative) (Details) (Washington Gas Light Company, USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2010
Washington Gas Light Company
Tax savings realized from tax sharing agreement	$ 2.9	$ 1.3	$ 0.3
Increase In Regulatory Assets For Recovery Of Increased Taxes				42.2
Unrecognized Tax Benefits, Period Increase (Decrease)	7.6
Interest Expense For Uncertain Tax Position	0	0	(1.6)
Effective Income Tax Rate, Continuing Operations	32.58%	37.93%	39.47%
Tax expense related to the Patient Protection and Affordable Care Act				$ 0

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Schedule II (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2012
WGL Holdings, Inc.
Valuation and Qualifying Accounts Disclosure [Line Items]
Valuation Allowances and Reserves, Beginning Balance	$ 20,433		$ 19,792		$ 17,969
Valuation Allowances and Reserves, Charged to Cost and Expense	15,874		9,527		18,316
Valuation Allowances and Reserves, Charged to Other Accounts	4,341	[1]	4,217	[1]	4,774	[1]
Valuation Allowances and Reserves, Deductions	17,307	[2]	13,103	[2]	21,267	[2]
Valuation Allowances and Reserves, Ending Balance	23,341		20,433		19,792
Washington Gas Light Company
Valuation and Qualifying Accounts Disclosure [Line Items]
Valuation Allowances and Reserves, Beginning Balance	17,498		17,129		15,863
Valuation Allowances and Reserves, Charged to Cost and Expense	12,004		7,024		12,794
Valuation Allowances and Reserves, Charged to Other Accounts	4,198	[1]	3,978	[1]	4,300	[1]
Valuation Allowances and Reserves, Deductions	14,491	[2]	10,633	[2]	15,828	[2]
Valuation Allowances and Reserves, Ending Balance	$ 19,209		$ 17,498		$ 17,129

[1] Recoveries on receivables previously written off as uncollectible and unclaimed customer deposits, overpayments, etc., not refundable.

[2] Includes deductions for purposes for which reserves were provided or revisions made of estimated exposure.

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Long Term Debt (Narrative) (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Long Term Debt Narrative [Abstract]
Medium Term Notes	$ 691.0	$ 583.0
Long Term Debt Weighted Average Interest Rate	5.65%	5.91%
Shelf Registration	On August 18, 2014, WGL entered into an Indenture with The Bank of New York Mellon (the "Trustee") to issue an unlimited amount of debt securities. Supplemental indentures will supplement the Indenture and establish the respective terms of the notes. The offering of the notes has been registered under a shelf registration statement on Form S-3. At September 30, 2014, Washington Gas had the capacity under a shelf registration to issue up to $275.0 million of additional MTNs.
Mortgage Debt Outstanding	$ 0	$ 0

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Stock Based Compensation (Tables)

12 Months Ended

Sep. 30, 2014

Performance Share Activity

Performance Share Activity
	Year Ended
	September 30, 2014
	Number of Shares(a)	Weighted Average Grant-Date Fair Value
Non-vested and outstanding, beginning of year	295,973	$	39.88
Granted	109,076		42.88
Vested	(84,849)		41.14
Cancelled/forfeited	(18,822)		40.47
Non-vested and outstanding, end of year	301,378	$	40.57
(a)The number of common shares issued related to performance shares may range from zero to 200 percent of the number of shares shown in the table above based on our achievement of performance goals for total shareholder return relative to a selected peer group of companies.

Performance Share Fair Value Assumptions

Fair Value Assumptions
Years Ended September 30,	2014			2013			2012
Expected stock-price volatility		19.10	%		19.40	%		27.80	%
Dividend yield		3.93	%		3.98	%		3.97	%
Weighted average grant-date fair value	$	42.88		$	39.73		$	38.99

Performance Unit Activity

Performance Unit Activity
	Year Ended
	September 30, 2014
	Number of Units
Non-vested and outstanding, beginning of year	11,582,556
Granted	4,658,648
Vested	(3,205,636)
Cancelled/forfeited	(766,647)
Non-vested and outstanding, end of year	12,268,921

Performance Units Fair Value Assumptions

Fair Value Assumptions
	September 30, 2014
	10/1/2013 Grant	10/1/2012 Grant
Expected stock-price volatility	18.1%	19.5%

Stock Option Activity

Stock Option Activity
	Number of Options	Weighted Average Exercise Price		Weighted Average Remaining Contractual Term (In years)	Aggregate Intrinsic Value (In thousands)
Outstanding at September 30, 2013	26,372	$	31.34	4.01	$	235
Granted	-		-	-		-
Exercised	(21,054)		31.34	-		232
Cancelled/forfeited	-		-	-		-
Outstanding at September 30, 2014	5,318	$	31.34	2.00	$	57
Exercisable at September 30, 2014	5,318	$	31.34	2.00	$	57

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Consolidated Statement of Capitalization - WGL (Parenthetical) (USD $)	Sep. 30, 2014	Sep. 30, 2013
Washington Gas Light Company
Common Shareholders' Equity
Common Stock, Par or Stated Value Per Share	$ 1	$ 1
Common Stock, Shares Authorized	80,000,000	80,000,000
Common Stock, Shares, Issued	46,479,536	46,479,536
Preferred Stock [Abstract]
Preferred Stock, Shares Authorized	1,500,000	1,500,000
Preferred Stock [Member]
Preferred Stock [Abstract]
Preferred Stock, Shares Authorized	1,500,000	1,500,000
Preferred Stock, Par or Stated Value Per Share	$ 0	$ 0
Series One [Member] | Washington Gas Light Company
Preferred Stock [Abstract]
Preferred Stock, Shares Outstanding	150,000	150,000
Preferred Stock, Par or Stated Value Per Share	$ 4.80	$ 4.80
Series Two [Member] | Washington Gas Light Company
Preferred Stock [Abstract]
Preferred Stock, Shares Outstanding	70,600	70,600
Preferred Stock, Par or Stated Value Per Share	$ 4.25	$ 4.25
Series Three [Member] | Washington Gas Light Company
Preferred Stock [Abstract]
Preferred Stock, Shares Outstanding	60,000	60,000
Preferred Stock, Par or Stated Value Per Share	$ 5.00	$ 5.00

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Long-Term Debt - Maturities (Details) (USD $)	Sep. 30, 2014
Footnote Details [Abstract]
Unamortized Discount on Long Term Debt Maturities	$ 121,567
Statement [Line Items]
2015	20,000,000	[1]
2016	25,000,000	[1]
2017	0	[1]
2018	0	[1]
2019	50,000,000	[1]
Thereafter	596,000,000	[1]
Total (before project debt financing)	691,000,000	[1]
Long Term Debt Project Financing	8,300,000	[1],[2]
Total	699,300,000	[1]
Less-current maturities	20,000,000	[1]
Total non-current	679,300,000	[1]
Medium-term Notes [Member]
Statement [Line Items]
2015	20,000,000	[1]
2016	25,000,000	[1]
2017	0	[1]
2018	0	[1]
2019	50,000,000	[1]
Thereafter	596,000,000	[1]
Total (before project debt financing)	691,000,000	[1]
Long Term Debt Project Financing	0	[1],[2]
Total	691,000,000	[1]
Less-current maturities	20,000,000	[1]
Total non-current	671,000,000	[1]
Other Long Term Debt [Member]
Statement [Line Items]
Long Term Debt Project Financing	8,300,000	[1],[2]
Total	8,300,000	[1]
Less-current maturities	0	[1]
Total non-current	$ 8,300,000	[1]

[1] Excludes unamortized discounts of $121,567 at September 30, 2014.

[2] Project debt financing is anticipated to be a non-cash extinguishment. Refer to Note 13 - Commitments and Contingencies for further discussion of this construction project financing.

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Preferred Stock (Tables)

12 Months Ended

Sep. 30, 2014

Preferred Stock Tables [Abstract]

Preferred Stock Table

Preferred Stock
Preferred		Liquidation Preference
Series	Shares		Per Share				Call Price
Outstanding	Outstanding		Involuntary		Voluntary		Per Share
$4.80	150,000	$100		$101		$101
$4.25	70,600	$100		$105		$105
$5.00	60,000	$100		$102		$102

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Other Investments

12 Months Ended

Sep. 30, 2014

Other Investments [Abstract]

Investment [Text Block]

NOTE 17. OTHER INVESTMENTS

When determining how to account for our interests in other legal entities, WGL first evaluates if we are required to apply the variable interest entity (VIE) model to the entity, otherwise the entity is evaluated under the voting interest model.

Under the VIE model, we have a controlling financial interest in a VIE (i.e. are the primary beneficiary) when we have current or potential rights that give us the power to direct the activities of a VIE that most significantly impact the VIE's economic performance combined with a variable interest that gives us the right to receive potentially significant benefits or the obligation to absorb potentially significant losses. When changes occur to the design of an entity we reconsider whether it is subject to the VIE model. We continuously evaluate whether we have a controlling financial interest in a VIE.

Under the voting interest model, we generally have a controlling financial interest in an entity where we currently hold, directly or indirectly, more than 50% of the voting rights or where we exercise control through substantive participating rights. However, we consider substantive rights held by other partners in determining if we hold a controlling financial interest, and in some cases, despite owning more than 50% of the common stock of an investee, an evaluation of our rights results in the determination that we do not have a controlling financial interest. We reevaluate whether we have a controlling financial interest in these entities when our voting or substantive participating rights change.

Unconsolidated affiliates are unconsolidated VIEs and other entities evaluated under the voting interest method in which we do not have a controlling financial interest, but over which we have varying degrees of influence. Where we have significant influence, the affiliates are accounted for as equity method investments. Where we do not have significant influence, the affiliates are accounted for under the cost method. Investments in, and advances to, affiliated companies are presented on a one-line basis in the caption “Investments in unconsolidated affiliates” on our Consolidated Balance Sheet.

WGL uses the Hypothetical Liquidation at Book Value (HLBV) methodology for certain equity method investments when the capital structure of the equity investment results in different liquidation rights and priorities than what is reflected by the underlying percentage ownership interests as defined by an equity investment agreement. For investments accounted for under the HLBV method, simply applying the percentage ownership interest to GAAP net income in order to determine earnings or losses does not accurately represent the income allocation and cash flow distributions that will ultimately be received by the investors. The equity investment agreements for ASD Solar, LP (ASD) and Meade Pipeline Co LLC (Meade) both have liquidation rights and priorities that are sufficiently different from the ownership percentages that the HLBV method was deemed appropriate.

WGL applies HLBV using a balance sheet approach. A calculation is prepared at each balance sheet date to determine the amount that WGL would receive if an equity investment entity were to liquidate all of its assets (as valued in accordance with GAAP) and distribute that cash to the investors based on the contractually defined liquidation priorities. The difference between the calculated liquidation distribution amounts at the beginning and the end of the reporting period is WGL's share of the earnings or losses from the equity investment for the period. The calculation may vary in its complexity depending on the capital structure and the tax considerations for the investments.

Variable Interest Entities

WGL has a variable interest in five investments that qualify as VIEs:

• Meade,
• SunEdison,
• Nextility,
• ASD Solar LP and
• Crab Run.

WGL and its subsidiaries are not the primary beneficiary for any of the above VIEs, therefore we have not consolidated any of the VIE entities. At September 30, 2014, the nature of WGL's involvement with these investments lacks the characteristics of a controlling financial interest. WGL does not have control over any of the VIEs' activities that are economically significant to the VIEs. In addition, WGL does not have the obligation to absorb expected losses or the right to receive expected gains that could be significant to the VIE.

Meade

On February 14, 2014, WGL, through its subsidiary WGL Midstream, entered into a limited liability company agreement and formed Meade, a Delaware limited liability company with COG Holdings LLC, Vega Midstream MPC LLC and River Road Interests LLC. Meade was formed to partner with Transcontinental Gas Pipeline Company, LLC (Williams) to invest in a regulated pipeline project called Central Penn Pipeline (Central Penn). The Central Penn will be an approximately 177 mile pipeline originating in Susquehanna County, Pennsylvania and extending to Lancaster County, Pennsylvania that will have the capacity to transport and deliver up to approximately 1.7 million dekatherms per day of natural gas.

WGL Midstream plans to invest an estimated $410.0 million for a 55% interest in Meade. WGL Midstream joins COG Holdings LLC (20% share), Vega Midstream MPC LLC (15% share) and River Road Interests LLC (10% share) in Meade. Meade is accounted for under the HLBV equity method of accounting, and any profits and losses are included in “Equity in earnings of unconsolidated affiliates” in the accompanying Consolidated Statement of Income and are added to or subtracted from the carrying amount of WGL's investment balance. WGL Midstream held a $5.8 million equity method investment in Meade at September 30, 2014.

Our maximum financial exposure includes contributions and guarantees on behalf of WGL Midstream. In addition, we have guaranteed the future commitments of one of the other partners in the venture. Our maximum exposure to loss at September 30, 2014 was $74.0 million, which represents the minimum funding requirements owed to Williams under the Construction and Ownership Agreement should Meade terminate its agreement with Williams early and the guarantee on behalf of one of the other partners.

SunEdison/Nextility

WGSW is party to three agreements to fund residential and commercial retail solar energy installations with three separate, privately held companies. WGSW has a master purchase agreement and master lease agreement with SunEdison, Inc. (SunEdison), formerly known as EchoFirst Finance Company LLC (EchoFirst) andNextility, Inc. (Nextility), formerly known as Skyline Innovations, Inc (Skyline) for sale/leaseback arrangements for residential and commercial solar systems.

Our agreements with SunEdison and Nextility are accounted for as direct financing leases. WGSW records associated interest in the financing leases in "Other income (expenses)-net" line in the accompanying Consolidated Statement of Income. WGSW held a $19.9 million and $29.2 million combined investment in direct financing leases at September 30, 2014 and 2013, respectively, of which $1.7 million and $5.8 million are current receivables recorded in "Accounts Receivable" in the accompanying Consolidated Balance Sheets at September 30, 2014and 2013, respectively.

Minimum future lease payments receivable under direct financing leases over the next five fiscal years and thereafter are as follows:

Minimum Payments Receivable for Direct Financing Leases
(In millions)
2015	$	2.3
2016		2.0
2017		1.9
2018		1.8
2019		1.7
Thereafter		12.3
Total	$	22.0

Minimum payments receivable exclude $5.1 million of residual values and $3.0 million in tax credits. Associated with these investments, WGSW holds $10.2 million of unearned income on its balance sheet. The initial direct costs (incurred in FY 2012) associated with these investments was $0.7million.

Our maximum financial exposure from solar agreements is limited to its lease payment receivables and investment contributions made to these companies. All additional future committed contributions are contingent on the projects meeting required criteria. Our exposure is offset by the owned physical assets received as part of the transaction and the quick economic return for the investment through the investment tax credit/treasury grant proceeds and accelerated depreciation.

ASD Solar, LP

In addition to SunEdison/Skyline, WGSW is also a limited partner in ASD Solar, LP (ASD), a partnership formed to own and operate a portfolio of residential solar projects, primarily rooftop photovoltaic power generation systems. As a limited partner, WGSW provided funding to the partnership but is excluded from involvement in the partnership's operations. In January 2014, the funding commitment period expired for the partnership. WGSW's maximum financial exposure includes contributions made to the partnership.

Our investment in ASD is accounted for under the HLBV equity method of accounting; any profits and losses are included in “Equity in earnings of unconsolidated affiliates” in the accompanying Consolidated Statement of Income and are added to or subtracted from the carrying amount of WGSW's investment balance. WGSW held a $66.8 million equity method investment in ASD at September 30, 2014.

ASD is consolidated by the general partner, Solar Direct LLC. Solar Direct LLC is a wholly owned subsidiary of American Solar Direct Inc. (ASDI). At September 30, 2014, the carrying amount of WGSW's investment in ASD exceeded the amount of the underlying equity in net assets by $35.9 million due to WGSW recording additions to its investment in ASD's net assets at fair value of contributions in accordance with GAAP. This basis difference is being amortized over the life of the assets.

Crab Run

WGL owns all of the shares of common stock of Crab Run Gas Company. Crab Run Gas Company is an exploration and production company who is the limited partner in the Western/Crab Run Limited Partnership (Crab Run). The partnership was formed to manage oil and gas properties and perform oil and gas leasing, marketing and production activities.

Crab Run is accounted for under the equity method of accounting; any profits and losses are included in “Equity in earnings of unconsolidated affiliates” in the accompanying Consolidated Statement of Income and are added to or subtracted from the carrying amount of WGL's investment balance. WGL held a minimal portion of equity investment in Crab Run at September 30, 2014.

Non-VIE Investments

ASDHI

Washington Gas Resources held a $5.6 million investment in American Solar Direct Holdings Inc. (ASDHI), at both September 30, 2014 and 2013. This investment is recorded at cost. No identified events or changes in circumstances that may have a significant effect on the carrying value of this investment have occurred. At September 30, 2014 and 2013, Washington Gas Resources also held $0.8 million and $1.9 million, respectively, in warrants of ASDHI which were accounted for as derivatives and recorded at fair value.

Constitution

In May of 2013, WGL Midstream invested in Constitution Pipeline Company, LLC (Constitution). WGL Midstream will invest an estimated $72.0 million in the project for a 10% share in the pipeline venture. WGL Midstream joins Williams Partners L.P. (41% share), Cabot Oil and Gas

Corporation (25% share) and Piedmont Natural Gas (24% share) in the project.This natural gas pipeline venture will transportnatural gas per day from the Marcellus region in northern Pennsylvania to major northeastern markets.At September 30, 2014, WGL Midstream had invested $22.2 million. Constitution is accounted for under the equity method of accounting; any profits and losses are included in “Equity in earnings of unconsolidated affiliates” in the accompanying Consolidated Statement of Income and are added to or subtracted from the carrying amount of WGL's investment balance. The equity method is considered appropriate because Constitution is an LLC with specific ownership accounts and ownership between five and fifty percent resulting in WGL Midstream maintaining a more than minor influence over the partnership operating and financing policies.

The balance sheet location of the investments discussed in this footnote at September 30, 2014 and 2013 are as follows:

WGL Holdings, Inc Balance Sheet Location of Other Investments
As of September 30, 2014 (in millions)		VIEs		Non-VIEs		Total
Assets
Investments in unconsolidated affiliates	$	72.6	$	27.9	$	100.5
Investments in direct financing leases, capital leases		18.2		-		18.2
Accounts receivable		1.7		-		1.7
Total assets	$	92.5	$	27.9	$	120.4

WGL Holdings, Inc. Balance Sheet Location of Other Investments
As of September 30, 2013 (in millions)		VIEs		Non-VIEs		Total
Assets
Investments in unconsolidated affiliates	$	55.4	$	12.1	$	67.5
Investments in direct financing leases, capital leases		23.4		-		23.4
Deferred charges and other assets- derivatives		-		1.1		1.1
Accounts receivable		5.8		-		5.8
Total assets	$	84.6	$	13.2	$	97.8
Liabilities
Other	$	8.5	$	-	$	8.5
Total liabilities	$	8.5	$	-	$	8.5

WGL Holdings, Inc.
Income Statement Location of Other Investments
	Fiscal year ended
	September 30, 2014
(in millions)	VIEs			Non-VIEs	Total
Equity in earnings of unconsolidated affiliates	$	2.2	$	1.0	$	3.2
Depreciation and amortization	$	0.2	$	-	$	0.2
Other income - net	$	2.6		-		2.6
Net Income	$	4.6	$	1.0	$	5.6

WGL Holdings, Inc.
Income Statement Location of Other Investments
	Fiscal year ended
	September 30, 2013
(in millions)	VIEs			Non-VIEs	Total
Equity in earnings of unconsolidated affiliates	$	1.0	$	0.5	$	1.5
Depreciation and amortization		0.1		-		0.1
Other income- net		1.4		-		1.4
Net Income	$	2.3	$	0.5	$	2.8

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Operating Segment Reporting

12 Months Ended

Sep. 30, 2014

Operating Segment Reporting [Abstract]

Operating Segment Reporting

NOTE 16. OPERATING SEGMENT REPORTING

We have four reportable operating segments: regulated utility, retail energy-marketing, commercial energy systems and midstream energy services. The division of these segments into separate revenue generating components is based upon regulation, products and services. Our chief operating decision maker is our Chief Executive Officer. While net income or loss applicable to common stock is the primary criterion for measuring a segment's performance, we also evaluate our operating segments based on other relevant factors, such as penetration into their respective markets and return on equity. Our four segments are summarized below.

• Regulated Utility – The regulated utility segment is our core business. It consists of Washington Gas and Hampshire. Washington Gas provides regulated gas distribution services (including the sale and delivery of natural gas) to customers and natural gas transportation services to an unaffiliated natural gas distribution company in West Virginia under a Federal Energy Regulatory Commission (FERC) approved interstate transportation service operating agreement. Hampshire provides regulated interstate natural gas storage services to Washington Gas under a FERC approved interstate storage service tariff.
• Retail Energy-Marketing – The retail energy-marketing segment consists of WGEServices, which sells natural gas and electricity directly to retail customers in competition with regulated utilities and unregulated gas and electricity marketers.
• Commercial Energy Systems – The commercial energy systems segment consists of WGESystems which provides design-build energy efficient and sustainable solutions including commercial solar, energy efficiency and combined heat and power projects to government and commercial clients. In addition, this segment comprises the operations of WGSW, a holding company formed to invest in alternative energy assets.
• Midstream Energy Services– The midstream energy services segment consists of WGL Midstream, which engages in acquiring, investing in, managing and optimizing natural gas storage and transportation assets.

Activities and transactions that are not significant enough on a stand-alone basis to warrant treatment as an operating segment, and that do not fit into one of our four operating segments, are aggregated as “Other Activities” and included as part of non-utility operations in the Operating Segment Financial Information presented below. Administrative and business development activity costs associated with the WGL and Washington Gas Resources are included in this segment.

The following tables present operating segment information for the fiscal years ended September 30, 2014, 2013 and 2012.

Operating Segment Financial Information
						Non-Utility Operations
(In thousands)				Regulated Utility		Retail Energy-Marketing	Commercial Energy Systems		Midstream Energy Services		Other Activities		Eliminations(b)		Consolidated
Year Ended September 30, 2014
Operating Revenues (a)			$	1,443,800	$	1,310,279	$	40,679	$	16,555	$	-	$	(30,366)	$	2,780,947
Operating Expenses:
	Cost of Energy-Related Sales			726,879		1,238,970		20,348		-		-		(30,613)		1,955,584
	Operation			234,391		43,750		10,419		8,517		11,749		75		308,901
	Maintenance			56,972		-		-		-		-		-		56,972
	Depreciation and Amortization			104,064		756		6,178		124		-		(350)		110,772
	General Taxes and Other Assessments:
		Revenue Taxes		84,287		8,276		5		-		-		-		92,568
		Other		53,402		4,615		253		274		84		-		58,628
		Total Operating Expenses	$	1,259,995	$	1,296,367	$	37,203	$	8,915	$	11,833	$	(30,888)	$	2,583,425
Operating Income (Loss)				183,805		13,912		3,476		7,640		(11,833)		522		197,522
Equity in Earnings of Unconsolidated Affiliates				-		1		1,953		771		469		-		3,194
Other Income (Expense)—Net				863		103		1,007		(239)		(198)		-		1,536
Interest Expense				37,127		10		-		-		601		-		37,738
Dividends on Washington Gas Preferred Stock				1,320		-		-		-		-		-		1,320
Income Tax Expense				48,181		5,764		1,019		1,969		111		210		57,254
Net Income (Loss) Applicable to Common Stock			$	98,040	$	8,242	$	5,417	$	6,203	$	(12,274)	$	312	$	105,940
Total Assets at September 30, 2014			$	3,979,522	$	389,700	$	521,570	$	211,824	$	369,816	$	(615,933)	$	4,856,499
Capital Expenditures			$	286,323	$	76	$	108,363	$	-	$	-	$	-	$	394,762
Equity Method Investments at September 30, 2014			$	-	$	-	$	66,810	$	28,076	$	16	$	-	$	94,902
(a)Operating revenues are reported gross of revenue taxes. Revenue taxes of both the regulated utility and the retail energy-marketing segments include gross receipt taxes. Revenue taxes of the regulated utility segment also include PSC fees, franchise fees and energy taxes. Operating revenue amounts in the "Eliminations" column represent total intersegment revenues associated with sales from the regulated utility segment to the retail energy-marketing segment. Midstream Energy Services' cost of energy related sales is netted with its gross revenues.
(b)Intersegment eliminations net income includes a timing difference between Commercial Energy Systems' recognition of revenue for the sale of Solar Renewable Energy Credits (SRECs) to Retail Energy-Marketing and Retail Energy's Marketing's recognition of the associate expense. Retail Energy-Marketing has recorded a portion of the SREC's purchased as inventory to be used in future periods at which time they will be expensed.

Operating Segment Financial Information
						Non-Utility Operations
(In thousands)				Regulated Utility		Retail Energy-Marketing	Commercial Energy Systems		Midstream Energy Services		Other Activities		Eliminations(b)			Consolidated
Year Ended September 30, 2013
Operating Revenues(a)			$	1,200,357	$	1,279,364	$	35,217	$	(20,390)	$	-	$	(28,410)	$	2,466,138
Operating Expenses:
	Cost of Energy-Related Sales			521,508		1,164,831		24,450		-		-		(26,458)		1,684,331
	Operation			243,341		49,574		6,875		8,683		9,344		(197)		317,620
	Maintenance			49,269		-		-		-		-		-		49,269
	Depreciation and Amortization			100,438		726		2,411		124		-		(415)		103,284
	General Taxes and Other Assessments:
		Revenue Taxes		81,422		6,831		7		-		-		-		88,260
		Other		52,271		4,411		303		474		97		-		57,556
		Total Operating Expenses	$	1,048,249	$	1,226,373	$	34,046	$	9,281	$	9,441	$	(27,070)	$	2,300,320
Operating Income (Loss)				152,108		52,991		1,171		(29,671)		(9,441)		(1,340)		165,818
Equity in Earnings of Unconsolidated Affiliates				-		-		1,070		312		128		-		1,510
Other Income (Expense)—Net				1,539		273		778		-		644		(686)		2,548
Interest Expense				35,631		13		234		417		402		(686)		36,011
Dividends on Washington Gas Preferred Stock				1,320		-		-		-		-		-		1,320
Income Tax Expense (Benefit)				44,883		20,227		(206)		(10,951)		(1,124)		(537)		52,292
Net Income (Loss) Applicable to Common Stock			$	71,813	$	33,024	$	2,991	$	(18,825)	$	(7,947)	$	(803)	$	80,253
Total Assets at September 30, 2013			$	3,486,296	$	403,082	$	318,995	$	231,368	$	290,440	$	(470,121)	$	4,260,060
Capital Expenditures			$	227,948	$	730	$	83,667	$	-	$	-	$	-	$	312,345
Equity Method Investments at September 30, 2013			$	-	$	-	$	54,977	$	6,507	$	413	$	-	$	61,897
(a)Operating revenues are reported gross of revenue taxes. Revenue taxes of both the regulated utility and the retail energy-marketing segments include gross receipt taxes. Revenue taxes of the regulated utility segment also include PSC fees, franchise fees and energy taxes. Operating revenue amounts in the "Eliminations" column represent total intersegment revenues associated with sales from the regulated utility segment to the retail energy-marketing segment. Midstream Energy Services' cost of energy related sales is netted with its gross revenues.
(b)Intersegment eliminations net income includes a timing difference between Commercial Energy Systems' recognition of revenue for the sale of Solar Renewable Energy Credits (SRECs) to Retail Energy- Marketing and Retail Energy's Marketing's recognition of the associate expense. Retail Energy- Marketing has recorded a portion of the SREC's purchased as inventory to be used in future periods at which time will be expensed.

Operating Segment Financial Information
						Non-Utility Operations
(In thousands)				Regulated Utility		Retail Energy-Marketing	Commercial Energy Systems		Midstream Energy Services		Other Activities		Eliminations(b)			Consolidated
Year Ended September 30, 2012
Operating Revenues			$	1,137,666	$	1,267,070	$	60,325	$	(11,221)	$	-	$	(28,530)	$	2,425,310
Operating Expenses:
	Cost of Energy-Related Sales			421,539		1,139,162		51,149		-		-		(26,802)		1,585,048
	Operation			227,362		52,161		5,414		2,860		3,612		(1,093)		290,316
	Maintenance			52,494		-		-		-		-		-		52,494
	Depreciation and Amortization			94,998		735		1,261		116		-		(634)		96,476
	General Taxes and Other Assessments:
		Revenue Taxes		74,244		5,776		8		-		-		-		80,028
		Other		50,822		4,070		280		240		16		(1)		55,427
		Total Operating Expenses	$	921,459	$	1,201,904	$	58,112	$	3,216	$	3,628	$	(28,530)	$	2,159,789
Operating Income (Loss)				216,207		65,166		2,213		(14,437)		(3,628)		-		265,521
Equity in Earnings of Unconsolidated Affiliates				-		-		947		-		293		-		1,240
Other Income—Net				3,085		42		(32)		-		1,097		(38)		4,154
Interest Expense				36,098		1		1		-		366		(38)		36,428
Dividends on Washington Gas Preferred Stock				1,320		-		-		-		-		-		1,320
Income Tax Expense (Benefit)				72,178		25,876		760		(5,347)		(118)		-		93,349
Net Income (Loss) Applicable to Common Stock			$	109,696	$	39,331	$	2,367	$	(9,090)	$	(2,486)	$	-	$	139,818
Total Assets at September 30, 2012			$	3,516,046	$	361,801	$	148,407	$	169,456	$	211,038	$	(295,801)	$	4,110,947
Capital Expenditures			$	208,225	$	984	$	41,818	$	101	$	-	$	-	$	251,128
Equity Method Investments at September 30, 2012			$	-	$	-	$	23,346	$	-	$	-	$	-	$	23,346
(a)Operating revenues are reported gross of revenue taxes. Revenue taxes of both the regulated utility and the retail energy-marketing segments include gross receipt taxes. Revenue taxes of the regulated utility segment also include PSC fees, franchise fees and energy taxes. Operating revenue amounts in the "Eliminations" column represent total intersegment revenues associated with sales from the regulated utility segment to the retail energy-marketing segment. Midstream Energy Services' cost of energy related sales is netted with its gross revenues.
(b)Intersegment eliminations net income includes a timing difference between Commercial Energy Systems' recognition of revenue for the sale of Solar Renewable Energy Credits (SRECs) to Retail Energy-Marketing and Retail Energy's Marketing's recognition of the associate expense. Retail Energy-Marketing has recorded a portion of the SREC's purchased as inventory to be used in future periods at which time they will be expensed.

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Fair Value Measurements (Quantitative information WGL) (Details) (Washington Gas Light Company, USD $)												12 Months Ended		12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2014 Natural Gas Related Derivatives [Member]	Sep. 30, 2013 Natural Gas Related Derivatives [Member]	Sep. 30, 2012 Natural Gas Related Derivatives [Member]	Sep. 30, 2014 Natural Gas Related Derivatives [Member] Discounted Cash Flow [Member] Maximum [Member] Natural Gas Basis Price [Member]	Sep. 30, 2013 Natural Gas Related Derivatives [Member] Discounted Cash Flow [Member] Maximum [Member] Natural Gas Basis Price [Member]	Sep. 30, 2014 Natural Gas Related Derivatives [Member] Discounted Cash Flow [Member] Minimum [Member] Natural Gas Basis Price [Member]	Sep. 30, 2013 Natural Gas Related Derivatives [Member] Discounted Cash Flow [Member] Minimum [Member] Natural Gas Basis Price [Member]	Sep. 30, 2013 Natural Gas Related Derivatives [Member] Option Model [Member] Maximum [Member] Natural Gas Basis Price [Member]	Sep. 30, 2013 Natural Gas Related Derivatives [Member] Option Model [Member] Maximum [Member] Annualized Volatility Price [Member]	Sep. 30, 2013 Natural Gas Related Derivatives [Member] Option Model [Member] Minimum [Member] Natural Gas Basis Price [Member]	Sep. 30, 2013 Natural Gas Related Derivatives [Member] Option Model [Member] Minimum [Member] Annualized Volatility Price [Member]
Fair Value Measurements Details [Line Items]
Fair Value Measurement With Unobservable Inputs Reconciliations Recurring Basis Net Assets And Liability Value	$ (270,600,000)	$ (133,600,000)	$ 35,100,000	$ (270,600,000)	$ (133,600,000)	$ 35,600,000
Input Price							$ 6.154	$ 2.205	$ (2.101)	$ (1.780)	$ 0.628		$ 0.024
Option Volatility Percentage												276.60%		46.80%

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Accounting Policies (Tables) (Details) (USD $)	12 Months Ended
	Sep. 30, 2014		Sep. 30, 2013
Footnote Details [Abstract]
Short Term Asset Retirement Obligation	$ 6,000,000		$ 2,700,000
Schedule Of Property Plant And Equipment At Original Cost [Line Items]
Property Plant And Equipment Total Percentage	100.00%		100.00%
Regulated Operation [Member]
Schedule Of Property Plant And Equipment At Original Cost [Line Items]
Public Utilities, Property, Plant and Equipment, Transmission, Distribution and Storage	3,635,300,000		3,356,100,000
Public Utilities Property Plant And Equipment Construction Work In Progress	203,900,000		150,800,000
General, miscellaneous and intangibles	448,300,000		430,600,000
Total Property, Plant and Equipment for Segments	4,287,500,000		3,937,500,000
Transmission And Distribution Percentage	79.30%		81.50%
General, miscellaneous and intangibles percentage	9.80%		10.40%
Construction Work In Progress Percentage	4.50%		3.70%
Property Plant And Equipment Percentage for Segments	93.60%		95.60%
Unregulated Operation [Member]
Schedule Of Property Plant And Equipment At Original Cost [Line Items]
Total Property, Plant and Equipment for Segments	295,300,000		180,600,000
Property Plant And Equipment Percentage for Segments	6.40%		4.40%
WGL Holdings, Inc.
Asset Retirement Obligations Details [Line Items]
Asset Retirement Obligation, Beginning Balance	104,000,000	[1]	72,700,000
Asset Retirement Obligation, Liabilities Incurred	4,900,000		1,200,000
Asset Retirement Obligation, Liabilities Settled	(5,200,000)		(1,000,000)
Asset Retirement Obligation, Accretion Expense	4,400,000		3,300,000
Asset Retirement Obligation, Revision of Estimate	73,100,000	[2]	27,800,000	[2]
Asset Retirement Obligation, Ending Balance	181,200,000	[1]	104,000,000	[1]
Schedule Of Property Plant And Equipment At Original Cost [Line Items]
Property, Plant and Equipment, Gross, Total	4,582,764,000		4,118,149,000
Washington Gas Light Company
Asset Retirement Obligations Details [Line Items]
Asset Retirement Obligation, Beginning Balance	102,700,000	[1]	71,500,000
Asset Retirement Obligation, Liabilities Incurred	4,900,000		1,100,000
Asset Retirement Obligation, Liabilities Settled	(5,200,000)		(1,000,000)
Asset Retirement Obligation, Accretion Expense	4,300,000		3,300,000
Asset Retirement Obligation, Revision of Estimate	73,100,000	[2]	27,800,000	[2]
Asset Retirement Obligation, Ending Balance	179,800,000	[1]	102,700,000	[1]
Schedule Of Property Plant And Equipment At Original Cost [Line Items]
Property, Plant and Equipment, Gross, Total	$ 4,250,194,000		$ 3,903,482,000

[1] Includes short-term asset retirement obligations of $6.0 million and $2.7 million for fiscal year 2014 and 2013, respectively.

[2] WGL revised its assumptions regarding the timing and amounts related to its obligation to cut, cap and purge pipeline. The revision is primarily driven by our accelerated pipeline replacement programs.

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Earnings Per Share (Tables)

12 Months Ended

Sep. 30, 2014

Earnings Per Share Tables [Abstract]

Earnings per Share

Basic and Diluted EPS
	Years Ended September 30,
(In thousands, except per share data)		2014		2013		2012
Basic earnings per average common share:
Net income applicable to common stock	$	105,940	$	80,253	$	139,818
Average common shares outstanding—basic		51,759		51,697		51,522
Basic earnings per average common share	$	2.05	$	1.55	$	2.71
Diluted earnings per average common share:
Net income applicable to common stock	$	105,940	$	80,253	$	139,818
Average common shares outstanding—basic		51,759		51,697		51,522
Stock-based compensation plans		11		111		67
Total average common shares outstanding—diluted		51,770		51,808		51,589
Diluted earnings per average common share	$	2.05	$	1.55	$	2.71

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Related Party - Transactions

12 Months Ended

Sep. 30, 2014

Related Party Transactions [Abstract]

Related Party Transactions Disclosure Text Block

NOTE 18. RELATED PARTY TRANSACTIONS

WGL and its subsidiaries engage in transactions during the ordinary course of business. Inter-company transactions and balances have been eliminated from the consolidated financial statements of WGL, except as described below. Washington Gas provides accounting, treasury, legal and other administrative and general support to affiliates, and files consolidated tax returns that include affiliated taxable transactions. Washington Gas bills its affiliates in accordance with regulatory requirements for the actual cost of providing these services, which approximates their market value. To the extent such billings are not yet paid, they are reflected in “Receivables from associated companies” on Washington Gas' balance sheets. Washington Gas assigns or allocates these costs directly to its affiliates and, therefore, does not recognize revenues or expenses associated with providing these services.

In connection with billing for unregulated third party marketers and with other miscellaneous billing processes, Washington Gas collects cash on behalf of affiliates and transfers the cash in a reasonable time period. Cash collected by Washington Gas on behalf of its affiliates but not yet transferred is recorded in “Payables to associated companies” on Washington Gas' balance sheets. The following tablepresents the receivables and payables from associated companies for the fiscal years ended September 30, 2014 and 2013.

Washington Gas Light Company
Receivables / Payables from Associated Companies
(In millions)	September 30, 2014		September 30, 2013
Receivables from Associated Companies	$	4.8	$	7.2
Payables to Associated Companies	$	54.7	$	20.6

Washington Gas provides gas balancing services related to storage, injections, withdrawals and deliveries to all energy marketers participating in the sale of natural gas on an unregulated basis through the customer choice programs that operate in its service territory. These balancing services include the sale of natural gas supply commodities related to various peaking arrangements contractually supplied to Washington Gas and then partially allocated and assigned by Washington Gas to the energy marketers, including WGEServices. Washington Gas records revenues for these balancing services pursuant to tariffs approved by the appropriate regulatory bodies. These related party amounts have been eliminated in the consolidated financial statements of WGL. The following table shows the amounts Washington Gas charged WGEServices for balance services.

Washington Gas - Gas Balancing Service Charges
		Years Ended September 30,
(In millions)		2014		2013		2012
Gas balancing service charge	$	26.6	$	25.0	$	26.8

As a result of these balancing services, an imbalance is created for volumes of natural gas received by Washington Gas that are not equal to the volumes of natural gas delivered to customers of the energy marketers. WGEServices recognized an accounts receivable from Washington Gas of$0.02 million and $1.0 millionat September 30, 2014 and 2013, respectively, related to an imbalance in gas volumes. Due to regulatory treatment, these receivables and payables are not eliminated in the consolidated financial statements of WGL. Refer to Note 1—Accounting Policies for further discussion of these imbalance transactions.

Washington Gas participates in a POR program as approved by the PSC of MD, whereby it purchases receivables from participating energy marketers at approved discount rates. In addition, WGEServices participates in POR programs with certain Maryland and Pennsylvania utilities, whereby it sells its receivables to various utilities, including Washington Gas, at approved discount rates. The receivables purchased by Washington Gas are included in “Accounts receivable” in the accompanying balance sheet. Any activity between Washington Gas and WGEServices related to the POR program has been eliminated in the accompanying financial statements for WGL. At September 30, 2014 and 2013, Washington Gas had balances of $7.7 million and $106.6 million, respectively, of purchased receivables from WGEServices.

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Changes in Accumulated Other Comprehensive Income

12 Months Ended

Sep. 30, 2014

Accumulated Other Comprehensive Income (Loss) [Abstract]

Changes in Accumulated Other Comprehensive Income by Component [Text Block]

WGL Holdings, Inc.
Changes in Accumulated Other Comprehensive Income by Component
		September 30,
(In thousands)		2014		2013
Beginning Balance	$	(11,048)	$	(12,201)
Qualified cash flow hedging instruments(c )		(1,548)		-
Change in prior service cost (credit) (a) (b)		6,095		(1,671)
Amortization of actuarial gain (a)		1,594		3,399
Amortization of transition obligation (a)		-		238
Current-period other comprehensive income		6,141		1,966
Income tax expense related to other comprehensive income (b)		3,054		813
Ending Balance	$	(7,961)	$	(11,048)
(a) These accumulated other comprehensive income components are included in the computation of net periodic benefit cost. Refer to Note 10-Pension and other post-retirement benefit plans for additional details.
(b) The majority of the 2014 change to the prior service cost component of other comprehensive income is related to the impact of the OPEB plan amendment and re-measurement. Refer to Note 10-Pension and other post-retirement benefit plans for additional details.
(c ) Cash flow hedging instruments represent interest rate swap agreements on debt issuances. Refer to Note 14 - Derivative and Weather-related Instruments for further discussion of the interest rate swap agreements.

Washington Gas Light Company
Changes in Accumulated Other Comprehensive Income by Component
		September 30,
(In thousands)		2014		2013
Beginning Balance	$	(11,048)	$	(12,201)
Change in prior service cost (credit) (a) (b)		6,095		(1,671)
Amortization of actuarial gain (a)		1,594		3,399
Amortization of transition obligation (a)		-		238
Current-period other comprehensive income		7,689		1,966
Income tax expense related to other comprehensive income(b)		3,054		813
Ending Balance	$	(6,413)	$	(11,048)
(a) These accumulated other comprehensive income components are included in the computation of net periodic benefit cost. Refer to Note 10-Pension and other post-retirement benefit plans for additional details.
(b) The majority of the 2014 change to the prior service cost component of other comprehensive income is related to the impact of the OPEB plan amendment and re-measurement. Refer to Note 10-Pension and other post-retirement benefit plans for additional details.

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Consolidated Statement of Capitalization - WGL (Washington Gas Light Company, USD $)									12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014 Series One [Member]	Sep. 30, 2013 Series One [Member]	Sep. 30, 2014 Series Two [Member]	Sep. 30, 2013 Series Two [Member]	Sep. 30, 2014 Series Three [Member]	Sep. 30, 2013 Series Three [Member]	Sep. 30, 2014 Due fiscal year 2014	Sep. 30, 2013 Due fiscal year 2014	Sep. 30, 2014 Due fiscal year 2015	Sep. 30, 2013 Due fiscal year 2015	Sep. 30, 2014 Due fiscal year 2016	Sep. 30, 2013 Due fiscal year 2016	Sep. 30, 2014 Due fiscal year 2019	Sep. 30, 2013 Due fiscal year 2019	Sep. 30, 2014 Due fiscal year 2020	Sep. 30, 2013 Due fiscal year 2020	Sep. 30, 2014 Due fiscal year 2023	Sep. 30, 2013 Due fiscal year 2023	Sep. 30, 2014 Due fiscal year 2025	Sep. 30, 2013 Due fiscal year 2025	Sep. 30, 2014 Due fiscal year 2027	Sep. 30, 2013 Due fiscal year 2027	Sep. 30, 2014 Due fiscal year 2028	Sep. 30, 2013 Due fiscal year 2028	Sep. 30, 2014 Due fiscal year 2030	Sep. 30, 2013 Due fiscal year 2030	Sep. 30, 2014 Due fiscal year 2036	Sep. 30, 2013 Due fiscal year 2036	Sep. 30, 2014 Due fiscal year 2041	Sep. 30, 2013 Due fiscal year 2041	Sep. 30, 2014 Due fiscal year 2044	Sep. 30, 2013 Due fiscal year 2044
Common Shareholders' Equity
Common stock, value	$ 46,479,000	$ 46,480,000
Paid-in capital	480,620,000	477,968,000
Retained Earnings	529,480,000	511,183,000
Accumulated Other Comprehensive Income (Loss), Net of Tax	(6,413,000)	(11,048,000)
Total Common shareholders' Equity	1,050,166,000	1,024,583,000
Common Shareholders Equity As Percentage Of Total Capitalization	59.80%	65.00%
Preferred Stock
Noncontrolling Interest, Amount Represented by Preferred Stock	28,173,000	28,173,000	15,000,000	15,000,000	7,173,000	7,173,000	6,000,000	6,000,000
Preferred Stock As Percentage Of Total Capitalization	1.60%	1.80%
Long-Term Debt
Medium Term Notes	691,000,000	583,000,000							0	67,000,000	20,000,000	20,000,000	25,000,000	25,000,000	50,000,000	50,000,000	50,000,000	50,000,000	20,000,000	20,000,000	40,500,000	40,500,000	125,000,000	125,000,000	52,000,000	52,000,000	8,500,000	8,500,000	50,000,000	50,000,000	75,000,000	75,000,000	175,000,000	0
Maximum Note Rate Range									0.00%	5.17%	4.83%	4.83%	5.17%	5.17%	7.46%	7.46%	4.76%	4.76%	6.65%	6.65%	5.44%	5.44%	6.82%	6.82%	6.85%	6.85%	7.50%	7.50%	5.78%	5.78%	5.21%	5.21%	5.00%	0.00%
Minimum Note Rate Range									0.00%	4.88%	4.83%	4.83%	5.17%	5.17%	7.46%	7.46%	4.76%	4.76%	6.65%	6.65%	5.44%	5.44%	6.40%	6.40%	6.57%	6.57%	7.50%	7.50%	5.70%	5.70%	5.21%	5.21%	4.22%	0.00%
Other Long-term Debt	8,350,000	8,097,000
Unamortized discount	(122,000)	(30,000)
Less-current maturities	20,000,000	67,000,000
Long-Term Debt	679,228,000	524,067,000
Long term debt, percentage of total capitalization	38.60%	33.20%
Capitalization, Long-term Debt and Equity	$ 1,757,567,000	$ 1,576,823,000
Total capitalization, percentage	100.00%	100.00%

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Subsequent Events

12 Months Ended

Sep. 30, 2014

Subsequent Events [Abstract]

Subsequent Events [Text Block]

NOTE 20. SUBSEQUENT EVENTS

Debt Issuances

On October 24, 2014, WGL issued $100.0 million of 2.25% notes due November 1, 2019 (“2019 Notes”) and $125.0 million of 4.60% notes due November 1, 2044 (“2044 Notes”).  The notes were priced at 99.792% and 99.226% of par, respectively. The first semiannual coupon payment date is May 1, 2015.  These issuances will be recorded at cost.

The 2019 Notes have a make whole call provision that WGL may exercise at any time on or after October 24, 2014 and prior to October 1, 2019. At any time on or after October 1, 2019, the 2019 Notes may be called at 100% of the principal of such notes, plus accrued and unpaid interest. The 2044 Notes have a make whole call provision that WGL may exercise at any time on or after October 24, 2014 and prior to May 1, 2044. At any time on or after May 1, 2044, the 2044 Notes may be called at 100% of the principal of such notes, plus accrued and unpaid interest.

In connection with the issuance of the 2044 Notes, WGL settled two forward starting swap hedges for $75.0 million and $50.0 million, both of which resulted in payments to the counterparties of $4.6 million and $3.1 million, respectively.

Proceeds from the sale of these notes will be used by WGLto primarily fund the repurchase of outstanding securities of WGL and capital investments of its non-utility subsidiaries.

These transactions were executed with Wells Fargo Securities, LLC, BB&T Capital Markets, TD Securities and CIBC World Markets as underwriters.

Security Ratings

On October 15, 2014, Fitch Ratings downgraded WGL's credit rating for its senior unsecured debt to “A” from “A+.” On October 22, 2014, Moody's assigned an issue credit rating for WGL's senior unsecured debt of “A3” and S&P assigned an issue credit rating for WGL's senior unsecured debt of “A.”

Legal Matters

As previously disclosed, WGL has been cooperating with a Department of Justice (“the Department”) investigation of some of the federal contracting activities of one of its non-utility subsidiaries, WGESystems. The Department's investigation concerned certain American Recovery and Reinvestment Act projects bid out by the General Services Administration in 2010, in which WGESystems participated as a subcontractor to an 8(a) prime contractor under the Small Business Administration's 8(a) Business Development Program. On November 18, 2014, WGESystems entered into a deferred prosecution agreement with the Department, which will resolve the investigation. The agreement is for a two-year period, and the Department will not pursue the prosecution of WGESystems if WGESystems discharges its obligations under the agreement during the two-year term of the agreement. Pursuant to the agreement, WGESystems will pay fines and monetary penalties totaling $2,587,261 to the Department and implement and maintain certain remedial measures specified in the agreement.

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Pension and Other Post-retirement Benefit Plans (Table 10) (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014
Pension Plans Defined Benefit [Member]
Expected Benefit Payments [Abstract]
2015	$ 48.9
2016	50.3
2017	51.9
2018	53.0
2019	54.7
2020-2024	286.5
Other PostretirementBenefit Plans Defined Benefit [Member]
Expected Benefit Payments [Abstract]
2015	17.9
2016	18.8
2017	19.4
2018	20.1
2019	20.6
2020-2024	$ 105.3

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Long Term Debt (Tables)

12 Months Ended

Sep. 30, 2014

Long Term Debt Tables [Abstract]

MTN and Private Placement Issuances and Retirements

MTN and Private Placement Issuances and Retirements
($ In millions)	Principal		Interest Rate	Nominal Maturity Date
Year Ended September 30, 2014
Issuances:
12/5/2013	$	75.0	5.00%(a)	12/15/2043
9/12/2014		100.0	4.22%(b)	9/15/2044
Total	$	175.0
Retirements:
11/7/2013	$	37.0	4.88%	11/7/2013
9/10/2014		30.0	5.17%	9/10/2014
Total	$	67.0
(a)The estimated effective cost of the issued notes, including consideration of issuances fees and hedge costs, is 4.95%.
(b)The estimated effective cost of the issued notes, including consideration of issuances fees and hedge costs, is 4.27%.

Long Term Debt Maturities

Long-Term Debt Maturities(a)
(In millions)	MTNs		Other		Total
2015	$	20.0	$	-	$	20.0
2016		25.0		-		25.0
2017		-		-		-
2018		-		-		-
2019		50.0		-		50.0
Thereafter		596.0		-		596.0
Total (before project debt financing)	$	691.0	$	-	$	691.0
Project debt financing(b)		-		8.3		8.3
Total	$	691.0	$	8.3	$	699.3
Less: current maturities		20.0		-		20.0
Total non-current	$	671.0	$	8.3	$	679.3
(a)Excludes unamortized discounts of $121,567 at September 30, 2014.
(b)Project debt financing is anticipated to be a non-cash extinguishment. Refer to Note 13 - Commitments and Contingencies for further discussion of this construction project financing.

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Changes in Accumulated Other Comprehensive Income (Tables)

12 Months Ended

Sep. 30, 2014

WGL Holdings, Inc.

Schedule Of Accumulated Other Comprehensive Income (Loss) [Table Text Block]

WGL Holdings, Inc.
Changes in Accumulated Other Comprehensive Income by Component
		September 30,
(In thousands)		2014		2013
Beginning Balance	$	(11,048)	$	(12,201)
Qualified cash flow hedging instruments(c )		(1,548)		-
Change in prior service cost (credit) (a) (b)		6,095		(1,671)
Amortization of actuarial gain (a)		1,594		3,399
Amortization of transition obligation (a)		-		238
Current-period other comprehensive income		6,141		1,966
Income tax expense related to other comprehensive income (b)		3,054		813
Ending Balance	$	(7,961)	$	(11,048)
(a) These accumulated other comprehensive income components are included in the computation of net periodic benefit cost. Refer to Note 10-Pension and other post-retirement benefit plans for additional details.
(b) The majority of the 2014 change to the prior service cost component of other comprehensive income is related to the impact of the OPEB plan amendment and re-measurement. Refer to Note 10-Pension and other post-retirement benefit plans for additional details.
(c ) Cash flow hedging instruments represent interest rate swap agreements on debt issuances. Refer to Note 14 - Derivative and Weather-related Instruments for further discussion of the interest rate swap agreements.

Washington Gas Light Company

Schedule Of Accumulated Other Comprehensive Income (Loss) [Table Text Block]

Washington Gas Light Company
Changes in Accumulated Other Comprehensive Income by Component
		September 30,
(In thousands)		2014		2013
Beginning Balance	$	(11,048)	$	(12,201)
Change in prior service cost (credit) (a) (b)		6,095		(1,671)
Amortization of actuarial gain (a)		1,594		3,399
Amortization of transition obligation (a)		-		238
Current-period other comprehensive income		7,689		1,966
Income tax expense related to other comprehensive income(b)		3,054		813
Ending Balance	$	(6,413)	$	(11,048)
(a) These accumulated other comprehensive income components are included in the computation of net periodic benefit cost. Refer to Note 10-Pension and other post-retirement benefit plans for additional details.
(b) The majority of the 2014 change to the prior service cost component of other comprehensive income is related to the impact of the OPEB plan amendment and re-measurement. Refer to Note 10-Pension and other post-retirement benefit plans for additional details.

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Pension and Other Post-retirement Benefit Plans (Narrative) (Details) (USD $)	12 Months Ended
	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2012
Defined Benefit Plan Disclosure [Line Items]
Change in plan's funded status	$ 127,500,000
Defined Benefit Plan Accumulated Other Comprehensive Income Net Transition Assets Obligations After Tax	190,600,000
Defined Contribution Plan, Contributions by Employer	4,200,000		3,500,000		3,400,000
Defined Benefit Plan Estimated Future Employer Contributions In Next Fiscal Year 1	0
Defined Contribution Plan Employer Discretionary Contribution Amount	1,600,000		800,000		600,000
Percentage Of Prior Years Asset Gains And Losses Recognized	20.00%
EGWP Effect On Post Retirement Benefits	500,000
Realized and unrealized gains and losses on equities prior year	80.00%
Realized and unrealized gains and losses on equities second prior year	60.00%
Realized and unrealized gains and losses on equities third prior year	40.00%
Realized and unrealized gains and losses on equities fourth prior year	20.00%
Defined Benefit Plan Target Allocation Percentage [Abstract]
US Large Cap Equities	32.50%
US Small Mid Cap Equities	4.50%
International Equities	8.00%
Fixed Income And Cash	50.00%
Real Estate Investments	5.00%
Asset Class Allocations Allowed Range Within Plus Or Minus	5.00%
Defined Benefit Plan, Assumed Health Care Cost Trend Rates [Abstract]
Health Care Cost Trend Rates For Medicare And Non Medicare Eligible Retirees	7.00%		7.50%
Future Healthcare Cost Trend Rates	5.00%
Future HRA Stipend Increase	3.00%
Maximum [Member]
Defined Benefit Plan Disclosure [Line Items]
Percentage Of Supplemental Contribution	6.00%
Minimum [Member]
Defined Benefit Plan Disclosure [Line Items]
Percentage Of Supplemental Contribution	4.00%
WGEServices
Defined Benefit Plan Disclosure [Line Items]
Defined Contribution Plan, Contributions by Employer			800,000		400,000
WGL Holdings, Inc.
Defined Benefit Plan Disclosure [Line Items]
Prepaid post-retirement benefits	96,385,000		0
Accumulated Other Comprehensive Income (Loss), Net of Tax	(7,961,000)		(11,048,000)		(12,201,000)
Washington Gas Light Company
Defined Benefit Plan Disclosure [Line Items]
Prepaid post-retirement benefits	95,660,000		0
Accumulated Other Comprehensive Income (Loss), Net of Tax	(6,413,000)		(11,048,000)		(12,201,000)
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Prepaid post-retirement benefits	0	[1]	0	[1]
Defined Benefit Plan Employer Payment Current Fiscal Year	0
The projected benefit obligation (PBO)	865,200,000		788,800,000
The projected accumulated benefit obligation (ABO)	801,900,000		737,200,000
Non-funded DB Serp [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan Estimated Future Employer Contributions In Next Fiscal Year 1	4,100,000
Defined Benefit Plan Employer Payment Current Fiscal Year	1,800,000
The projected benefit obligation (PBO)	50,700,000		47,800,000
The projected accumulated benefit obligation (ABO)	46,200,000		43,900,000
Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Prepaid post-retirement benefits	96,400,000		0
Defined Benefit Plan Estimated Future Employer Contributions In Next Fiscal Year 1	16,600,000
Defined Benefit Plan Employer Payment Current Fiscal Year	16,000,000
Assumed Income Tax Rate	41.50%
Other PostretirementBenefit Plans Defined Benefit [Member] | Union Eligible Employee [Member]
Defined Benefit Plan Target Allocation Percentage [Abstract]
US Large Cap Equities	50.00%
Fixed Income And Cash	50.00%
Other PostretirementBenefit Plans Defined Benefit [Member] | Management Employee [Member]
Defined Benefit Plan Target Allocation Percentage [Abstract]
US Large Cap Equities	60.00%
Fixed Income And Cash	40.00%
Non-funded DB Serp Restoration [Member]
Defined Benefit Plan Disclosure [Line Items]
The projected benefit obligation (PBO)	1,200,000		800,000
The projected accumulated benefit obligation (ABO)	$ 700,000		$ 500,000

[1] The DB SERP and DB Restoration, included in pension benefits in the table above, have no assets.

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Consolidated Balance Sheets (USD $) In Thousands, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013
Capitalization
Long-Term Debt	$ 679,300	[1]
Current Liabilities
Notes payable	453,500		373,100
WGL Holdings, Inc.
Property, Plant and Equipment
At original cost	4,582,764		4,118,149
Accumulated depreciation and amortization	(1,268,319)		(1,210,686)
Net property, plant and equipment	3,314,445		2,907,463
Current Assets
Cash and cash equivalents	8,811		3,478
Receivables
Accounts receivable	222,253		229,544
Gas costs and other regulatory assets	3,752		10,825
Unbilled revenues	96,314		98,598
Allowance for doubtful accounts	(23,341)		(20,433)
Net receivables	298,978		318,534
Materials and supplies-principally at average cost	23,647		24,904
Storage gas	333,602		347,291
Deferred income taxes	26,664		24,522
Prepaid taxes	66,578		24,450
Other prepayments	34,269		29,922
Derivatives	18,331		35,315
Other	24,635		11,595
Total current assets	835,515		820,011
Deferred Charges and Other Assets
Gas costs	191,346		93,963
Pension and other post-retirement benefits	192,981		240,634
Other	71,638		66,010
Prepaid post-retirement benefits	96,385		0
Derivatives	18,739		26,306
Investments in direct financing leases, capital leases	18,159		23,390
Investments in unconsolidated affiliates	100,528		67,522
Other	16,763		14,761
Total deferred charges and other assets	706,539		532,586
Total Assets	4,856,499		4,260,060
Capitalization
Common shareholders' equity	1,246,576		1,274,545
Washington Gas Light Company preferred stock	28,173		28,173
Long-Term Debt	679,228		524,067
Total capitalization	1,953,977		1,826,785
Current Liabilities
Current maturities of long-term debt	20,000		67,000
Notes payable	453,500		373,100
Accounts payable and other accrued liabilities	313,221		270,658
Wages payable	19,995		18,645
Accrued interest	3,488		3,399
Dividends declared	22,449		22,075
Customer deposits and advance payments	68,318		67,154
Gas costs and other regulatory liabilities	22,563		27,013
Accrued taxes	14,133		16,056
Derivatives	48,555		48,413
Other	34,063		36,564
Total current liabilities	1,020,285		950,077
Deferred Credits
Unamortized investment tax credits	99,351		46,378
Deferred income taxes	660,908		629,807
Accrued pensions and benefits	120,446		148,890
Asset retirement obligations	175,203		101,321
Regulatory liabilities
Accrued asset removal costs	327,388		321,266
Other post-retirement benefits	86,428		0
Other	17,588		13,459
Derivatives	294,745		141,334
Other	100,180		80,743
Total deferred credits	1,882,237		1,483,198
Total Capitalization and Liabilities	4,856,499		4,260,060
Washington Gas Light Company
Property, Plant and Equipment
At original cost	4,250,194		3,903,482
Accumulated depreciation and amortization	(1,228,130)		(1,178,600)
Net property, plant and equipment	3,022,064		2,724,882
Current Assets
Cash and cash equivalents	1,060		0
Receivables
Accounts receivable	121,419		91,405
Gas costs and other regulatory assets	3,752		10,825
Unbilled revenues	20,881		19,418
Allowance for doubtful accounts	(19,209)		(17,498)
Net receivables	126,843		104,150
Materials and supplies-principally at average cost	23,600		24,857
Storage gas	156,083		132,226
Deferred income taxes	22,916		27,000
Prepaid taxes	16,137		14,868
Other prepayments	14,272		7,926
Receivables from associated companies	4,821		7,173
Derivatives	3,884		4,278
Total current assets	369,616		322,478
Deferred Charges and Other Assets
Gas costs	191,346		93,963
Pension and other post-retirement benefits	191,896		239,434
Other	71,584		65,984
Prepaid post-retirement benefits	95,660		0
Derivatives	9,455		16,051
Other	13,457		11,597
Total deferred charges and other assets	573,398		427,029
Total Assets	3,965,078		3,474,389
Capitalization
Common shareholders' equity	1,050,166		1,024,583
Washington Gas Light Company preferred stock	28,173		28,173
Long-Term Debt	679,228		524,067
Total capitalization	1,757,567		1,576,823
Current Liabilities
Current maturities of long-term debt	20,000		67,000
Notes payable	89,000		124,500
Accounts payable and other accrued liabilities	176,467		132,814
Wages payable	18,290		17,057
Accrued interest	3,488		3,399
Dividends declared	19,722		19,359
Customer deposits and advance payments	68,318		67,154
Gas costs and other regulatory liabilities	22,563		27,013
Accrued taxes	24,610		25,380
Payables to associated companies	54,685		20,557
Derivatives	33,858		24,749
Other	7,199		9,047
Total current liabilities	538,200		538,029
Deferred Credits
Unamortized investment tax credits	6,479		7,354
Deferred income taxes	619,946		611,453
Accrued pensions and benefits	118,954		147,479
Asset retirement obligations	173,775		99,972
Regulatory liabilities
Accrued asset removal costs	327,388		321,266
Other post-retirement benefits	85,814		0
Other	17,588		13,459
Derivatives	260,789		106,144
Other	58,578		52,410
Total deferred credits	1,669,311		1,359,537
Total Capitalization and Liabilities	$ 3,965,078		$ 3,474,389

[1] Excludes unamortized discounts of $121,567 at September 30, 2014.

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Income Taxes (Tables)

12 Months Ended

Sep. 30, 2014

Unrecognized Tax Benefits

Unrecognized Tax Benefits
(In thousands)		2014		2013		2012
Total unrecognized tax benefits, October 1,	$	25,051	$	22,082	$	20,699
Increases in tax positions relating to current year		10,512		5,251		3,396
Decreases in tax positions relating to prior year		(2,950)		(2,282)		(2,013)
Total unrecognized tax benefits, September 30,	$	32,613	$	25,051	$	22,082

WGL Holdings, Inc.

Components of Income Tax Expense

WGL Holdings, Inc.
Components of Income Tax Expense
	Years Ended September 30,
(In thousands)		2014		2013		2012
INCOME TAX EXPENSE
Current:
Federal	$	29,976	$	41,425	$	(13,188)
State		5,149		11,258		(30)
Total current		35,125		52,683		(13,218)
Deferred:
Federal
Accelerated depreciation		35,747		33,394		45,506
Other		(18,014)		(31,173)		44,727
State
Accelerated depreciation		9,822		6,795		9,412
Other		(1,760)		(7,585)		8,054
Total deferred		25,795		1,431		107,699
Amortization of investment tax credits		(3,666)		(1,822)		(1,132)
Total income tax expense	$	57,254	$	52,292	$	93,349

Reconciliation Between the Statutory Federal Income Tax Rate and Effective Tax Rate

WGL Holdings, Inc.
Reconciliation Between the Statutory Federal Income Tax Rate and Effective Tax Rate
		Years Ended September 30,
($ In thousands)		2014				2013				2012
Income taxes at statutory federal income tax rate	$	57,580	35.00	%	$	46,853	35.00	%	$	82,070	35.00	%
Increase (decrease) in income taxes resulting from:
Accelerated depreciation less amount deferred		1,875	1.14			2,106	1.57			1,178	0.50
Amortization of investment tax credits		(3,666)	(2.23)			(1,822)	(1.36)			(1,132)	(0.48)
Cost of removal		(4,902)	(2.98)			(2,356)	(1.76)			(2,291)	(0.98)
State income taxes-net of federal benefit		8,734	5.31			7,448	5.56			12,068	5.15
Medicare Part D adjustment		(3,621)	(2.20)			-	-			2,827	1.21
Other items-net		1,254	0.76			63	0.05			(1,371)	(0.59)
Total income tax expense and effective tax rate	$	57,254	34.80	%	$	52,292	39.06	%	$	93,349	39.81	%

Components of Deferred Income Tax Assets (Liabilities)

WGL Holdings, Inc.
Components of Deferred Income Tax Assets (Liabilities)
		September 30,
(In thousands)		2014				2013
ACCUMULATED DEFERRED INCOME TAXES	Current		Non-current		Current		Non-current
Deferred income tax assets:
Pensions	$	-	$	24,349	$	-	$	17,362
Other post-retirement benefits		-		-		-		18,510
Uncollectible accounts		9,268		-		8,127		-
Inventory overheads		6,591		-		6,431		-
Capital gains/losses-net		-		-		2		-
Valuation allowance		-		-		(2)		-
Employee compensation and benefits		6,306		37,873		5,876		37,301
Customer advances		-		197		-		197
Derivatives		6,503		31,555		-		7,872
Deferred gas costs		-		4,218		4,911		-
Solar grant/investment tax credit		-		39,184		-		17,415
Other		814		1,225		816		2,530
Total assets		29,482		138,601		26,161		101,187
Deferred income tax liabilities:
Other post-retirement benefits		-		38,299		-		-
Accelerated depreciation and other plant related items		-		669,040		-		596,754
Losses/gains on reacquired debt		-		1,426		-		1,567
Income taxes recoverable through future rates		-		65,374		-		112,222
Deferred gas costs		2,818		-		-		4,667
Derivatives		-		-		1,639		-
Partnership basis differences		-		25,370		-		15,784
Total liabilities		2,818		799,509		1,639		730,994
Net accumulated deferred income tax assets (liabilities)	$	26,664	$	(660,908)	$	24,522	$	(629,807)

Washington Gas Light Company

Components of Income Tax Expense

Washington Gas Light Company
Components of Income Tax Expense
		Years Ended September 30,
(In thousands)		2014		2013		2012
INCOME TAX EXPENSE
Current:
Federal	$	37,098	$	40,492	$	(13,155)
State		4,262		7,515		(3,332)
Total current		41,360		48,007		(16,487)
Deferred:
Federal
Accelerated depreciation		34,833		34,518		45,661
Other		(30,523)		(35,982)		27,851
State
Accelerated depreciation		9,540		6,770		9,423
Other		(6,800)		(8,221)		6,197
Total deferred		7,050		(2,915)		89,132
Amortization of investment tax credits		(876)		(895)		(898)
Total income tax expense	$	47,534	$	44,197	$	71,747

Reconciliation Between the Statutory Federal Income Tax Rate and Effective Tax Rate

Washington Gas Light Company
Reconciliation Between the Statutory Federal Income Tax Rate and Effective Tax Rate
		Years Ended September 30,
($ In thousands)		2014				2013				2012
Income taxes at statutory federal income tax rate	$	51,050	35.00	%	$	40,782	35.00	%	$	63,628	35.00	%
Increase (decrease) in income taxes resulting from:
Accelerated depreciation less amount deferred		1,875	1.29			2,106	1.81			1,178	0.65
Amortization of investment tax credits		(876)	(0.60)			(895)	(0.77)			(898)	(0.49)
Cost of removal		(4,902)	(3.36)			(2,356)	(2.02)			(2,291)	(1.26)
State income taxes-net of federal benefit		6,711	4.60			5,487	4.71			8,916	4.90
Consolidated tax sharing allocation		(2,862)	(1.96)			(1,290)	(1.11)			(309)	(0.17)
Medicare Part D adjustment		(3,621)	(2.48)			-	-			2,827	1.56
Other items-net		159	0.09			363	0.31			(1,304)	(0.72)
Total income tax expense and effective tax rate	$	47,534	32.58	%	$	44,197	37.93	%	$	71,747	39.47	%

Components of Deferred Income Tax Assets (Liabilities)

Washington Gas Light Company
Components of Deferred Income Tax Assets (Liabilities)
		Years Ended September 30,
(In thousands)		2014				2013
ACCUMULATED DEFERRED INCOME TAXES	Current		Non-current		Current		Non-current
Deferred income tax assets:
Pensions	$	-	$	23,738	$	-	$	16,768
Other post-retirement benefits		-		-		-		18,474
Uncollectible accounts		7,618		-		6,948		-
Inventory overheads		6,591		-		6,431		-
Employee compensation and benefits		5,902		27,961		5,756		27,125
Customer advances		-		197		-		197
Derivatives		4,809		31,555		2,138		7,872
Deferred gas costs		-		4,218		4,911		-
Investment tax credit		-		312		-		312
Other		814		-		816		1,727
Total assets		25,734		87,981		27,000		72,475
Deferred income tax liabilities:
Other post-retirement benefits		-		38,065		-		-
Accelerated depreciation and other plant related items		-		602,376		-		565,996
Losses/gains on reacquired debt		-		1,426		-		1,567
Income taxes recoverable through future rates		-		65,128		-		111,698
Deferred gas costs		2,818		-		-		4,667
Other		-		932		-		-
Total liabilities		2,818		707,927		-		683,928
Net accumulated deferred income tax assets (liabilities)	$	22,916	$	(619,946)	$	27,000	$	(611,453)

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Fair Value Measurements (Reconciliation with Level 3 Inputs) (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
WGL Holdings, Inc.
Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs
Balance at beginning of period	$ (151.7)	$ 42.8
Realized and unrealized gains (losses)
Recorded to income	(79.4)	(94.8)	(16.8)
Recorded to regulatory assets-gas costs	(113.6)	(115.3)
Transfers out of Level 3	1.7	(18.1)
Purchases	5.2	5.7
Settlements	38.1	28.0
Balance at end of period	(299.7)	(151.7)	42.8
WGL Holdings, Inc. | Weather Instruments [Member]
Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs
Balance at beginning of period	0	(0.5)
Realized and unrealized gains (losses)
Recorded to income	0	1.2	7.9
Recorded to regulatory assets-gas costs	0	0
Transfers out of Level 3	0	(0.7)
Purchases	0	0
Settlements	0	0
Balance at end of period	0	0	(0.5)
WGL Holdings, Inc. | Natural Gas Related Derivatives [Member]
Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs
Balance at beginning of period	(155.2)	39.6
Realized and unrealized gains (losses)
Recorded to income	(72.6)	(72.4)	22.1
Recorded to regulatory assets-gas costs	(113.6)	(115.3)
Transfers out of Level 3	1.7	(17.4)
Purchases	0	0
Settlements	45.0	10.3
Balance at end of period	(294.7)	(155.2)	39.6
WGL Holdings, Inc. | Electricity Related Derivatives [Member]
Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs
Balance at beginning of period	2.4	2.8
Realized and unrealized gains (losses)
Recorded to income	(5.7)	(23.8)	(47.7)
Recorded to regulatory assets-gas costs	0	0
Transfers out of Level 3	0	0
Purchases	5.2	5.7
Settlements	(6.9)	17.7
Balance at end of period	(5.0)	2.4	2.8
WGL Holdings, Inc. | Warrant
Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs
Balance at beginning of period	1.1	0.9
Realized and unrealized gains (losses)
Recorded to income	(1.1)	0.2	0.9
Recorded to regulatory assets-gas costs	0	0
Transfers out of Level 3	0	0
Purchases	0	0
Settlements	0	0
Balance at end of period	0	1.1	0.9
Washington Gas Light Company
Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs
Balance at beginning of period	(133.6)	35.1
Realized and unrealized gains (losses)
Recorded to income	(69.4)	(44.7)	22.2
Recorded to regulatory assets-gas costs	(113.6)	(115.3)
Transfers out of Level 3	1.7	(18.1)
Settlements	44.3	9.4
Balance at end of period	(270.6)	(133.6)	35.1
Washington Gas Light Company | Weather Instruments [Member]
Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs
Balance at beginning of period	0	(0.5)
Realized and unrealized gains (losses)
Recorded to income	0	1.2	7.9
Recorded to regulatory assets-gas costs	0	0
Transfers out of Level 3	0	(0.7)
Settlements	0	0
Balance at end of period	0	0	(0.5)
Washington Gas Light Company | Natural Gas Related Derivatives [Member]
Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs
Balance at beginning of period	(133.6)	35.6
Realized and unrealized gains (losses)
Recorded to income	(69.4)	(45.9)	14.3
Recorded to regulatory assets-gas costs	(113.6)	(115.3)
Transfers out of Level 3	1.7	(17.4)
Settlements	44.3	9.4
Balance at end of period	(270.6)	(133.6)	35.6
Washington Gas Light Company | Electricity Related Derivatives [Member]
Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs
Balance at beginning of period	0	0
Realized and unrealized gains (losses)
Recorded to income	0	0	0
Recorded to regulatory assets-gas costs	0	0
Transfers out of Level 3	0	0
Settlements	0	0
Balance at end of period	0	0	0
Washington Gas Light Company | Warrant
Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs
Balance at beginning of period	0	0
Realized and unrealized gains (losses)
Recorded to income	0	0	0
Recorded to regulatory assets-gas costs	0	0
Transfers out of Level 3	0	0
Settlements	0	0
Balance at end of period	$ 0	$ 0	$ 0

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Consolidated Statement of Capitalization - WGLH (WGL Holdings, Inc., USD $)									12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014 Series One [Member]	Sep. 30, 2013 Series One [Member]	Sep. 30, 2014 Series Two [Member]	Sep. 30, 2013 Series Two [Member]	Sep. 30, 2014 Series Three [Member]	Sep. 30, 2013 Series Three [Member]	Sep. 30, 2014 Due fiscal year 2014	Sep. 30, 2013 Due fiscal year 2014	Sep. 30, 2014 Due fiscal year 2015	Sep. 30, 2013 Due fiscal year 2015	Sep. 30, 2014 Due fiscal year 2016	Sep. 30, 2013 Due fiscal year 2016	Sep. 30, 2014 Due fiscal year 2019	Sep. 30, 2013 Due fiscal year 2019	Sep. 30, 2014 Due fiscal year 2020	Sep. 30, 2013 Due fiscal year 2020	Sep. 30, 2014 Due fiscal year 2023	Sep. 30, 2013 Due fiscal year 2023	Sep. 30, 2014 Due fiscal year 2025	Sep. 30, 2013 Due fiscal year 2025	Sep. 30, 2014 Due fiscal year 2027	Sep. 30, 2013 Due fiscal year 2027	Sep. 30, 2014 Due fiscal year 2028	Sep. 30, 2013 Due fiscal year 2028	Sep. 30, 2014 Due fiscal year 2030	Sep. 30, 2013 Due fiscal year 2030	Sep. 30, 2014 Due fiscal year 2036	Sep. 30, 2013 Due fiscal year 2036	Sep. 30, 2014 Due fiscal year 2041	Sep. 30, 2013 Due fiscal year 2041	Sep. 30, 2014 Due fiscal year 2044	Sep. 30, 2013 Due fiscal year 2044
Common Shareholders' Equity
Common stock, value	$ 525,932,000	$ 574,461,000
Paid-in capital	11,847,000	10,710,000
Retained Earnings	716,758,000	700,422,000
Accumulated Other Comprehensive Income (Loss), Net of Tax	(7,961,000)	(11,048,000)
Total Common shareholders' Equity	1,246,576,000	1,274,545,000
Common shareholders equity, percentage of total capitalization	63.80%	69.80%
Preferred Stock
Preferred Stock	0	0
Washington Gas Light Company preferred stock	28,173,000	28,173,000	15,000,000	15,000,000	7,173,000	7,173,000	6,000,000	6,000,000
Preferred stock, percentage of total capitalization	1.40%	1.50%
Long-Term Debt
Medium Term Notes	691,000,000	583,000,000							0	67,000,000	20,000,000	20,000,000	25,000,000	25,000,000	50,000,000	50,000,000	50,000,000	50,000,000	20,000,000	20,000,000	40,500,000	40,500,000	125,000,000	125,000,000	52,000,000	52,000,000	8,500,000	8,500,000	50,000,000	50,000,000	75,000,000	75,000,000	175,000,000	0
Maximum Note Rate Range									5.17%	5.17%	4.83%	4.83%	5.17%	5.17%	7.46%	7.46%	4.76%	4.76%	6.65%	6.65%	5.44%	5.44%	6.82%	6.82%	6.85%	6.85%	7.50%	7.50%	5.78%	5.78%	5.21%	5.21%	5.00%	5.00%
Minimum Note Rate Range									4.88%	4.88%	4.83%	4.83%	5.17%	5.17%	7.46%	7.46%	4.76%	4.76%	6.65%	6.65%	5.44%	5.44%	6.40%	6.40%	6.57%	6.57%	7.50%	7.50%	5.70%	5.70%	5.21%	5.21%	4.22%	4.22%
Other long-term debt	8,350,000	8,097,000
Unamortized discount	(122,000)	(30,000)
Less-current maturities	20,000,000	67,000,000
Long-Term Debt	679,228,000	524,067,000
Long Term Debt As Percentage Of Total Capitalization	34.80%	28.70%
Capitalization, Long-term Debt and Equity	$ 1,953,977,000	$ 1,826,785,000
Total Capitalization As Percentage	100.00%	100.00%

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Derivative and Weather Related Instruments (Details 2) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
WGEServices
Concentration of Credit Risk
Obligation to counterparties	$ 4.1
Percentage Of Credit Exposure	10.00%
Number of Counterparties	2
WGEServices | Weather Instruments [Member]
Gain (Loss) On Derivative Instruments Net Pretax [Abstract]
Gain (losses) on weather related instruments, pretax	3.4	(0.8)	11.8
WGL Midstream
Concentration of Credit Risk
Obligation to counterparties	13.6
Percentage Of Credit Exposure	10.00%
Number of Counterparties	3
Washington Gas Light Company
Concentration of Credit Risk
Obligation to counterparties	16.7
Percentage Of Credit Exposure	10.00%
Number of Counterparties	3
Washington Gas Light Company | Weather Instruments [Member]
Gain (Loss) On Derivative Instruments Net Pretax [Abstract]
Gain (losses) on weather related instruments, pretax		$ 0.8	$ 7.9

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Accounts Payable and Other Accrued Liabilities (Details) (USD $)	Sep. 30, 2014	Sep. 30, 2013
WGL Holdings, Inc.
Accounts payable - trade	$ 278,800,000	$ 216,300,000
Employee benefits and payroll accruals	19,800,000	23,400,000
Embedded derivatives and other accrued liabilities	14,600,000	30,900,000
Accounts Payable and Accrued Liabilities, Current, Total	313,221,000	270,658,000
Washington Gas Light Company
Accounts payable - trade	146,400,000	99,700,000
Employee benefits and payroll accruals	18,200,000	21,400,000
Embedded derivatives and other accrued liabilities	11,900,000	11,700,000
Accounts Payable and Accrued Liabilities, Current, Total	$ 176,467,000	$ 132,814,000

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Fair Value Measurements (Quantitative information WGLH) (Details) (WGL Holdings, Inc., USD $)													12 Months Ended				12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2014 Natural Gas Related Derivatives [Member]	Sep. 30, 2013 Natural Gas Related Derivatives [Member]	Sep. 30, 2012 Natural Gas Related Derivatives [Member]	Sep. 30, 2014 Natural Gas Related Derivatives [Member] Discounted Cash Flow [Member] Maximum [Member] Natural Gas Basis Price [Member]	Sep. 30, 2013 Natural Gas Related Derivatives [Member] Discounted Cash Flow [Member] Maximum [Member] Natural Gas Basis Price [Member]	Sep. 30, 2014 Natural Gas Related Derivatives [Member] Discounted Cash Flow [Member] Minimum [Member] Natural Gas Basis Price [Member]	Sep. 30, 2013 Natural Gas Related Derivatives [Member] Discounted Cash Flow [Member] Minimum [Member] Natural Gas Basis Price [Member]	Sep. 30, 2014 Natural Gas Related Derivatives [Member] Option Model [Member] Maximum [Member] Natural Gas Basis Price [Member]	Sep. 30, 2013 Natural Gas Related Derivatives [Member] Option Model [Member] Maximum [Member] Natural Gas Basis Price [Member]	Sep. 30, 2014 Natural Gas Related Derivatives [Member] Option Model [Member] Maximum [Member] Annualized Volatility Price [Member]	Sep. 30, 2013 Natural Gas Related Derivatives [Member] Option Model [Member] Maximum [Member] Annualized Volatility Price [Member]	Sep. 30, 2014 Natural Gas Related Derivatives [Member] Option Model [Member] Minimum [Member] Natural Gas Basis Price [Member]	Sep. 30, 2013 Natural Gas Related Derivatives [Member] Option Model [Member] Minimum [Member] Natural Gas Basis Price [Member]	Sep. 30, 2014 Natural Gas Related Derivatives [Member] Option Model [Member] Minimum [Member] Annualized Volatility Price [Member]	Sep. 30, 2013 Natural Gas Related Derivatives [Member] Option Model [Member] Minimum [Member] Annualized Volatility Price [Member]	Sep. 30, 2014 Electricity Related Derivatives [Member]	Sep. 30, 2013 Electricity Related Derivatives [Member]	Sep. 30, 2012 Electricity Related Derivatives [Member]	Sep. 30, 2014 Electricity Related Derivatives [Member] Discounted Cash Flow [Member] Maximum [Member] Electricity Congestion Price [Member]	Sep. 30, 2013 Electricity Related Derivatives [Member] Discounted Cash Flow [Member] Maximum [Member] Electricity Congestion Price [Member]	Sep. 30, 2014 Electricity Related Derivatives [Member] Discounted Cash Flow [Member] Minimum [Member] Electricity Congestion Price [Member]	Sep. 30, 2013 Electricity Related Derivatives [Member] Discounted Cash Flow [Member] Minimum [Member] Electricity Congestion Price [Member]
Fair Value Measurements Details [Line Items]
Fair Value Measurement With Unobservable Inputs Reconciliations Recurring Basis Net Assets And Liability Value	$ (299,700,000)	$ (151,700,000)	$ 42,800,000	$ (294,700,000)	$ (155,200,000)	$ 39,600,000													$ (5,000,000)	$ 2,400,000	$ 2,800,000
Input Price							$ 6.154	$ 2.205	$ (2.101)	$ (1.780)	$ 6.154	$ 0.628			$ (1.675)	$ (0.181)						$ 90.95	$ 64.150	$ (2.85)	$ (1.995)
Option Volatility Percentage													589.60%	276.60%			30.90%	34.60%

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Accounting Policies (Policies)

12 Months Ended

Sep. 30, 2014

Organization And Significant Accounting Policies [Abstract]

Consolidation, Policy [Policy Text Block]

CONSOLIDATION OF FINANCIAL STATEMENTS

The consolidated financial statements include the accounts of WGL and its subsidiaries during the fiscal years reported. Certain prior period amounts have been recast to conform to current period presentation. Inter-company transactions have been eliminated. Refer to Note 18—Related Party Transactions for a discussion of inter-company transactions. WGL has a variable interest in five investments that qualify as variable interest entities (VIEs). At September 30, 2014, WGL and its subsidiaries are not the primary beneficiary for any of the VIEs, therefore we have not consolidated any of the VIE entities. Our other investment projects are recorded using the cost method and as direct financing leases. Refer to Note 17—Other Investments for a discussion of VIEs and other investments.

Use of Estimates, Policy [Policy Text Block]

USE OF ESTIMATES IN THE PREPARATION OF FINANCIAL STATEMENTS

In accordance with generally accepted accounting principles in the United States of America (GAAP), we make certain estimates and assumptions regarding: (i) reported assets and liabilities; (ii) disclosedcontingent assets and liabilities at the date of the financial statements and (iii) reported revenues, revenues subject to refund, and expenses during the reporting period. Actual results could differ from those estimates.

Property, Plant and Equipment, Policy [Policy Text Block]

PROPERTY, PLANT AND EQUIPMENT

Property, plant and equipment (comprised principally of utility plant) are stated at original cost, including labor, materials, taxes and overhead costs incurred during the construction period. The cost of utility plant of Washington Gas includes an allowance for funds used during construction (AFUDC) that is calculated under a formula prescribed by our regulators. Washington Gas capitalizes AFUDC as a component of construction overhead. The before-tax rates for AFUDC for fiscal years September 30, 2014, 2013 and 2012 were 3.36%, 5.43% and 7.40%, respectively.

Washington Gas charges maintenance and repairs directly to operating expenses, except those charges applicable to transportation and power-operated equipment, which it allocates to operating expenses, construction and other accounts based on the use of the equipment. Washington Gas capitalizes betterments and renewal costs, and calculates depreciation applicable to its utility gas plant in service primarily using a straight-line method over the estimated remaining life of the plant. The composite depreciation and amortization rate of the regulated utility segment was 2.77%, 2.86% and 2.87% during fiscal years 2014, 2013 and 2012, respectively. In accordance with regulatory requirements, such rates include a component related to asset removal costs for Washington Gas. These asset removal costs are accrued through depreciation expense with a corresponding credit to “Regulatory liabilities—Accrued asset removal costs.” When Washington Gas retires depreciable utility plant and equipment, it charges the associated original costs to “Accumulated depreciation and amortization” and any related removal costs incurred are charged to “Regulatory liabilities—Accrued asset removal costs.” Washington Gas periodically reviews the adequacy of its depreciation rates by considering estimated remaining lives and other factors. For information about Asset Retirement Obligations (ARO's), refer to the section entitled "Asset Retirement Obligatons".

At September 30, 2014 and 2013, 93.6% and 95.6%, respectively, of WGL's consolidated original cost of property, plant and equipment was related to the regulated utility segment as shown below.

Impairment or Disposal of Long-Lived Assets, Policy [Policy Text Block]

IMPAIRMENT OF LONG-LIVED ASSETS

Management regularly reviews property and equipment and other long-lived assets, including certain definite-lived intangible assets and our equity method investments for possible impairment. This review occurs quarterly, or more frequently if events or changes in circumstances indicate the carrying amount of the asset may not be recoverable.

DuringSeptember 30, 2014, 2013 and 2012, Washington Gas recorded impairment charges of $0.8 million, $2.6 million and $5.0 million, respectively, in operation and maintenance expense related to its Springfield Operations Center asset.Washington Gas is actively marketing the unused operations facility for sale. At September 30, 2014 and 2013, Washington Gas recorded a $1.9 million and $0.5 million impairment loss for the unrecoverable portion of the costs incurred associated with an abandoned LNG storage project.

For our equity and cost method investments, an impairment is recorded when the investment has experienced decline in value that is other-than-temporary. Additionally, if the projects in which we hold an investment recognize an impairment loss, we would record our proportionate share of that impairment loss and evaluate the investment for decline in value that is other-than-temporary. There were no events or circumstances during the years ended September 30, 2014,2013 and2012 that resulted in any impairment charges.

Lease, Policy [Policy Text Block]

OPERATING LEASES

We have classified the lease of our corporate headquarters as an operating lease. We amortize as rent expense the total of all scheduled lease payments (including lease payment escalations) and tenant allowances on a straight-line basis over the term of the lease. For this purpose, the lease term began on the date when the lessor commenced constructing the leasehold improvements which allowed us to occupy our corporate headquarters. Leasehold improvement costs are classified as “Property, Plant and Equipment” on the Balance Sheets, and are being amortized to depreciation and amortization expense on a straight-line basis over the 15-year non-cancelable period of the lease. Refer to Note 13—Commitments andContingencies for financial data for all of our operating leases.

DIRECT FINANCING LEASESWGSW is party to three agreements to fund residential and commercial retail solar energy installations with three separate, privately held companies. WGSW has a master purchase agreement and master lease agreement with SunEdison, Inc. (SunEdison), formerly known as EchoFirst Finance Company LLC (EchoFirst) and Nextility, Inc. (Nextility), formerly known as Skyline Innovations, Inc (Skyline) for sale/leaseback arrangements for residential and commercial solar systems. Our agreements with SunEdison and Nextility are accounted for as direct financing leases. WGSW records associated interest in the financing leases in "Other income (expenses)-net" line in the accompanying Consolidated Statement of Income.

Cash and Cash Equivalents, Policy [Policy Text Block]

CASH AND CASH EQUIVALENTS

We consider all investments with original maturities of three months or less to be cash equivalents. We did not have any restrictions on our cash balances that would impact the payment of dividends by WGL or our subsidiaries as of September 30, 2014 and 2013.

Storage Gas Valutation Methods

STORAGE GAS VALUATION METHODS

For Washington Gas and WGEServices, storage gas inventory is stated at the lower-of-cost or market as determined using the first-in, first-out method. For WGL Midstream, storage gas inventory is stated at the lower-of-cost or market using the weighted average cost method.

For the fiscal year ended September 30, 2014, Washington Gas recorded a decrease to net income due to a lower-of-cost or market adjustment of $0.2million. For the fiscal year ended September 30, 2013, Washington Gas did not record any lower-of-cost or market adjustments. For the fiscal year ended September 30, 2012, Washington Gas recorded a decrease to net income due to a lower-of-cost or market adjustment of $1.4million. For the fiscal years ended September 30, 2014, 2013 and 2012, WGEServices did not record any lower-of-cost or market adjustments. For the fiscal years ended September 30, 2014, 2013 and 2012, WGL Midstream recorded a decrease to net income due to lower-of-cost or market adjustments of $3.0 million, $10.1 million and $22.4 million, respectively.

Derivatives, Reporting of Derivative Activity [Policy Text Block]

WEATHER-RELATED INSTRUMENTS

Periodically, we purchase certain weather-related instruments, such as HDD derivatives and CDD derivatives. We account for these weather related instruments in accordance with Financial Accounting Standards Board Accounting Standards Codification (ASC) Subtopic 815-45, Derivatives and Hedging—Weather Derivatives. For weather insurance policies and HDD derivatives, benefits or costs are ultimately recognized to the extent actual HDDs fall above or below the contractual HDDs for each instrument. Benefits or costs are recognized for CDD derivatives when the average temperature exceeds a contractually stated level during the contract period. Premiums for weather-related instruments are amortized based on the pattern of normal temperature days over the coverage period. Weather-related instruments for which we collect a premium are carried at fair value. Washington Gas' weather related instrument premium expense or benefit is not considered in establishing retail rates. Washington Gas does not purchase such instruments for jurisdictions in which it has received rate mechanisms that compensate it on a normal weather basis. Refer to Note 14—Derivative and Weather-Related Instruments for further discussion of our weather-related instruments.

DERIVATIVE ACTIVITIES

Regulated Utility.Washington Gas enters into both physical and financial derivative contracts for the purchase and sale of natural gas that are subject to mark-to-market accounting. Changes in the fair value of derivative instruments recoverable or refundable to customers and therefore subject to ASC Topic 980, Regulated Operations, are recorded as regulatory assets or liabilities while changes in the fair value of derivative instruments not affected by rate regulation are reflected in earnings.

As part of its asset optimization program, Washington Gas enters into derivative contracts related to the sale and purchase of natural gas at a future price with the primary objective of locking in operating margins that Washington Gas expects to ultimately realize. The derivatives used under this program may cause significant period-to-period volatility in earnings for the portion of net profits retained for shareholders; however, this volatility will not change the margins that Washington Gas expects to realize from these transactions. In accordance with ASC Topic 815, all financially and physically settled contracts under our asset optimization program are reported on a net basis in the statements of income in “Utility cost of gas”.

From time to time, Washington Gas also utilizes derivative instruments that are designed to minimize the risk of interest-rate volatility associated with planned issuances of Medium-Term Notes (MTNs). Gains or losses associated with these derivative transactions are deferred as regulatory assets or liabilities and amortized to interest expense in accordance with regulatory accounting requirements. Refer to Note 14—Derivative and Weather-Related Instruments for further discussion of our derivative activities.

Non-Utility Operations.WGEServices enters into both physical and financial contracts for the purchase and sale of natural gas and electricity. We designate a portion of these physical contracts related to the purchase of natural gas and electricity to serve our customers as “normal purchases and normal sales;” therefore, they are not subject to the mark-to-market accounting requirements of ASC Topic 815. WGL Midstream enters into derivative contracts for the purpose of optimizing its storage and transportation capacity as well as managing the transportation and storage assets on behalf of third parties. The financial contracts and the portion of the physical contracts that qualify as derivative instruments and are subject to the mark-to-market accounting requirements are recorded on the balance sheet at fair value and are reflected in earnings. WGEServices records these derivatives as revenues or expenses depending on the nature of the economically hedged item.WGL Midstream nets financial and physical contracts in revenues.WGL may, from time to time, designate interest rate swaps used to manage the interest rate risk associated with future debt issuances, as cash flow hedges. Any gains or losses arising from the effective portion of cash flow hedges are recorded in other comprehensive income and are amortized using the effective interest rate method into earnings over the same period as the hedged interest payments are made.  Gains or losses arising from the ineffective portion of cash flow hedges are recognized in earnings immediately.

Income Tax, Policy [Policy Text Block]

INCOME TAXES

We recognize deferred income tax assets and liabilities for all temporary differences between the financial statement basis and the tax basis of assets and liabilities, including those where regulators prohibit deferred income tax treatment for ratemaking purposes of Washington Gas. Regulatory assets or liabilities, corresponding to such additional deferred income tax assets or liabilities, may be recorded to the extent recoverable from or payable to customers through the ratemaking process. Refer to Note 2—Regulated Operationsfor Washington Gas' regulatory assets and liabilities associated with income taxes due from and to customers at September 30, 2014 and 2013. Amounts applicable to income taxes due from and due to customers primarily represent differences between the book and tax basis of net utility plant in service. We amortize investment tax credits as reductions to income tax expense over the estimated service lives of the related properties. Refer to Note 9—Income Taxes which provides detailed financial information related to our income taxes.

Share-based Compensation, Option and Incentive Plans Policy [Policy Text Block]

STOCK-BASED COMPENSATION

We account for stock-based compensation expense in accordance with ASC Topic 718, Compensation—Stock Compensation, which requires us to measure and recognize stock-based compensation expense in our financial statements based on the fair value at the date of grant for our equity-classified share-based awards, which include performance shares and stock options granted to certain employees and shares issued to directors. For liability-classified share-based awards, which include performance units, we recognize stock-based compensation expense based on their fair value at the end of each reporting period. For both equity-classified and liability-classified share-based awards, we estimate forfeitures over the requisite service period when recognizing compensation expense; these estimates are periodically adjusted to the extent to which actual forfeitures differ from such estimates. Refer to Note 11—Stock-Based Compensation for further discussion of the accounting for our stock-based compensation plans.

Asset Retirement Obligations, Policy [Policy Text Block]

ASSET RETIREMENT OBLIGATIONS

Washington Gas accounts for its AROs in accordance with ASC Subtopic 410-20, Asset Retirement and Environmental Obligations—AssetRetirement Obligations. Our asset retirement obligations include the costs to cut, purge and cap distribution system, remove asbestos and plug storage wells upon their retirement. These standards require recording the estimated retirement cost over the life of the related asset by depreciating the present value of the retirement obligation, measured at the time of the asset's acquisition, and accreting the liability until it is settled. There are timing differences between the ARO-related accretion and depreciation amounts being recorded pursuant to GAAP and the recognition of depreciation expense for legal asset removal costs that we are currently recovering in rates. These timing differences are recorded as a reduction to “Regulatory liabilities—Accrued asset removal costs” in accordance with ASC Topic 980. We do not have any assets that are legally restricted related to the settlement of asset retirement obligations.

Fair Value Measurement Policy [Policy Text Block]

Recurring Basis

We measure the fair value of our financial assets and liabilities using a combination of the income and market approach in accordance with ASC Topic 820. These financial assets and liabilities primarily consist of (i) derivatives recorded on our balance sheet under ASC Topic 815, (ii) weather-relatedinstruments and (iii)short-term investments, commercial paper and long-term debt outstanding required to be disclosed at fair value. Under ASC Topic 820, fair value is defined as the exit price, representing the amount that would be received in the sale of an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. To value our financial instruments, we use market data or assumptions that market participants would use, including assumptions about credit risk (both our own credit risk and the counterparty's credit risk) and the risks inherent in the inputs to valuation.

We enter into derivative contracts in the futures and over-the-counter (OTC) wholesale and retail markets. These markets are the principal markets for the respective wholesale and retail contracts. Our relevant market participants are our existing counterparties and others who have participated in energy transactions at our delivery points. These participants have access to the same market data as WGL. We value our derivative contracts based on an “in-exchange” premise, and valuations are generally based on pricing service data or indicative broker quotes depending on the market location. We measure the net credit exposure at the counterparty level where the right to set-off exists. The net exposure is determined using the mark-to-market exposure adjusted for collateral, letters of credit and parent guarantees. We use published default rates from Standard & Poor's Ratings Services and Moody's Investors Service as inputs for determining credit adjustments.

Investment [Policy Text Block]

When determining how to account for our interests in other legal entities, WGL first evaluates if we are required to apply the variable interest entity (VIE) model to the entity, otherwise the entity is evaluated under the voting interest model.Variable Interest EntitiesMeade is accounted for under the HLBV equity method of accounting, and any profits and losses are included in “Equity in earnings of unconsolidated affiliates” in the accompanying Consolidated Statement of Income and are added to or subtracted from the carrying amount of WGL's investment balance. Our investment in ASD is accounted for under the HLBV equity method of accounting; any profits and losses are included in “Equity in earnings of unconsolidated affiliates” in the accompanying Consolidated Statement of Income and are added to or subtracted from the carrying amount of WGSW's investment balance. Crab Run is accounted for under the equity method of accounting; any profits and losses are included in “Equity in earnings of unconsolidated affiliates” in the accompanying Consolidated Statement of Income and are added to or subtracted from the carrying amount of WGL's investment balance. Non Variable Interest EntitiesWashington Gas Resources holds an investment in American Solar Direct Holdings Inc. (ASDHI). This investment is recorded at cost. No identified events or changes in circumstances that may have a significant effect on the carrying value of this investment have occurred.Constitution is accounted for under the equity method of accounting; any profits and losses are included in “Equity in earnings of unconsolidated affiliates” in the accompanying Consolidated Statement of Income and are added to or subtracted from the carrying amount of WGL's investment balance. The equity method is considered appropriate because Constitution is an LLC with specific ownership accounts and ownership between five and fifty percent resulting in WGL Midstream maintaining a more than minor influence over the partnership operating and financing policies.Refer to Note 17 - Other Investments for further discussion of our investments. OTHER INVESTMENTS

Regulatory Assets and Liabilities Recognition Criteria

Asset Optimization Program.  Washington Gas optimizes the value of its long-term natural gas transportation and storage capacity resources by entering into physical and financial transactions in the form of forwards, futures and option contracts for periods when these resources are not being used to physically serve utility customers. Refer to “Derivative Activities” below for further discussion of the accounting for derivative transactions entered into under this program. Regulatory sharing mechanisms in all three jurisdictions allow the profit from these transactions to be shared between Washington Gas’ customers and shareholders. All unrealized fair value gains and losses, and margins generated from the physical and financial settlement of these asset optimization contracts are recorded in utility cost of gas or, in the case of amounts to be shared with rate payers, regulatory liabilities. Transportation Gas Imbalance.  Interruptible shippers and third party marketer shippers transport gas to Washington Gas’ distribution system as part of the unbundled services offered. The delivered volumes of gas from third party shippers into Washington Gas’ distribution system rarely equal the volumes billed to third party marketer customers, resulting in transportation gas imbalances. These imbalances are usually short-term in duration, and Washington Gas monitors the activity and regularly notifies the shippers when their accounts have an imbalance. In accordance with regulatory treatment, Washington Gas does not record a receivable from or liability to third party marketers associated with gas volumes related to these transportation imbalances but, rather, reflects the financial impact as a regulatory asset or liability related to its gas cost adjustment mechanism, thereby eliminating any profit or loss that would occur as a result of the imbalance. The regulatory treatment combines the imbalance for all marketers, including WGEServices, into a single “net” adjustment to the regulatory asset or liability. Refer to Note 18—Related Party Transactions for further discussion of the accounting for these imbalance transactions. Cost of Gas.  Washington Gas’ jurisdictional tariffs contain mechanisms that provide for the recovery of the cost of gas incurred on behalf of firm customers, including related pipeline transportation and storage capacity charges. Under these mechanisms, Washington Gas periodically adjusts its firm customers’ rates to reflect increases and decreases in these costs. Under or over-collections of gas costs in the current cycle are charged or credited to deferred charges or credits on the balance sheet as non-current regulatory assets or liabilities. Amounts deferred at the end of the cycle, August 31 of each year, are fully reconciled and transferred to current assets or liabilities under the balance sheet captions “Gas costs and other regulatory assets” and “Gas costs and other regulatory liabilities.” These balances are recovered or refunded to customers over the subsequent 12 month period. RATE REFUNDS DUE TO CUSTOMERS When Washington Gas files a request with certain regulatory commissions to modify customers’ rates, it is permitted to charge customers new rates, subject to refund, until the regulatory commission renders a final decision on the amount of the authorized change in rates. During this interim period, Washington Gas records a provision for a rate refund regulatory liability based on the difference between the amount it collects in rates and the amount it expects to recover from a final regulatory decision. Similarly, Washington Gas periodically records provisions for rate refunds related to other transactions. Actual results for these regulatory contingencies are often difficult to predict and could differ significantly from the estimates reflected in the financial statements. Refer to Note 13—Commitments and Contingencies for further discussion of regulatory matters and related contingencies.

Revenue Recognition Policy

REVENUE AND COST RECOGNITION

Regulated Utility Operations

Revenues.  For regulated deliveries of natural gas, Washington Gas reads meters and bills customers on a 21 day monthly cycle basis. The billing cycles for customers do not coincide with the accounting periods used for financial reporting purposes; therefore, Washington Gas accrues unbilled revenues for gas delivered, but not yet billed, at the end of each accounting period.

Revenue Taxes.  Revenue taxes such as gross receipts taxes, Public Service Commission (PSC) fees, franchise fees and energy taxes are reported gross in operating revenues. Refer to Note 16—Operating Segment Reporting for amounts recorded related to revenue taxes.

Non-Utility Operations

Retail Energy-Marketing Segment.WGEServices sells natural gas and electricity on an unregulated basis to residential, commercial and industrial customers both inside and outside the Washington Gas service territory.

WGEServices enters into indexed or fixed-rate contracts with residential, commercial and industrial customers for sales of natural gas and electricity. Customer contracts, which typically have terms less than 24 months, but may extend up to five years, allow WGEServices to bill customers based upon metered gas and electricity usage. Usage is measured either on a cycle basis at customer premises or based on quantities delivered to the local utility, both of which may vary by month. The billing cycles for customers do not coincide with the accounting periods used for financial reporting purposes; therefore, WGEServices accrues unbilled revenues for gas and electricity delivered, but not yet billed, at the end of each accounting period. Revenues are reflected in “Operating Revenues—Non utility.”

WGEServices procures natural gas and electricity supply under contract structures in which it assembles the various components of supply from multiple suppliers to match its customer requirements. The cost of natural gas and electricity for these purchases is recorded using the contracted volumes and prices in “Non-Utility cost of energy-related sales.”

Commercial Energy Systems Segment.WGESystems recognizes income and expenses for all design-build construction contracts using the percentage-of-completion method in “Operating Revenues—Non-utility” and “Non-Utility cost of energy-related sales.”WGESystems also recognizes income from its distributed energy assets based on the terms of the related power purchase agreements. Solar Renewable Energy Certificates (SRECs) are recorded as inventory by WGESystems after every 1,000 Kilowatt-hours (kwh) of electricity are produced by an eligible solar facility. WGESystems recognizes income on the sale of SRECs based on the contractual terms and conditions of the sale. WGSW recognizes income on its investments in distributed energy assets based on the specific terms of its sale leaseback arrangementsand through the hypothetical liquidation at book value approach to the equity method of investment accounting for its investment interest. Other income and expense is recognized from the lease of distributed energy assets associated with the SunEdison and Nextilityassociations.

Midstream Energy Services Segment.WGL Midstream reports its margins in non-utility revenue by netting its cost / loss on physical and financial gas purchase contracts with revenues / gains on physical and financial gas sales contracts.

Other Activities.Washington Gas Resourcesrecognizes income on its investment using the cost approach of investment accounting. Crab Run recognizes income using the equity method of accounting.

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Preferred Stock (Details) (Washington Gas Light Company, USD $)	Sep. 30, 2014	Sep. 30, 2013
Series One [Member]
Preferred Stock, Par or Stated Value Per Share	$ 4.80	$ 4.80
Preferred Stock, Shares Outstanding	150,000	150,000
Preferred Stock, Liquidation Preference Per Share Involuntary	$ 100
Preferred Stock Liquidation Preference Voluntary	$ 101
Preferred Stock, Redemption Price Per Share	$ 101
Series Two [Member]
Preferred Stock, Par or Stated Value Per Share	$ 4.25	$ 4.25
Preferred Stock, Shares Outstanding	70,600	70,600
Preferred Stock, Liquidation Preference Per Share Involuntary	$ 100
Preferred Stock Liquidation Preference Voluntary	$ 105
Preferred Stock, Redemption Price Per Share	$ 105
Series Three [Member]
Preferred Stock, Par or Stated Value Per Share	$ 5.00	$ 5.00
Preferred Stock, Shares Outstanding	60,000	60,000
Preferred Stock, Liquidation Preference Per Share Involuntary	$ 100
Preferred Stock Liquidation Preference Voluntary	$ 102
Preferred Stock, Redemption Price Per Share	$ 102

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Pension and Other Post-Retirement Benefit Plans

12 Months Ended

Sep. 30, 2014

Pension and Other Post-Retirement Benefit Plans [Abstract]

Pension and Other Post-Retirement Benefit Plans

NOTE 10. PENSION AND OTHER POST-RETIREMENT BENEFIT PLANS

Washington Gas maintains a qualified, trusteed, non-contributory defined benefit pension plan (qualified pension plan) covering most active and vested former employees of Washington Gas. The non-contributory defined benefit pension plan is closed to all employees hired on or after January 1, 2010. Washington Gas accounts for the qualified pension plan and other post-retirement benefit plans under the provisions of ASC 715, Compensation-Retirement Benefits.

Most executive officers of Washington Gas also participate in a non-funded defined benefit supplemental executive retirement plan (DB SERP), a non-qualified pension plan. A rabbi trust has been established for the potential future funding of the DB SERP liability. The DB SERP was closed to new entrants beginning January 1, 2010 and instead, executive officers are eligible to participate in a new non-funded defined contribution SERP (DC SERP). In addition, effective January 1, 2010, Washington Gas established a non-funded defined benefit restoration plan (DBrestoration) for the purpose of providing supplemental pension and pension-related benefits to a select group of management employees.

WGL subsidiaries offer defined-contribution savings plans to all eligible employees. These plans allow participants to defer on a pre-tax or after-tax basis, a portion of their salaries for investment in various alternatives. We make matching contributions to the amounts contributed by employees in accordance with the specific plan provisions. The Washington Gas plan was amended during 2013 to implement the merger of the WGEServices plan. The WGEServices plan was merged into the Washington Gas plan effective January 1, 2014.Beginning January 1, 2014, matching and supplemental contributions to the Washington Gas plan included matching and supplemental contributions from the former WGEServices plan. Total matching contributions to the Washington Gas plan were $4.2 million, $3.5 million and $3.4 million during fiscal years 2014, 2013 and 2012, respectively. All employees not participating in the qualified pension plan receive an employer provided supplemental contribution ranging from 4% to 6% depending on years of service. Total supplemental contributions to the plan were $1.6 million, $0.8 million and $0.6million during fiscal years ended September 30, 2014, 2013 and 2012, respectively.

Total matching contributions to the formerWGEServices plan were $0.8 million and $0.4 million during fiscal years 2013 and 2012, respectively.

Washington Gas provides certain healthcare and life insurance benefits for retired employees. Substantially all employees of Washington Gas may become eligible for such benefits if they attain retirement status while working for Washington Gas. Washington Gas accounts for these benefits under the provisions of ASC 715, Compensation-Retirement Benefits.Washington Gas elected to amortize the accumulated post-retirement benefit obligation of $190.6 million existing at the October 1, 1993 adoption date of this standard, known as the transition obligation, over a twenty-year period ended in 2013.

On April 24, 2014, Washington Gas replaced the existing retiree medical benefit plan and dental plan options for Medicare-eligible retirees age 65 and older with a special tax-free Health Reimbursement Account (HRA) plan effective January 1, 2015. With the introduction of the new plan, effective January 1, 2015, participating retirees and dependents will receive a subsidy each year through the HRA account to help purchase supplemental medical and dental coverage in the marketplace. As part of the new HRA plan, participants who enroll in a Medicare Part D prescription drug plan and meet the threshold for Medicare catastrophic prescription drug coverage will be eligible for an additional reimbursement of their out-of-pocket prescription drug costs in excess of the threshold. Retirees and dependents under age 65 will still be covered under the existing Washington Gas Retiree Medical Plan until they become eligible for Medicare at age 65 and can obtain coverage through the new HRA plan. Due to the impact of the amendment, we remeasured the funded status of the plan in April 2014. The funded status of the plan changed by approximately $127.5 million from an underfunded liability to an overfunded asset as a result of the plan amendment. The offsetting amount for this remeasurement was substantially recorded as a decrease to regulatory assets. The overfunded asset for this plan at September 30, 2014 was $96.4 million.

Almost all costs associated with Washington Gas' defined benefit post-retirement plans have historically been, and will continue to be, recovered through Washington Gas' rates. Therefore, in accordance with ASC Topic 980 and ASC Topic 715, Washington Gas established a regulatory asset/liability for the substantial majority of the unrecognized costs/income associated with its defined benefit post-retirement plans. To the extent these amounts will not be recovered through Washington Gas' rates, they are recorded directly to “Accumulated other comprehensive loss, net of taxes.”

Obligations and Assets

Washington Gas uses a measurement date of September 30 for its pension, and retiree healthcare and life insurance benefit plans. The following table provides certain information about Washington Gas' post-retirement benefits:

Post-Retirement Benefits
						Health and Life
(In millions)		Pension Benefits(a)				Benefits
Year Ended September 30,		2014		2013		2014		2013
Change in projected benefit obligation(b)
Benefit obligation at beginning of year	$	837.4	$	937.2	$	429.8	$	480.1
Service cost		14.0		17.0		7.6		9.6
Interest cost		40.4		36.6		18.7		18.8
Change in plan benefits		-		-		(136.5)		-
Actuarial loss (gain)		68.6		(110.0)		38.2		(62.3)
Retiree contributions		-		-		4.4		3.9
Medicare Part D reimbursements		-		-		0.5		0.7
Benefits paid		(43.3)		(43.4)		(19.5)		(21.0)
Projected benefit obligation at end of year(b)	$	917.1	$	837.4	$	343.2	$	429.8
Change in plan assets
Fair value of plan assets at beginning of year	$	745.2	$	750.6	$	380.9	$	358.3
Actual return on plan assets		103.3		38.6		57.8		19.9
Company contributions		1.7		1.8		16.0		18.0
Retiree contributions and Medicare Part D reimbursements		-		-		4.4		5.7
Expenses		(2.2)		(2.4)		-		-
Benefits paid		(43.3)		(43.4)		(19.5)		(21.0)
Fair value of plan assets at end of year	$	804.7	$	745.2	$	439.6	$	380.9
Funded status at end of year	$	(112.4)	$	(92.2)	$	96.4	$	(48.9)
Total amounts recognized on balance sheet
Non-current asset	$	-	$	-	$	96.4	$	-
Current liability		(4.2)		(3.5)		-		-
Non-current liability		(108.2)		(88.7)		-		(48.9)
Total recognized	$	(112.4)	$	(92.2)	$	96.4	$	(48.9)
(a)The DB SERP and DB Restoration, included in pension benefits in the table above, have no assets.
(b)For the Health and Life Benefits, the change in projected benefit obligation represents the accumulated benefit obligation.

The following table provides the projected benefit obligation (PBO) and accumulated benefit (ABO) for the qualified pension plan, DB SERP and DB Restoration at September 30, 2014 and 2013.

Projected and accumulated benefit obligation
(In millions)		Qualified Pension Plan				DB SERP				DB Restoration
September 30,	2014		2013		2014		2013		2014		2013
Projected benefit obligation	$	865.2	$	788.8	$	50.7	$	47.8	$	1.2	$	0.8
Accumulated benefit obligation	$	801.9	$	737.2	$	46.2	$	43.9	$	0.7	$	0.5

AMOUNTS RECOGNIZED IN REGULATORY ASSETS/LIABILITIES AND ACCUMULATED OTHER COMPREHENSIVE INCOME

The following table provides amounts recorded to regulatory assets, regulatory liabilities and accumulated other comprehensive loss at September 30, 2014 and 2013:

Unrecognized Costs/Income Recorded on the Balance Sheet
(In millions)		Pension Benefits				Health and Life Benefits
September 30,	2014		2013		2014		2013
Actuarial net loss	$	162.6	$	171.1	$	50.1	$	55.3
Prior service cost (credit)		1.2		1.3		(149.3)		(22.4)
Total	$	163.8	$	172.4	$	(99.2)	$	32.9
Regulatory asset (liability)	$	147.9	$	155.1	$	(94.6)	$	31.3
Pre-tax accumulated other comprehensive loss (gain)(a)		15.9		17.3		(4.6)		1.6
Total	$	163.8	$	172.4	$	(99.2)	$	32.9
(a)The total amount of accumulated other comprehensive loss recorded on our balance sheets at September 30, 2014 and 2013 is net of an income tax benefit of $4.9 million and $7.9 million, respectively.

The following table provides amounts that are included in regulatory assets/liabilities and accumulated other comprehensive loss associated with our unrecognized pension and other post-retirement benefit costs that were recognized as components of net periodic benefit cost during fiscal year 2014.

Amounts Recognized During Fiscal Year 2014
	Regulatory assets/liabilities				Accumulated other comprehensive loss
(In millions)	Pension Benefits		Health and Life Benefits		Pension Benefits		Health and Life Benefits
Actuarial net loss	$	15.5	$	4.8	$	1.3	$	0.3
Prior service cost (credit)		0.2		(9.1)		0.1		(0.5)
Total	$	15.7	$	(4.3)	$	1.4	$	(0.2)

The following table provides amounts that are included in regulatory assets/liabilities and accumulated other comprehensive loss associated with our unrecognized pension and other post-retirement benefit costs that are expected to be recognized as components of net periodic benefit cost during fiscal year 2015.

Amounts to be Recognized During Fiscal Year 2015
	Regulatory assets/liabilities				Accumulated other comprehensive loss
(In millions)	Pension Benefits		Health and Life Benefits		Pension Benefits		Health and Life Benefits
Actuarial net loss	$	17.1	$	4.2	$	1.7	$	0.2
Prior service cost (credit)		0.2		(14.5)		0.1		(0.7)
Total	$	17.3	$	(10.3)	$	1.8	$	(0.5)

Theincrease in the actuarial net loss for pension benefits to be recognized in fiscal year 2015 when compared to fiscal year 2014 is primarily due to a decrease in the discount rate for our qualified pension plan. Thedecrease in the actuarial net loss for health and life benefits to be recognized in fiscal year 2015 when compared to fiscal year 2014 is primarily due to updated census data, offset by a decrease in the discount rate for our health and life plan.

Realized and unrealized gains and losses for assets under Washington Gas' post-retirement benefit plans are spread over a period of five years. Each year, 20% of the prior five years' asset gains and losses are recognized. The market-related value of assets is equal to the market value of assets less the following percentages of prior years' realized and unrealized gains and losses on equities: 80% of the prior year, 60% of the second prior year, 40% of the third prior year and 20% of the fourth prior year.

Net Periodic Benefit Cost

The components of the net periodic benefit costs (income) for fiscal years ended September 30,2014, 2013 and 2012 related to pension and other postretirement benefits were as follows:

Components of Net Periodic Benefit Costs (Income)
(In millions)		Pension Benefits						Health and Life Benefits
Year Ended September 30,		2014		2013		2012		2014		2013		2012
Service cost	$	14.0	$	17.0	$	12.9	$	7.6	$	9.6	$	8.0
Interest cost		40.4		36.6		40.5		18.7		18.8		25.1
Expected return on plan assets		(41.0)		(41.9)		(43.5)		(19.3)		(18.3)		(18.8)
Recognized prior service cost		0.3		1.0		1.0		(9.6)		(3.9)		(3.9)
Recognized actuarial loss		16.8		28.7		16.1		5.0		9.2		13.3
Amortization of transition obligation		-		-		-		-		1.1		1.1
Net periodic benefit cost		30.5		41.4		27.0		2.4		16.5		24.8
Amount allocated to construction projects		(4.3)		(5.7)		(3.4)		(0.4)		(2.8)		(3.7)
Amount deferred as regulatory asset (liability)-net		7.0		(3.7)		(7.5)		(2.3)		2.4		1.5
Amount charged (credited) to expense	$	33.2	$	32.0	$	16.1	$	(0.3)	$	16.1	$	22.6

Amounts included in the line item “Amount deferred as regulatory asset/liability-net,” represent the difference between the cost of the applicable pension benefits and the health and life benefits and the amount that Washington Gas is permitted to recover in rates that it charges to customers in the District of Columbia.In June 2013, this mechanism was discontinued, however, any balances remaining will be amortized over five years.

ASSUMPTIONS

The weighted average assumptions used to determine net periodic benefit obligations and net periodic benefit costs were as follows:

Benefit Obligations Assumptions
	Pension Benefits		Health and Life Benefits
September 30,	2014	2013	2014	2013
Discount rate(a)	4.00%-4.40%	4.50%-5.00%	4.40%	5.10%
Rate of compensation increase	3.50%-4.10%	3.85%-5.15%	4.10%	3.85%
(a)The decrease in the discount rate in fiscal year 2014 compared to prior years primarily reflects the decrease in long-term interest rates.

Net Periodic Benefit Cost Assumptions
	Pension Benefits			Health and Life Benefits
Years Ended September 30,	2014	2013	2012	2014	2013	2012
Discount rate(a)	4.50%-5.00%	4.00%	5.30%	4.60%-5.10%	4.00%	5.10%
Expected long-term return on plan assets(b)	6.50%	6.75%	7.50%	6.25%	6.75%	7.40%
Rate of compensation increase(c)	3.85%-5.15%	3.85%-5.15%	3.85%-5.15%	3.85%	3.85%	3.85%-5.15%
(a) The changes in the discount rates over the last two fiscal years primarily reflects the changes in long-term interest rates.
(b) For health and life benefits, the expected returns for certain funds may be lower due to certain portions of income that are subject to an assumed income tax rate of 41.5%.
(c) The changes in the rate of compensation reflects the best estimates of actual future compensation levels including consideration of general price levels, productivity, seniority, promotion, and other factors such as inflation rates.

Washington Gas determines the expected long-term rate of return on plan assets by averaging the expected earnings for the target asset portfolio. In developing the expected rate of return assumption, Washington Gas evaluates an analysis of historical actual performance and long-term return projections, which gives consideration to our asset mix and anticipated length of obligation of our plan.

Washington Gas assumed the healthcare cost trend rates related to the accumulated post-retirement benefit obligation for non-Medicare eligible retirees to be 7.0% and 7.5% for fiscal years2014 and 2013, respectively. Washington Gas expects these rates to decrease gradually to 5.0% in 2021 and remain at those levels thereafter. For Medicare eligible retirees age 65 and older that will receive a subsidy each year through an HRA account, Washington Gas assumed a 3.0% increase to approximate possible future increases to the stipend. While the plan terms do not guarantee increases to the stipend, Washington Gas intends to review the stipend annually.

Healthcare Trends
(In millions)	One Percentage-Point Increase		One Percentage-Point Decrease
Increase (decrease) total service and interest cost components	$	3.6	$	(2.7)
Increase (decrease) post-retirement benefit obligation	$	10.5	$	(9.2)

INVESTMENT POLICIES AND STRATEGIES

The investment objective of the qualified pension, healthcare, and life insurance benefit plans (“Plan” or “Plans”) is to allocate each Plan's assets to appropriate investment asset classes (asset categories) so that the benefit obligations of each Plan are adequately funded, consistent with appropriate risk tolerance guidelines for the Plans' and Washington Gas' tolerance for risk.

In order to best achieve the investment objectives for each Plan, strategic allocation targets and ranges are established that control exposure to selected investment asset classes. Asset/liability modeling (ALM) is used to test the benefits and risks of several potential strategic asset allocation mixes. Simulated investment performance results based on assumptions about expected return, volatility, and correlation characteristics of the selected asset classes are tested for their effects on contributions, pension expense, PBO funded status, and downside Value at Risk metrics over a ten-year planning time horizon. Important outcomes from past ALM studies include decisions to increase fixed income exposure and to lengthen the duration of those fixed income assets. Both changes result in a better matching of each Plan's assets and liabilities, and help reduce volatility of each Plan's funded status. Implementation of these fixed income strategies occurred during fiscal year 2010 for the qualified pension plan and during fiscal year 2011 for the healthcare and life insurance benefit plans.

A pension plan ALM study that was completed during November 2011 resulted in a one-way dynamic asset allocation strategy that allows for the de-risking of the portfolio over time. Under this strategy, the target fixed income allocation percentage will increase by 5% for each 5% improvement in the plan's funded ratio, as measured by an investment consultant. This strategy resulted in portfolio de-risking during October 2012 including increased fixed income exposure and reduced U.S. large-cap equity exposure.

For the qualified pension plan, Washington Gas' funding policy is to contribute an amount sufficient to satisfy the minimum annual funding requirements under the Pension Protection Act. Any contributions above the minimum annual funding requirements would be limited to amounts that are deductible under appropriate tax law. For the healthcare and life insurance benefit plans, Washington Gas' funding policy is to contribute amounts that are collected from ratepayers.

Significant amounts of the various Plans' assets are managed by the same financial institution. In addition, the Plans have a high exposure to U.S. based investments. There are no other significant risk concentrations related to investments in any entity, industry, country, commodity, or investment fund.

Target qualified pension plan trust asset allocations are 32.5% U.S. Large-Cap Equities, 4.5% U.S. Small/Mid-Cap Equities, 8% International Equities, 5% Real Estate, and 50% Fixed Income.

Washington Gas' portion of retired employee healthcare and life insurance benefits obligation is funded through two trusts: (i) the Washington Gas Light Company Postretirement Benefit Master Trust for Retired Previously Union-Eligible Employees ("union-eligible trust") and (ii) the Washington Gas Light Company Postretirement Benefit Master Trust for Retired Management Employees ("management trust"). Target asset allocations are 50% U.S. Large-Cap Equities and 50% Fixed Income for the union-eligible trust. Target allocations are 60% U.S. Large-Cap Equities and 40% Fixed Income for the management trust.

Actual asset balances are reviewed monthly, and are allowed to range within plus or minus 5% or less of the target allocations. Assets are generally rebalanced to target allocations before actual amounts fall below or rise above the allowable ranges.

Investment vehicles used to manage qualified pension plan trust and management trust assets include commingled funds and separately managed portfolios. A private placement mutual fund is also employed to manage a portion of qualified pension plan trust assts. Commingled funds are used in the management of union-eligible trust assets.

U.S. and international equity assets are diversified across sectors, industries, and investment styles. Fixed income assets are primarily diversified across U.S. government and investment grade corporate debt instruments, with some exposure to foreign sovereign debt and minor exposure to non-investment-grade securities. Real estate is diversified geographically across the U.S. by property type.

The qualified pension plan's investment policy allows the use of futures, options, and other derivatives for purposes of reducing portfolio risk and as a low-cost option for gaining market exposure, but derivatives may not be used for leverage. The qualified pension plan's investment policy prohibits investments in Washington Gas securities. The prohibition applies to separately managed portfolios but does not apply to any commingled fund investments.

The following tables present the fair value of the pension plan assets by asset category as of September 30, 2014 and 2013:

Pension Plan Assets
										% of
($ In millions)		Level 1		Level 2		Level 3		Total		Total
At September 30, 2014
Cash and cash equivalents		$	0.6	$	-	$	-	$	0.6	0.1	%
Equity securities
	U.S. Small Cap		32.3		-		-		32.3	4.0
	Preferred Securities		-		0.1		-		0.1	0.0
Fixed income securities
	U.S. Treasuries		-		110.6		-		110.6	13.8
	U.S. Corporate Debt		-		108.4		-		108.4	13.5
	U.S. Agency Obligations and Government Sponsored Entities		-		24.6		-		24.6	3.0
	Asset-Backed Securities and Collateralized Mortgage Obligations		-		1.8		-		1.8	0.2
	Municipalities		-		9.2		-		9.2	1.1
	Non-U.S. Corporate Debt		-		23.8		-		23.8	3.0
	Repurchase Agreements(a)		-		2.5		-		2.5	0.3
	Other(b)		-		7.0		-		7.0	0.8
Mutual Funds(c)			-		112.4		-		112.4	14.0
Commingled Funds and Pooled Separate Accounts(d)			-		316.2		23.8		340.0	42.3
Private Equity/Limited Partnerships(e)			-		30.5		-		30.5	3.8
Derivatives(f)			-		(0.1)		-		(0.1)	0.0
Total fair value of plan investments		$	32.9	$	747.0	$	23.8	$	803.7	99.9	%
Receivable (payable)(g)									1.0	0.1
Total plan assets at fair value								$	804.7	100.0	%

Pension Plan Assets
										% of
($ In millions)		Level 1		Level 2		Level 3		Total		Total
At September 30, 2013
Cash and cash equivalents		$	0.9	$	-	$	-	$	0.9	0.1	%
Equity securities
	U.S. Small Cap		31.5		-		-		31.5	4.2
	Preferred Securities		-		0.1		-		0.1	-
Fixed income securities
	U.S. Treasuries		-		124.5		-		124.5	16.7
	U.S. Corporate Debt		-		93.6		-		93.6	12.6
	U.S. Agency Obligations and Government Sponsored Entities		-		19.0		-		19.0	2.5
	Asset-Backed Securities and Collateralized Mortgage Obligations		-		1.9		-		1.9	0.2
	Municipalities		-		9.0		-		9.0	1.2
	Non-U.S. Corporate Debt		-		18.4		-		18.4	2.5
	Repurchase Agreements(a)		-		1.0		-		1.0	0.1
	Other(b)		-		5.7		-		5.7	0.8
Mutual Funds(c)			-		93.2		-		93.2	12.5
Commingled Funds and Pooled Separate Accounts(d)			-		295.5		21.1		316.6	42.5
Private Equity/Limited Partnerships(e)			-		33.3		-		33.3	4.5
Derivatives(f)			-		(0.3)		-		(0.3)	-
Total fair value of plan investments		$	32.4	$	694.9	$	21.1	$	748.4	100.4	%
Receivable (payable)(g)									(3.2)	(0.4)
Total plan assets at fair value								$	745.2	100.0	%
(a)	This category includes Treasury Bills with a pre-commitment from the counterparty to repurchase the same securities on the next business day at an agreed-upon price.
(b)	This category primarily includes Yankee bonds and non-U.S. government bonds.
(c)	At September 30, 2014 and September 30, 2013, investments in mutual funds consisted primarily of corporate fixed income instruments.
(d)	At September 30, 2014, investments in commingled funds and pooled separate accounts consisted primarily of 75% common stock of large-cap U.S. companies; 14% income producing properties located in the United States; 9% equity securities of non-U.S. companies; and 2% short-term money market investments. At September 30, 2013, investments in commingled funds and pooled separate accounts consisted primarily of 67% common stock of large-cap U.S. companies; 12% income producing properties located in the United States; 20% equity securities of non-U.S. companies; and 1% short-term money market investments.
(e)	At September 30, 2014, investments in private equity/limited partnership consisted of common stock of international companies.
(f)	At September 30, 2014, this category includes long-term U.S. Treasury interest rate futures contracts and interest rate put options.
(g)	At September 30, 2014, this receivable represents a pending trade for investment sales. At September 30, 2013, this payable represents a pending trade for investment purchases.

Healthcare and Life Insurance Plan Assets
										% of
($ In millions)			Level 1		Level 2		Level 3		Total	Total
At September 30, 2014
Cash and Cash Equivalents		$	0.8	$	-	$	-	$	0.8	0.2	%
Mutual Funds(a)			-		1.9		-		1.9	0.4
Fixed Income Securities
	U.S Agency Obligations		-		2.0		-		2.0	0.5
	U.S. Treasuries		-		25.6		-		25.6	5.8
	U.S. Corporate Debt		-		34.0		-		34.0	7.7
	Municipalities		-		4.8		-		4.8	1.1
	Non-U.S. Corporate Debt		-		5.7		-		5.7	1.3
	Others(b)		-		5.3		-		5.3	1.2
Commingled Funds(c)			-		359.7		-		359.7	81.8
Total fair value of plan investments		$	0.8	$	439.0	$	-	$	439.8	100.0	%
Receivable (payable)									(0.2)	-
Total plan assets at fair value								$	439.6	100.0	%

At September 30, 2013
Cash and Cash Equivalents		$	0.6	$	-	$	-	$	0.6	0.2	%
Fixed Income Securities
	U.S Agency Obligations		-		1.7		-		1.7	0.4
	U.S. Treasuries		-		23.6		-		23.6	6.2
	U.S. Corporate Debt		-		28.7		-		28.7	7.5
	Municipalities		-		4.1		-		4.1	1.1
	Non-U.S. Corporate Debt		-		4.6		-		4.6	1.2
	Others(b)		-		5.3		-		5.3	1.4
Commingled Funds(c)			-		311.2		-		311.2	81.7
Total fair value of plan investments		$	0.6	$	379.2	$	-	$	379.8	99.7	%
Receivable (payable)									1.1	0.3
Total plan assets at fair value								$	380.9	100.0	%
(a)	At September 30, 2014, investments in mutual funds consisted primarily of 63% short-term obligations consisting of certificates of deposit and time deposits, 23% high-quality commercial paper, 6% repurchase agreements, 4% corporate notes of U.S. and foreign corporations and 4% U.S. governmental and U.S. agency securities.
(b)	At September 30, 2014 and 2013, this category consisted primarily of 82% non-U.S. government bonds and 18% Yankee bonds.
(c)	At September 30, 2014 and 2013, investments in commingled funds consisted primarily of 66% common stock of large-cap U.S. companies, 17% U.S. agency obligations and government sponsored entities and 17% corporate bonds.

Valuation Methods

Equity securities are traded on a securities exchangeand are valued at the closing quoted market price as of the balance sheet date.

Mutual funds are valued at the quoted net asset value (NAV) per share, which is computed as of the close of business on the balance sheet date. Mutual funds with a publicly quoted NAV per share are classified as Level 1; mutual funds with a NAV per share that is not made publicly available are classified as Level 2. Real Estate Investment Funds which have redemption restrictions are classified as Level 3.

Commingled funds and pooled separate accounts are valued at the quoted NAV per unit, computed as of the close of business on the balance sheet date.

Private Equity/Limited Partnership funds are valued at the quoted NAV, which is computed monthly and allocated based on ownership interest in partners' capital.

Fixed income securities are valued using pricing models that consider various observable inputs such as benchmark yields, reported trades, broker quotes and issuer spreads to determine fair value.

The Plans may engage in repurchase transactions. Generally, in accordance with the terms of a repurchase agreement, the Plans take possession of Treasury Bills in exchange for cash and the counterparty is obligated to repurchase, and the Plan to resell, the same securities at an agreed-upon price and time. The repurchase agreements have a one-day maturity and a fair value equal to the Plan's cash outlay at the time the agreement is executed.

The following table summarizes the changes in the fair value of the Level 3 assets for the fiscal years ended 2014 and 2013:

(In millions)
Years Ended September 30,		2014		2013
Balance, beginning of year		$	21.1	$	18.7
Actual return on plan assets:
	Assets still held at year end		2.7		2.4
Balance, end of year		$	23.8	$	21.1

Benefit Contribution

During fiscal year 2014, Washington Gas did not contribute to its qualified pension but did contribute $1.8million to its non-funded DB SERP plan. During fiscal year 2015, Washington Gas does not expect to make a contribution to its qualified pension plan and expects to make a paymentof$4.1million to its non-funded DB SERP. During fiscal year 2014, Washington Gas contributed $16.0 million to its health and life insurance benefit plans.Washington Gas expects to make a contribution of $16.6 millionto its health and life insurance benefit plans during fiscal year 2015.

Expected Benefit Payments

Expected benefit payments, including benefits attributable to estimated future employee service, which are expected to be paid over the next ten years are as follows:

Expected Benefit Payments
(In millions)	Pension Benefits		Health and Life Benefits
2015	$	48.9	$	17.9
2016		50.3		18.8
2017		51.9		19.4
2018		53.0		20.1
2019		54.7		20.6
2020—2024		286.5		105.3

MEDICARE SUBSIDY RECEIPTS / EMPLOYER GROUP WAIVER PLAN

Prior to 2013 Washington Gas sponsored a post-65 retiree prescription drug plan that was at least actuarially equivalent to Medicare (Medicare Part D), and as a result was eligible to receive a federal subsidy under the Medicare Prescription Drug, Improvement and Modernization Act of 2003. Effective January 1, 2013 Washington Gas implemented an Employer Group Waiver Plan with a wraparound supplemental plan ("EGWP/wrap"). Accordingly, the Washington Gas retiree medical plan began receiving direct reimbursements and discounts from Medicare and the large pharmaceutical companies. During the year ended September 30, 2014, Washington Gas received $0.5 million in reimbursements related to the EGWP/wrap. Effective January 1, 2015, Washington Gas will cease to participate in the EGWP/wrap because participants age 65 and older will be transitioning into the new WGL Retiree HRA Plan, where such participants will receive an annual stipend that could be used to purchase health and prescription drug insurance.

REGULATORY MATTERS

A significant portion of the estimated pension and post-retirement medical and life insurance benefits apply to our regulated activities. Each regulatory commission having jurisdiction over Washington Gas requires it to fund amounts reflected in rates for post-retirement medical and life insurance benefits into irrevocable trusts.

District of Columbia Jurisdiction

Washington Gas recovers all costs allocable to the District of Columbia associated with its qualified pension plan and other post-retirement medical and life insurance benefits. Expenses of the SERP allocable to the District of Columbia are not recovered through rates. The PSC of DC granted the recovery of post-retirement medical and life insurance benefit costs determined in accordance with GAAP through a five-year phase-in plan that ended September 30, 1998. Washington Gas deferred the difference generated during the phase-in period as a regulatory asset. Effective October 1, 1998, the PSC of DC granted Washington Gas full recovery of costs determined under GAAP, plus a fifteen-year amortization of the regulatory asset established during the phase-in period that ended in fiscal year 2014.

Virginia Jurisdiction

On September 28, 1995, the SCC of VA issued a generic order that allowed Washington Gas to recover most costs determined under GAAP for post-retirement medical and life insurance benefits in rates over twenty years. The SCC of VA, however, set a forty-year recovery period of the transition obligation. As prescribed by GAAP, Washington Gas amortizes these costs over a twenty-year period. With the exception of the transition obligation, the SCC of VA has approved a level of rates sufficient to recover annual costs for all pension and other post-retirement medical and life insurance benefit costs determined under GAAP.

Maryland Jurisdiction

In Washington Gas' most recent rate case, the PSC of MD approved 50% of the expenses of the SERP for recovery through rates.The PSC of MD has approved a level of rates sufficient to recover pension and other post-retirement benefit costs as determined under GAAP.

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Accounting Policies (Tables)

12 Months Ended

Sep. 30, 2014

Public Utilities, Property, Plant and Equipment [Abstract]

Schedule of Public Utility Property, Plant, and Equipment [Table Text Block]

Property, Plant and Equipment at Original Cost
September 30,		2014			2013
($ In millions)		Dollars	%		Dollars	%
Regulated utility segment
Distribution, transmission and storage	$	3,635.3	79.3	$	3,356.1	81.5
General, miscellaneous and intangibles		448.3	9.8		430.6	10.4
Construction work in progress (CWIP)		203.9	4.5		150.8	3.7
Total regulated utility segment		4,287.5	93.6		3,937.5	95.6
Unregulated segments		295.3	6.4		180.6	4.4
Total	$	4,582.8	100.0	$	4,118.1	100.0

WGL Holdings, Inc.

Changes in Asset Retirement Obligations [Line Items]

Schedule of Change in Asset Retirement Obligation [Table Text Block]

WGL Holdings, Inc.
Changes in Asset Retirement Obligations
		September 30,
(In millions)		2014		2013
Asset retirement obligations at beginning of year	$	104.0	$	72.7
Liabilities incurred in the period		4.9		1.2
Liabilities settled in the period		(5.2)		(1.0)
Accretion expense		4.4		3.3
Revisions in estimated cash flows(a)		73.1		27.8
Asset retirement obligations at the end of the year(b)	$	181.2	$	104.0

Washington Gas Light Company

Changes in Asset Retirement Obligations [Line Items]

Schedule of Change in Asset Retirement Obligation [Table Text Block]

Washington Gas Light Company
Changes in Asset Retirement Obligations
		September 30,
(In millions)		2014		2013
Asset retirement obligations at beginning of year	$	102.7	$	71.5
Liabilities incurred in the period		4.9		1.1
Liabilities settled in the period		(5.2)		(1.0)
Accretion expense		4.3		3.3
Revisions in estimated cash flows(a)		73.1		27.8
Asset retirement obligations at the end of the year(b)	$	179.8	$	102.7
(a) WGL revised its assumptions regarding the timing and amounts related to its obligation to cut, cap and purge pipeline. The revision is primarily driven by our accelerated pipeline replacement programs.
(b) Includes short-term asset retirement obligations of $6.0 million and $2.7 million for fiscal year 2014 and 2013, respectively.

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Fair Value Measurements (Fair Value of Financial Instruments) (Details) (USD $)	Sep. 30, 2014		Sep. 30, 2013
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Commercial Paper	$ 453,500,000		$ 373,100,000
WGL Holdings, Inc.
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Commercial Paper	453,500,000		373,100,000
Washington Gas Light Company
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Commercial Paper	89,000,000		124,500,000
Carrying Amount | WGL Holdings, Inc.
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Money Market Funds	9,700,000	[1]	6,500,000	[1]
Other Short Term Investments	0	[1]	100,000	[1]
Commercial Paper	453,500,000	[2]	373,100,000	[2]
Long-term debt	679,200,000	[3]	524,100,000	[3]
Carrying Amount | Washington Gas Light Company
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Money Market Funds	4,300,000	[1]	3,100,000	[1]
Other Short Term Investments	0	[1]	100,000	[1]
Commercial Paper	89,000,000	[2]	124,500,000	[2]
Long-term debt	679,200,000	[3]	524,100,000	[3]
Fair Value | WGL Holdings, Inc.
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Money Market Funds	9,700,000	[1]	6,500,000	[1]
Other Short Term Investments	0	[1]	100,000	[1]
Commercial Paper	453,500,000	[2]	373,100,000	[2]
Long-term debt	809,300,000	[3]	630,200,000	[3]
Fair Value | Washington Gas Light Company
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Money Market Funds	4,300,000	[1]	3,100,000	[1]
Other Short Term Investments	0	[1]	100,000	[1]
Commercial Paper	89,000,000	[2]	124,500,000	[2]
Long-term debt	$ 809,300,000	[3]	$ 630,200,000	[3]

[1] Balance located in cash and cash equivalents in the accompanying balance sheets. These amounts may be offset by outstanding checks.

[2] Balance is located in notes payable in the accompanying balance sheets.

[3] Less current maturities and unamortized discounts.

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Environmental Matters

12 Months Ended

Sep. 30, 2014

Environmental Matters [Abstract]

Environmental Loss Contingency Disclosure [Text Block]

NOTE 12.ENVIRONMENTAL MATTERS

We are subject to federal, state and local laws and regulations related to environmental matters. These laws and regulations may require expenditures over a long time frame to control environmental effects. Almost all of the environmental liabilities we have recorded are for costs expected to be incurred to remediate sites where we or a predecessor affiliate operated MGPs. Estimates of liabilities for environmental response costs are difficult to determine with precision because of the various factors that can affect their ultimate level. These factors include, but are not limited to, the following:

• the complexity of the site;
• changes in environmental laws and regulations at the federal, state and local levels;
• the number of regulatory agencies or other parties involved;
• new technology that renders previous technology obsolete or experience with existing technology that proves ineffective;
• the level of remediation required and
• variations between the estimated and actual period of time that must be dedicated to respond to an environmentally-contaminated site.

Washington Gas has identified up to ten sites where it or its predecessors may have operated MGPs. Washington Gas last used any such plant in 1984. In connection with these operations, we are aware that coal tar and certain other by-products of the gas manufacturing process are present at or near some former sites, and may be present at others. Based on the information available to us, we have concluded that none of the sites are likely to present an unacceptable risk to human health or the environment, and either the appropriate remediation is being undertaken, or Washington Gas believes no remediation is necessary.

At both September 30, 2014 and 2013, Washington Gas recorded a liability of $8.5 million, on an undiscounted basis related to future environmental response costs, which included the estimated costs for four MGP sites. These estimates principally include the minimum liabilities associated with a range of environmental response costs expected to be incurred at the sites identified. At September 30, 2014 and 2013, Washington Gas estimated the maximum liability associated with all of its sites to be approximately $19.3 million and $20.5 million, respectively. The estimates were determined by Washington Gas' environmental experts, based on experience in remediating MGP sites and advice from legal counsel and environmental consultants. The variation between the recorded and estimated maximum liability primarily results from differences in the number of years that will be required to perform environmental response processes at each site and the extent of remediation that may be required.

Regulatory orders issued by the PSC of MD allow Washington Gas to recover the costs associated with the sites applicable to Maryland over the period ending in 2025. Rate orders issued by the PSC of DC allow Washington Gas a three-year recovery of prudently incurred environmental response costs, and allow Washington Gas to defer additional costs incurred between rate cases. Regulatory orders from the SCC of VA have generally allowed the recovery of prudent environmental remediation costs to the extent they were included in the underlying financial data supporting an application for rate change.

At both September 30, 2014 and 2013, Washington Gas reported a regulatory asset of $0.6 million, for the portion of environmental response costs that are expected to be recoverable in future rates.

We do not expect that the ultimate impact of these matters will have a material effect on our financial position, cash flows, capital expenditures, earnings or competitive position.

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Income Taxes (Components of Income Tax Expense) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
WGL Holdings, Inc.
Current:
Federal	$ 29,976	$ 41,425	$ (13,188)
State	5,149	11,258	(30)
Current Income Tax Expense (Benefit), Total	35,125	52,683	(13,218)
Deferred
Deferred Income Tax Expense (Benefit), Total	25,795	1,431	107,699
Amortization of investment tax credits	(3,666)	(1,822)	(1,132)
Income Tax Expense (Benefit), Continuing Operations, Total	57,254	52,292	93,349
Washington Gas Light Company
Current:
Federal	37,098	40,492	(13,155)
State	4,262	7,515	(3,332)
Current Income Tax Expense (Benefit), Total	41,360	48,007	(16,487)
Deferred
Deferred Income Tax Expense (Benefit), Total	7,050	(2,915)	89,132
Amortization of investment tax credits	(876)	(895)	(898)
Income Tax Expense (Benefit), Continuing Operations, Total	47,534	44,197	71,747
Accelerated Depreciation [Member] | WGL Holdings, Inc.
Deferred
Federal	35,747	33,394	45,506
State	9,822	6,795	9,412
Accelerated Depreciation [Member] | Washington Gas Light Company
Deferred
Federal	34,833	34,518	45,661
State	9,540	6,770	9,423
Other Federal [Member] | WGL Holdings, Inc.
Deferred
Federal	(18,014)	(31,173)	44,727
State	(1,760)	(7,585)	8,054
Other Federal [Member] | Washington Gas Light Company
Deferred
Federal	(30,523)	(35,982)	27,851
State	$ (6,800)	$ (8,221)	$ 6,197

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Subsequent Events (Details)	12 Months Ended
	Sep. 30, 2014
Debt Issuance [Member]
Subsequent Event [LineItems]
Subsequent Event Description	Debt Issuance On October 24, 2014, WGL issued $100.0 million of 2.25% notes due November 1, 2019 (“2019 Notes”) and $125.0 million of 4.60% notes due November 1, 2044 (“2044 Notes”). The notes were priced at 99.792% and 99.226% of par, respectively. The first semiannual coupon payment date is May 1, 2015. The 2019 Notes have a make whole call provision that WGL may exercise at any time on or after October 24, 2014 and prior to October 1, 2019. At any time on or after October 1, 2019, the 2019 Notes may be called at 100% of the principal of such notes, plus accrued and unpaid interest. The 2044 Notes have a make whole call provision that WGL may exercise at any time on or after October 24, 2014 and prior to May 1, 2044. At any time on or after May 1, 2044, the 2044 Notes may be called at 100% of the principal of such notes, plus accrued and unpaid interest. In connection with the issuance of the 2044 Notes, WGL settled two forward starting swap hedges for $75.0 million and $50.0 million, both of which resulted in payments to the counterparties of $4.6 million and $3.1 million, respectively. Proceeds from the sale of these notes will be used by WGL to primarily fund the repurchase of outstanding securities of WGL and capital investments of its non-utility subsidiaries. These transactions were executed with Wells Fargo Securities, LLC, BB&T Capital Markets, TD Securities and CIBC World Markets as underwriters.
Security Ratings [Member]
Subsequent Event [LineItems]
Subsequent Event Description	Security Ratings On October 15, 2014, Fitch Ratings downgraded WGL’s credit rating for its senior unsecured debt to “A” from “A+.” On October 22, 2014, Moody’s assigned an issue credit rating for WGL’s senior unsecured debt of “A3” and S&P assigned an issue credit rating for WGL’s senior unsecured debt of “A.”
Legal Matters [Member]
Subsequent Event [LineItems]
Subsequent Event Description	Legal Matters As previously disclosed, WGL has been cooperating with a Department of Justice (“the Department”) investigation of some of the federal contracting activities of one of its non-utility subsidiaries, WGESystems. The Department’s investigation concerned certain American Recovery and Reinvestment Act projects bid out by the General Services Administration in 2010, in which WGESystems participated as a subcontractor to an 8(a) prime contractor under the Small Business Administration’s 8(a) Business Development Program. On November 18, 2014, WGESystems entered into a deferred prosecution agreement with the Department, which will resolve the investigation. The agreement is for a two-year period, and the Department will not pursue the prosecution of WGESystems if WGESystems discharges its obligations under the agreement during the two-year term of the agreement. Pursuant to the agreement, WGESystems will pay fines and monetary penalties totaling $2,587,261 to the Department and implement and maintain certain remedial measures specified in the agreement.

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Consolidated Statement of Capitalization - WGLH (Parenthetical) (USD $)	Sep. 30, 2014	Sep. 30, 2013
Preferred Stock [Member]
Preferred Stock [Abstract]
Preferred Stock, Shares Authorized	1,500,000	1,500,000
Preferred Stock, Par or Stated Value Per Share	$ 0	$ 0
Preferred Stock [Member] | WGL Holdings, Inc.
Preferred Stock [Abstract]
Preferred Stock, Shares Authorized	3,000,000	3,000,000
Preferred Stock, Issued	0	0
Preferred Stock, Par or Stated Value Per Share	$ 0	$ 0
Common Stock [Member] | WGL Holdings, Inc.
Common Shareholders' Equity
Common Stock, Par or Stated Value Per Share	$ 0	$ 0
Common Stock, Shares Authorized	120,000,000	120,000,000
Common Stock, Shares, Issued	50,656,553	51,774,204
Series One [Member] | WGL Holdings, Inc.
Preferred Stock [Abstract]
Preferred Stock, Shares Outstanding	150,000	150,000
Preferred Stock, Par or Stated Value Per Share	$ 4.80	$ 4.80
Series Two [Member] | WGL Holdings, Inc.
Preferred Stock [Abstract]
Preferred Stock, Shares Outstanding	70,600	70,600
Preferred Stock, Par or Stated Value Per Share	$ 4.25	$ 4.25
Series Three [Member] | WGL Holdings, Inc.
Preferred Stock [Abstract]
Preferred Stock, Shares Outstanding	60,000	60,000
Preferred Stock, Par or Stated Value Per Share	$ 5.00	$ 5.00

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Consolidated Statements of Income (USD $) In Thousands, except Per Share data, unless otherwise specified	12 Months Ended
	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2012
WGL Holdings, Inc.
OPERATING REVENUES
Utility	$ 1,416,951		$ 1,174,724		$ 1,109,355
Non-utility	1,363,996		1,291,414		1,315,955
Total Operating Revenues	2,780,947	[1]	2,466,138	[1]	2,425,310	[1]
OPERATING EXPENSES
Utility cost of gas	700,305		496,487		394,955
Non-utility cost of energy-related sales	1,255,279		1,187,844		1,190,093
Operation and maintenance	365,873		366,889		342,810
Depreciation and amortization	110,772		103,284		96,476
General taxes and other assessments	151,196		145,816		135,455
Total Operating Expenses	2,583,425		2,300,320		2,159,789
OPERATING INCOME (LOSS)	197,522		165,818		265,521
Equity in earnings of unconsolidated affiliates	3,194		1,510		1,240
Other Income (Expense) - Net	1,536		2,548		4,154
Interest Expense	37,738		36,011		36,428
INCOME (LOSS) BEFORE INCOME TAXES	164,514		133,865		234,487
INCOME TAX EXPENSE (BENEFIT)	57,254		52,292		93,349
Net income	107,260		81,573		141,138
Dividends on Washington Gas Light Company preferred stock	1,320		1,320		1,320
NET INCOME (LOSS) APPLICABLE TO COMMON STOCK	105,940		80,253		139,818
AVERAGE COMMON SHARES OUTSTANDING
Basic	51,759		51,697		51,522
Diluted	51,770		51,808		51,589
EARNINGS PER AVERAGE COMMON SHARE
Basic	$ 2.05		$ 1.55		$ 2.71
Diluted	$ 2.05		$ 1.55		$ 2.71
DIVIDENDS DECLARED PER COMMON SHARE	$ 1.7400		$ 1.6600		$ 1.5875
Washington Gas Light Company
OPERATING REVENUES
Total Operating Revenues	1,443,800		1,200,357		1,137,666
OPERATING EXPENSES
Utility cost of gas	726,879		521,508		421,539
Operation and maintenance	294,613		295,664		282,746
Depreciation and amortization	102,713		99,188		93,811
General taxes and other assessments	137,472		133,391		124,814
Total Operating Expenses	1,261,677		1,049,751		922,910
OPERATING INCOME (LOSS)	182,123		150,606		214,756
Other Income (Expense) - Net	862		1,544		3,135
Interest Expense	37,127		35,631		36,098
INCOME (LOSS) BEFORE INCOME TAXES	145,858		116,519		181,793
INCOME TAX EXPENSE (BENEFIT)	47,534		44,197		71,747
Net income	98,324		72,322		110,046
Dividends on Washington Gas Light Company preferred stock	1,320		1,320		1,320
NET INCOME (LOSS) APPLICABLE TO COMMON STOCK	$ 97,004		$ 71,002		$ 108,726

[1] Operating revenues are reported gross of revenue taxes. Revenue taxes of both the regulated utility and the retail energy-marketing segments include gross receipt taxes. Revenue taxes of the regulated utility segment also include PSC fees, franchise fees and energy taxes. Operating revenue amounts in the "Eliminations" column represent total intersegment revenues associated with sales from the regulated utility segment to the retail energy-marketing segment. Midstream Energy Services' cost of energy related sales is netted with its gross revenues.

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Long-Term Debt

12 Months Ended

Sep. 30, 2014

Long-Term Debt [Abstract]

Long-Term Debt

NOTE 5. LONG-TERM DEBT

FIRST MORTGAGE BONDS

The Mortgage of Washington Gas dated January 1, 1933 (Mortgage), as supplemented and amended, securing any First Mortgage Bonds (FMBs) it issues, constitutes a direct lien on substantially all property and franchises owned by Washington Gas, other than a small amount of property that is expressly excluded. Washington Gas had no debt outstanding under the Mortgage at September 30, 2014 and 2013. Any FMBs that may be issued in the future will represent indebtedness of Washington Gas.

SHELF REGISTRATION

On August 18, 2014, WGL entered into an Indenture with The Bank of New York Mellon (the "Trustee") to issue an unlimited amount of debt securities. Supplemental indentures will supplement the Indenture and establish the respective terms of the notes. The offering of the notes has been registered under a shelf registration statement on Form S-3.

At September 30, 2014, Washington Gas had the capacity under a shelf registration to issue up to $275.0 million of additional MTNs.

UNSECURED NOTES

Washington Gas issues unsecured MTNs and private placement notes with individual terms regarding interest rates, maturities and call or put options. These notes can have maturity dates of one or more years from the date of issuance. At September 30, 2014 and 2013,outstanding MTNs and private placement notes were $691.0millionand $583.0 million, respectively, at a weighted average interest rate of5.65% and 5.91%, respectively.

The indenture for the unsecured MTNs and the note purchase agreement for the private placement notes provide that Washington Gas will not issue any FMBs under its Mortgage without securing all MTNs and the subject private placement notes with the Mortgage.

Certain of Washington Gas' outstanding MTNs and private placement notes have a make-whole call feature that pays the holder a premium based on a spread over the yield to maturity of a U.S. Treasury security having a comparable maturity, when that particular note is called by Washington Gas before its stated maturity date. With the exception of this make-whole call feature, Washington Gas is not required to pay call premiums for calling debt prior to the stated maturity date.

The table below shows MTN and private placement issuances and retirements for the year ended September 30, 2014.

MTN and Private Placement Issuances and Retirements
($ In millions)	Principal		Interest Rate	Nominal Maturity Date
Year Ended September 30, 2014
Issuances:
12/5/2013	$	75.0	5.00%(a)	12/15/2043
9/12/2014		100.0	4.22%(b)	9/15/2044
Total	$	175.0
Retirements:
11/7/2013	$	37.0	4.88%	11/7/2013
9/10/2014		30.0	5.17%	9/10/2014
Total	$	67.0
(a)The estimated effective cost of the issued notes, including consideration of issuances fees and hedge costs, is 4.95%.
(b)The estimated effective cost of the issued notes, including consideration of issuances fees and hedge costs, is 4.27%.

There were no MTN or private placement issuances or retirements for the year ended September 30, 2013.

LONG-TERM DEBT MATURITIES

Maturities of long-term debt for each of the next five fiscal years and thereafter as of September 30, 2014 are summarized in the following table.

Long-Term Debt Maturities(a)
(In millions)	MTNs		Other		Total
2015	$	20.0	$	-	$	20.0
2016		25.0		-		25.0
2017		-		-		-
2018		-		-		-
2019		50.0		-		50.0
Thereafter		596.0		-		596.0
Total (before project debt financing)	$	691.0	$	-	$	691.0
Project debt financing(b)		-		8.3		8.3
Total	$	691.0	$	8.3	$	699.3
Less: current maturities		20.0		-		20.0
Total non-current	$	671.0	$	8.3	$	679.3
(a)Excludes unamortized discounts of $121,567 at September 30, 2014.
(b)Project debt financing is anticipated to be a non-cash extinguishment. Refer to Note 13 - Commitments and Contingencies for further discussion of this construction project financing.

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Other Investments - Narratives (Details) (USD $)	Sep. 30, 2014	Sep. 30, 2013
Summary Of Investments Other Than Investments In Related Parties Reportable Data [Line Items]
Direct Fiinancing Leases Receivable	$ 22,000,000
WGL Holdings, Inc.
Summary Of Investments Other Than Investments In Related Parties Reportable Data [Line Items]
Assets	72,600,000	120,300,000
Investments in direct financing leases, capital leases	18,159,000	23,390,000
Investments in unconsolidated affiliates	100,528,000	67,522,000
WGL Holdings, Inc. | Crab Run [Member]
Summary Of Investments Other Than Investments In Related Parties Reportable Data [Line Items]
Investments in unconsolidated affiliates	0
WGL Holdings, Inc. | Warrant
Summary Of Investments Other Than Investments In Related Parties Reportable Data [Line Items]
Assets	0	1,100,000
Willams Partners L.P. | Constitution [Member]
Summary Of Investments Other Than Investments In Related Parties Reportable Data [Line Items]
Equity Method Investment Ownership Percentage	41.00%
Cabot Oil And Gas Corporation | Constitution [Member]
Summary Of Investments Other Than Investments In Related Parties Reportable Data [Line Items]
Equity Method Investment Ownership Percentage	25.00%
Piedmont Natural Gas | Constitution [Member]
Summary Of Investments Other Than Investments In Related Parties Reportable Data [Line Items]
Equity Method Investment Ownership Percentage	24.00%
COG Holdings LLC [Member] | Meade [Member]
Summary Of Investments Other Than Investments In Related Parties Reportable Data [Line Items]
Equity Method Investment Ownership Percentage	20.00%
Vega Midstream MPC LLC [Member] | Meade [Member]
Summary Of Investments Other Than Investments In Related Parties Reportable Data [Line Items]
Equity Method Investment Ownership Percentage	15.00%
River Road Interests LLC [Member] | Meade [Member]
Summary Of Investments Other Than Investments In Related Parties Reportable Data [Line Items]
Equity Method Investment Ownership Percentage	10.00%
WGL Midstream | Constitution [Member]
Summary Of Investments Other Than Investments In Related Parties Reportable Data [Line Items]
Estimated Investment In Constitution	72,000,000
Equity Method Investment Ownership Percentage	10.00%
Investments in unconsolidated affiliates	22,200,000
WGL Midstream | Meade [Member]
Summary Of Investments Other Than Investments In Related Parties Reportable Data [Line Items]
Equity Method Investment Ownership Percentage	55.00%
Pipeline length in miles	177
Transportation and delivery	1.7
VIE Maximum Loss Exposure	74,000,000
Estimated Investment in Meade	410,000,000
Investments in unconsolidated affiliates	5,800,000
WGSW, Inc. [Member] | Sun Edison/Nextility [Member]
Summary Of Investments Other Than Investments In Related Parties Reportable Data [Line Items]
Investments in direct financing leases, capital leases	19,900,000	29,200,000
Net Investment in Direct Financing Lease, Current	1,700,000	5,800,000
WGSW, Inc. [Member] | ASD Solar, LP [Member]
Summary Of Investments Other Than Investments In Related Parties Reportable Data [Line Items]
Equity Method Investment Difference Between Carrying Amount and Underlying Equity	35,900,000
Investments in unconsolidated affiliates	66,800,000
Washington Gas Resources Corp. | American Solar Direct Holdings Inc. (ASDHI)
Summary Of Investments Other Than Investments In Related Parties Reportable Data [Line Items]
Cost Method Investments	5,600,000	5,600,000
Warrants	$ 800,000	$ 1,900,000

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Derivative and Weather Related Instruments (Gains and Losses) (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2012
WGL Holdings, Inc.
Gains and (Losses) on Derivative Instruments
Recorded to other comprehensive income	$ (1.5)	[1]	$ 0	[1]	$ 0	[1]
Gains (Losses) On Derivative Instruments	(244.9)		(173.1)		50.4
Potential Collateral Requirements for Derivative Liabilities with Credit-risk-Contingent Features
Derivative liabilities with credit-risk-contingent features	28.8		77.0
Maximum potential collateral requirements	16.5		33.6
WGL Holdings, Inc. | Operating Revenues Non Utility [Member]
Gains and (Losses) on Derivative Instruments
Recorded to income	(47.9)		(9.9)		19.2
WGL Holdings, Inc. | Utility Cost Of Gas [Member]
Gains and (Losses) on Derivative Instruments
Recorded to income	(87.3)		(45.9)		22.3
WGL Holdings, Inc. | Non Utility Cost Of Energy Related Sales [Member]
Gains and (Losses) on Derivative Instruments
Recorded to income	36.2		(2.4)		(34.2)
WGL Holdings, Inc. | Other Income [Member]
Gains and (Losses) on Derivative Instruments
Other income net	(1.1)		0.2		0.9
WGL Holdings, Inc. | Gas Costs [Member]
Gains and (Losses) on Derivative Instruments
Recorded to regulatory assets/liabilities	(143.3)		(115.1)		42.2
WGL Holdings, Inc. | Other Regulatory Assets Liability [Member]
Gains and (Losses) on Derivative Instruments
Recorded to regulatory assets/liabilities	0.2		0		0
WGL Holdings, Inc. | Interest expense [Member]
Gains and (Losses) on Derivative Instruments
Recorded to income	(0.2)		0		0
Washington Gas Light Company
Gains and (Losses) on Derivative Instruments
Gains (Losses) On Derivative Instruments	(230.4)		(161.0)		64.5
Potential Collateral Requirements for Derivative Liabilities with Credit-risk-Contingent Features
Derivative liabilities with credit-risk-contingent features	20.6		44.7
Maximum potential collateral requirements	16.1		1.7
Washington Gas Light Company | Utility Cost Of Gas [Member]
Gains and (Losses) on Derivative Instruments
Recorded to income	(87.3)		(45.9)		22.3
Washington Gas Light Company | Gas Costs [Member]
Gains and (Losses) on Derivative Instruments
Recorded to regulatory assets/liabilities	(143.3)		(115.1)		42.2
Washington Gas Light Company | Other Regulatory Assets Liability [Member]
Gains and (Losses) on Derivative Instruments
Recorded to regulatory assets/liabilities	$ 0.2		$ 0		$ 0

[1] This pre-tax unrealized gain represents the effective portion of our cash flow hedge. Upon settlement of the hedge, the realized gain or loss, to the extent effective, will be amortized as an adjustment to the interest expense. We expect this amortization to be minimal for fiscal 2015.

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Committments and Contingencies - Tables (Details) (USD $)	Sep. 30, 2014
Minimum Payments Under Operating Leases [Abstract]
Operating Leases, Future Minimum Payments Due, Current	$ 7,800,000
Operating Leases, Future Minimum Payments, Due in Two Years	6,300,000
Operating Leases, Future Minimum Payments, Due in Three Years	4,900,000
Operating Leases, Future Minimum Payments, Due in Four Years	4,300,000
Operating Leases, Future Minimum Payments, Due in Five Years	1,000,000
Operating Leases, Future Minimum Payments, Due Thereafter	10,500,000
Operating Leases, Future Minimum Payments Due	34,800,000
Unrecorded Unconditional Purchase Obligation [Line Items]
Unrecorded Unconditional Purchase Obligation, Due within One Year	573,800,000
Unrecorded Unconditional Purchase Obligation, Due within Two Years	265,300,000
Unrecorded Unconditional Purchase Obligation, Due within Three Years	177,300,000
Unrecorded Unconditional Purchase Obligation, Due within Four Years	937,300,000
Unrecorded Unconditional Purchase Obligation, Due within Five Years	958,600,000
Unrecorded Unconditional Purchase Obligation, Due after Five Years	13,742,000,000
Unrecorded Unconditional Purchase Obligation	16,654,300,000
Gas Purchase Committments [Member]
Footnote Details [Abstract]
Commitments Related To Renewable Energy Credits	15,300,000	[1]
Gas Purchase Committments [Member] | Washington Gas Light Company
Unrecorded Unconditional Purchase Obligation [Line Items]
Unrecorded Unconditional Purchase Obligation, Due within One Year	280,000,000	[2]
Unrecorded Unconditional Purchase Obligation, Due within Two Years	288,900,000	[2]
Unrecorded Unconditional Purchase Obligation, Due within Three Years	336,700,000	[2]
Unrecorded Unconditional Purchase Obligation, Due within Four Years	323,200,000	[2]
Unrecorded Unconditional Purchase Obligation, Due within Five Years	303,500,000	[2]
Unrecorded Unconditional Purchase Obligation, Due after Five Years	2,990,200,000	[2]
Unrecorded Unconditional Purchase Obligation	4,522,500,000	[2]
Gas Purchase Committments [Member] | Retail Energy Marketing [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Unrecorded Unconditional Purchase Obligation, Due within One Year	167,500,000	[3]
Unrecorded Unconditional Purchase Obligation, Due within Two Years	49,200,000	[3]
Unrecorded Unconditional Purchase Obligation, Due within Three Years	13,800,000	[3]
Unrecorded Unconditional Purchase Obligation, Due within Four Years	600,000	[3]
Unrecorded Unconditional Purchase Obligation, Due within Five Years	0	[3]
Unrecorded Unconditional Purchase Obligation, Due after Five Years	0	[3]
Unrecorded Unconditional Purchase Obligation	231,100,000	[3]
Gas Purchase Committments [Member] | WGL Midstream
Unrecorded Unconditional Purchase Obligation [Line Items]
Unrecorded Unconditional Purchase Obligation, Due within One Year	29,200,000	[4]
Unrecorded Unconditional Purchase Obligation, Due within Two Years	24,400,000	[4]
Unrecorded Unconditional Purchase Obligation, Due within Three Years	80,200,000	[4]
Unrecorded Unconditional Purchase Obligation, Due within Four Years	906,000,000	[4]
Unrecorded Unconditional Purchase Obligation, Due within Five Years	933,400,000	[4]
Unrecorded Unconditional Purchase Obligation, Due after Five Years	13,479,800,000	[4]
Unrecorded Unconditional Purchase Obligation	15,453,000,000	[4]
Electric Purchase Committments [Member] | Retail Energy Marketing [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Unrecorded Unconditional Purchase Obligation, Due within One Year	359,400,000	[1]
Unrecorded Unconditional Purchase Obligation, Due within Two Years	171,700,000	[1]
Unrecorded Unconditional Purchase Obligation, Due within Three Years	65,000,000	[1]
Unrecorded Unconditional Purchase Obligation, Due within Four Years	3,600,000	[1]
Unrecorded Unconditional Purchase Obligation, Due within Five Years	0	[1]
Unrecorded Unconditional Purchase Obligation, Due after Five Years	0	[1]
Unrecorded Unconditional Purchase Obligation	599,700,000	[1]
Pipeline Contracts [Member] | Washington Gas Light Company
Unrecorded Unconditional Purchase Obligation [Line Items]
Unrecorded Unconditional Purchase Obligation, Due within One Year	195,400,000	[5]
Unrecorded Unconditional Purchase Obligation, Due within Two Years	224,700,000	[5]
Unrecorded Unconditional Purchase Obligation, Due within Three Years	217,700,000	[5]
Unrecorded Unconditional Purchase Obligation, Due within Four Years	211,100,000	[5]
Unrecorded Unconditional Purchase Obligation, Due within Five Years	201,300,000	[5]
Unrecorded Unconditional Purchase Obligation, Due after Five Years	1,205,300,000	[5]
Unrecorded Unconditional Purchase Obligation	2,255,500,000	[5]
Pipeline Contracts [Member] | Retail Energy Marketing [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Unrecorded Unconditional Purchase Obligation, Due within One Year	2,400,000	[6]
Unrecorded Unconditional Purchase Obligation, Due within Two Years	600,000	[6]
Unrecorded Unconditional Purchase Obligation, Due within Three Years	600,000	[6]
Unrecorded Unconditional Purchase Obligation, Due within Four Years	600,000	[6]
Unrecorded Unconditional Purchase Obligation, Due within Five Years	600,000	[6]
Unrecorded Unconditional Purchase Obligation, Due after Five Years	1,300,000	[6]
Unrecorded Unconditional Purchase Obligation	6,100,000	[6]
Pipeline Contracts [Member] | WGL Midstream
Unrecorded Unconditional Purchase Obligation [Line Items]
Unrecorded Unconditional Purchase Obligation, Due within One Year	15,300,000	[7]
Unrecorded Unconditional Purchase Obligation, Due within Two Years	19,400,000	[7]
Unrecorded Unconditional Purchase Obligation, Due within Three Years	17,700,000	[7]
Unrecorded Unconditional Purchase Obligation, Due within Four Years	26,500,000	[7]
Unrecorded Unconditional Purchase Obligation, Due within Five Years	24,600,000	[7]
Unrecorded Unconditional Purchase Obligation, Due after Five Years	260,900,000	[7]
Unrecorded Unconditional Purchase Obligation	$ 364,400,000	[7]

[1] Represents electric purchase commitments that are based on existing fixed price and fixed volume contracts. Includes $15.3 million of commitments related to renewable energy credits.

[2] (b) The contracts referenced above are estimated based on market prices at September 30, 2014.

[3] Represents fixed price commitments with city gate equivalent deliveries.

[4] Includes short-term commitments to purchase fixed volumes of natural gas, as well as long-term gas purchase commitments that contain fixed volume purchase requirements. Cost estimates are based on forward market prices for purchases under these purchase commitments.

[5] (a) Represents minimum payments for natural gas transportation, storage and peaking contracts that have expiration dates through fiscal year 2032.

[6] Represents minimum payments for natural gas transportation, storage and peaking contracts that have expiration dates through fiscal year 2025.

[7] Represents minimum payments for natural gas transportation, storage and peaking contracts that have expiration dates through fiscal year 2044.

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Document and Entity Information (USD $) In Thousands, except Share data, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Oct. 31, 2014	Mar. 31, 2014
Document and Entity Information [Abstract]
Entity Registrant Name	WGL Holdings Inc.
Entity Central Index Key	0001103601
Document Type	10-K
Document Period End Date	Sep. 30, 2014
Amendment Flag	false
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	Q4
Current Fiscal Year End Date	--09-30
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Public Float			$ 2,064,823,797
Entity Common Stock, Shares Outstanding		49,708,750

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Common Stock

12 Months Ended

Sep. 30, 2014

Common Stock, Number of Shares, Par Value and Other Disclosures [Abstract]

Common Stock

NOTE6. COMMON STOCK — WGL

COMMON STOCK OUTSTANDING

Shares of common stock outstanding were 50,656,553 and 51,774,204 at September 30, 2014 and 2013, respectively.

COMMON STOCK RESERVES

At September 30, 2014, there were 4,582,301authorized, but unissued, shares of common stock reserved under the following plans:

Common Stock Reserves
Reserve for:	Number of Shares
Omnibus incentive compensation plan(a)	999,443
Dividend reinvestment and common stock purchase plan	2,849,012
Employee savings plans	637,196
Directors’ stock compensation plan	96,650
Total common stock reserves	4,582,301
(a)In March 2007, WGL adopted a shareholder-approved Omnibus Incentive Compensation Plan to replace on a prospective basis the 1999 Incentive Compensation Plan. Included are shares that may be issued which would reduce the number of shares authorized under the Omnibus Incentive Compensation Plan. These shares include 301,378 shares dedicated to performance shares granted but not vested and include 5,318 shares dedicated to stock options issued but not exercised. Refer to Note 11 - Stock-Based Compensation for a discussion regarding our stock-based compensation plans.

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Pension and Other Post-retirement Benefit Plans (Table 8) (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2012
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan assets at end of year	$ 23.8		$ 21.1		$ 18.7
Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	803.7		748.4
Receivable (Payable)	1.0	[1]	(3.2)	[1]
Fair value of plan assets at end of year	804.7	[2]	745.2	[2]	750.6	[2]
Percentage of fair value of plan investments	99.90%		100.40%
Percent Receivable (Payable)	0.10%	[1]	(0.40%)	[1]
Total plan assets percent	100.00%		100.00%
Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	439.8		379.8
Receivable (Payable)	(0.2)		1.1
Fair value of plan assets at end of year	439.6		380.9		358.3
Percentage of fair value of plan investments	100.00%		99.70%
Percent Receivable (Payable)	0.00%		0.30%
Total plan assets percent	100.00%		100.00%
Level 1 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	32.9		32.4
Level 1 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0.8		0.6
Level 2 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	747.0		694.9
Level 2 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	439.0		379.2
Level 3 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	23.8		21.1
Level 3 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
Cash and Cash Equivalents [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0.6		0.9
Percentage of fair value of plan investments	0.10%		0.10%
Cash and Cash Equivalents [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0.8		0.6
Percentage of fair value of plan investments	0.20%		0.20%
Cash and Cash Equivalents [Member] | Level 1 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0.6		0.9
Cash and Cash Equivalents [Member] | Level 1 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0.8		0.6
Cash and Cash Equivalents [Member] | Level 2 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
Cash and Cash Equivalents [Member] | Level 2 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
Cash and Cash Equivalents [Member] | Level 3 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
Cash and Cash Equivalents [Member] | Level 3 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
Equity Securities US Small Cap [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	32.3		31.5
Percentage of fair value of plan investments	4.00%		4.20%
Equity Securities US Small Cap [Member] | Level 1 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	32.3		31.5
Equity Securities US Small Cap [Member] | Level 2 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
Equity Securities US Small Cap [Member] | Level 3 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
Equity Securities Preferred [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0.1		0.1
Percentage of fair value of plan investments	0.00%		0.00%
Equity Securities Preferred [Member] | Level 1 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
Equity Securities Preferred [Member] | Level 2 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0.1		0.1
Equity Securities Preferred [Member] | Level 3 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
US Treasury Securities [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	110.6		124.5
Percentage of fair value of plan investments	13.80%		16.70%
US Treasury Securities [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	25.6		23.6
Percentage of fair value of plan investments	5.80%		6.20%
US Treasury Securities [Member] | Level 1 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
US Treasury Securities [Member] | Level 1 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
US Treasury Securities [Member] | Level 2 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	110.6		124.5
US Treasury Securities [Member] | Level 2 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	25.6		23.6
US Treasury Securities [Member] | Level 3 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
US Treasury Securities [Member] | Level 3 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
US Government Agencies Debt Securities [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	2.0		1.7
Percentage of fair value of plan investments	0.50%		0.40%
US Government Agencies Debt Securities [Member] | Level 1 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
US Government Agencies Debt Securities [Member] | Level 2 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	2.0		1.7
US Government Agencies Debt Securities [Member] | Level 3 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
U S Government Agencies And Sponsored Entities Debt Securities [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	24.6		19.0
Percentage of fair value of plan investments	3.00%		2.50%
U S Government Agencies And Sponsored Entities Debt Securities [Member] | Level 1 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
U S Government Agencies And Sponsored Entities Debt Securities [Member] | Level 2 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	24.6		19.0
U S Government Agencies And Sponsored Entities Debt Securities [Member] | Level 3 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
Domestic Corporate Debt Securities [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	108.4		93.6
Percentage of fair value of plan investments	13.50%		12.60%
Domestic Corporate Debt Securities [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	34.0		28.7
Percentage of fair value of plan investments	7.70%		7.50%
Domestic Corporate Debt Securities [Member] | Level 1 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
Domestic Corporate Debt Securities [Member] | Level 1 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
Domestic Corporate Debt Securities [Member] | Level 2 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	108.4		93.6
Domestic Corporate Debt Securities [Member] | Level 2 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	34.0		28.7
Domestic Corporate Debt Securities [Member] | Level 3 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
Domestic Corporate Debt Securities [Member] | Level 3 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
Asset-backed Securities [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	1.8		1.9
Percentage of fair value of plan investments	0.20%		0.20%
Asset-backed Securities [Member] | Level 1 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
Asset-backed Securities [Member] | Level 2 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	1.8		1.9
Asset-backed Securities [Member] | Level 3 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
Municipalities | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	9.2		9.0
Percentage of fair value of plan investments	1.10%		1.20%
Municipalities | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	4.8		4.1
Percentage of fair value of plan investments	1.10%		1.10%
Municipalities | Level 1 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
Municipalities | Level 1 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
Municipalities | Level 2 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	9.2		9.0
Municipalities | Level 2 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	4.8		4.1
Municipalities | Level 3 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
Municipalities | Level 3 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
Foreign Corporate Debt Securities [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	23.8		18.4
Percentage of fair value of plan investments	3.00%		2.50%
Foreign Corporate Debt Securities [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	5.7		4.6
Percentage of fair value of plan investments	1.30%		1.20%
Foreign Corporate Debt Securities [Member] | Level 1 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
Foreign Corporate Debt Securities [Member] | Level 1 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
Foreign Corporate Debt Securities [Member] | Level 2 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	23.8		18.4
Foreign Corporate Debt Securities [Member] | Level 2 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	5.7		4.6
Foreign Corporate Debt Securities [Member] | Level 3 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
Foreign Corporate Debt Securities [Member] | Level 3 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0		0
Repurchase Agreements [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	2.5	[3]	1.0	[3]
Percentage of fair value of plan investments	0.30%	[3]	0.10%	[3]
Repurchase Agreements [Member] | Level 1 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0	[3]	0	[3]
Repurchase Agreements [Member] | Level 2 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	2.5	[3]	1.0	[3]
Repurchase Agreements [Member] | Level 3 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0	[3]	0	[3]
Fixed Income Securities Other [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	7.0	[4]	5.7	[4]
Percentage of fair value of plan investments	0.80%	[4]	0.80%	[4]
Fixed Income Securities Other [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	5.3	[5]	5.3	[5]
Percentage of fair value of plan investments	1.20%	[5]	1.40%	[5]
Fixed Income Securities Other [Member] | Level 1 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0	[4]	0	[4]
Fixed Income Securities Other [Member] | Level 1 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0	[5]	0	[5]
Fixed Income Securities Other [Member] | Level 2 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	7.0	[4]	5.7	[4]
Fixed Income Securities Other [Member] | Level 2 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	5.3	[5]	5.3	[5]
Fixed Income Securities Other [Member] | Level 3 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0	[4]	0	[4]
Fixed Income Securities Other [Member] | Level 3 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0	[5]	0	[5]
Mutual Funds [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	112.4	[6]	93.2	[6]
Percentage of fair value of plan investments	14.00%	[6]	12.50%	[6]
Mutual Funds [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	1.9	[7]
Percentage of fair value of plan investments	0.40%	[7]
Mutual Funds [Member] | Level 1 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0	[6]	0	[6]
Mutual Funds [Member] | Level 1 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0	[7]
Mutual Funds [Member] | Level 2 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	112.4	[6]	93.2	[6]
Mutual Funds [Member] | Level 2 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	1.9	[7]
Mutual Funds [Member] | Level 3 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0	[6]	0	[6]
Mutual Funds [Member] | Level 3 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0	[7]
Commingled Funds [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	359.7	[8]	311.2	[8]
Percentage of fair value of plan investments	81.80%	[8]	81.70%	[8]
Commingled Funds [Member] | Level 1 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0	[8]	0	[8]
Commingled Funds [Member] | Level 2 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	359.7	[8]	311.2	[8]
Commingled Funds [Member] | Level 3 [Member] | Other PostretirementBenefit Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0	[8]	0	[8]
Commingled Funds And Pooled Separate Accounts [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	340.0	[9]	316.6	[9]
Percentage of fair value of plan investments	42.30%	[9]	42.50%	[9]
Commingled Funds And Pooled Separate Accounts [Member] | Level 1 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0	[9]	0	[9]
Commingled Funds And Pooled Separate Accounts [Member] | Level 2 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	316.2	[9]	295.5	[9]
Commingled Funds And Pooled Separate Accounts [Member] | Level 3 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	23.8	[9]	21.1	[9]
Private Equity / Limited Partnership | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	30.5	[10]	33.3	[10]
Percentage of fair value of plan investments	3.80%	[10]	4.50%	[10]
Private Equity / Limited Partnership | Level 1 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0	[10]	0	[10]
Private Equity / Limited Partnership | Level 2 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	30.5	[10]	33.3	[10]
Private Equity / Limited Partnership | Level 3 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0	[10]	0	[10]
Futures Contract [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	(0.1)	[11]	(0.3)	[11]
Percentage of fair value of plan investments	0.00%	[11]	0.00%	[11]
Futures Contract [Member] | Level 1 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	0	[11]	0	[11]
Futures Contract [Member] | Level 2 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	(0.1)	[11]	(0.3)	[11]
Futures Contract [Member] | Level 3 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Fair value of plan investments	$ 0	[11]	$ 0	[11]

[1] At September 30, 2014, this receivable represents a pending trade for investment sales. At September 30, 2013, this payable represents a pending trade for investment purchases.

[2] The DB SERP and DB Restoration, included in pension benefits in the table above, have no assets.

[3] This category includes Treasury Bills with a pre-commitment from the counterparty to repurchase the same securities on the next business day at an agreed-upon price.

[4] This category primarily includes Yankee bonds and non-U.S. government bonds.

[5] At September 30, 2014 and 2013, this category consisted primarily of 82% non-U.S. government bonds and 18% Yankee bonds.

[6] At September 30, 2014 and September 30, 2013, investments in mutual funds consisted primarily of corporate fixed income instruments.

[7] At September 30, 2014, investments in mutual funds consisted primarily of 63% short-term obligations consisting of certificates of deposit and time deposits, 23% high-quality commercial paper, 6% repurchase agreements, 4% corporate notes of U.S. and foreign corporations and 4% U.S. governmental and U.S. agency securities.

[8] At September 30, 2014 and 2013, investments in commingled funds consisted primarily of 66% common stock of large-cap U.S. companies, 17% U.S. agency obligations and government sponsored entities and 17% corporate bonds.

[9] At September 30, 2014, investments in commingled funds and pooled separate accounts consisted primarily of 75% common stock of large-cap U.S. companies; 14% income producing properties located in the United States; 9% equity securities of non-U.S. companies; and 2% short-term money market investments. At September 30, 2013, investments in commingled funds and pooled separate accounts consisted primarily of 67% common stock of large-cap U.S. companies; 12% income producing properties located in the United States; 20% equity securities of non-U.S. companies; and 1% short-term money market investments.

[10] At September 30, 2014, investments in private equity/limited partnership consisted of common stock of international companies.

[11] At September 30, 2014, this category includes long-term U.S. Treasury interest rate futures contracts and interest rate put options.

XML

Commitments and Contingencies (Narrative) (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014 Counterparties		Sep. 30, 2013	Sep. 30, 2012
Commitments and Contingencies [Line Items]
Operating Leases, Rent Expense	$ 5.5		$ 5.6	$ 5.2
Construction Project Financing	8.3		6.7
Number Of Service Agreements With Pipeline Companies	4
Reserve for Bad Debt-Construction Project Financing	0		0
WGL Holdings, Inc.
Commitments and Contingencies [Line Items]
Recorded Unconditional Purchase Obligation	528.5
WGESystems
Commitments and Contingencies [Line Items]
Recorded Unconditional Purchase Obligation	6.0
Accrual for Loss Contingency	2.6
Other External Partners
Commitments and Contingencies [Line Items]
Recorded Unconditional Purchase Obligation	18.7
Maximum [Member]
Commitments and Contingencies [Line Items]
Pipeline Service Agreements Expiration Dates Range	2032
Other Agreements And Peaking Services Expiration Dates Range	2032
Maximum [Member] | WGEServices
Commitments and Contingencies [Line Items]
Asset Optimization Pipeline Transportation Storage And Peaking Contracts Range	2025	[1]
Maximum [Member] | WGL Midstream
Commitments and Contingencies [Line Items]
Asset Optimization Pipeline Transportation Storage And Peaking Contracts Range	2044	[2]
Minimum [Member]
Commitments and Contingencies [Line Items]
Pipeline Service Agreements Expiration Dates Range	2015
Other Agreements And Peaking Services Expiration Dates Range	2015
Asset Optimization Pipeline Transportation Storage And Peaking Contracts Range	2015
Retail Energy Marketing [Member]
Commitments and Contingencies [Line Items]
Recorded Unconditional Purchase Obligation	227.3
Subsidiary of Common Parent [Member] | WGL Midstream
Commitments and Contingencies [Line Items]
Recorded Unconditional Purchase Obligation	$ 276.5

[1] Represents minimum payments for natural gas transportation, storage and peaking contracts that have expiration dates through fiscal year 2025.

[2] Represents minimum payments for natural gas transportation, storage and peaking contracts that have expiration dates through fiscal year 2044.

XML

Consolidated Statements of Comprehensive Income (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2012
WGL Holdings, Inc.
Net Income	$ 107,260		$ 81,573		$ 141,138
Qualified cash flow hedging instruments	(1,548)	[1]	0		0
Pension and other post-retirement benefit plans
Change in prior service cost (credit)	6,095	[2],[3]	(1,671)	[2]	(640)
Change in actuarial net gain (loss)	1,594	[2]	3,399	[2]	(2,125)
Change in transition obligation	0	[2]	238	[2]	239
TOTAL OTHER COMPREHENSIVE INCOME (LOSS) BEFORE TAXES	6,141		1,966		(2,526)
INCOME TAX EXPENSE (BENEFIT) RELATED TO OTHER COMPREHENSIVE INCOME	3,054	[3]	813		(987)
OTHER COMPREHENSIVE INCOME (LOSS)	3,087		1,153		(1,539)
COMPREHENSIVE INCOME	110,347		82,726		139,599
Washington Gas Light Company
Net Income	98,324		72,322		110,046
Pension and other post-retirement benefit plans
Change in prior service cost (credit)	6,095	[2],[3]	(1,671)	[2]	(640)
Change in actuarial net gain (loss)	1,594	[2]	3,399	[2]	(2,125)
Change in transition obligation	0	[2]	238	[2]	239
TOTAL OTHER COMPREHENSIVE INCOME (LOSS) BEFORE TAXES	7,689		1,966		(2,526)
INCOME TAX EXPENSE (BENEFIT) RELATED TO OTHER COMPREHENSIVE INCOME	3,054	[3]	813		(987)
OTHER COMPREHENSIVE INCOME (LOSS)	4,635		1,153		(1,539)
COMPREHENSIVE INCOME	$ 102,959		$ 73,475		$ 108,507

[1] (c ) Cash flow hedging instruments represent interest rate swap agreements on debt issuances. Refer to Note 14 - Derivative and Weather-related Instruments for further discussion of the interest rate swap agreements.

[2] (a) These accumulated other comprehensive income components are included in the computation of net periodic benefit cost. Refer to Note 10-Pension and other post-retirement benefit plans for additional details.

[3] (b) The majority of the 2014 change to the prior service cost component of other comprehensive income is related to the impact of the OPEB plan amendment and re-measurement. Refer to Note 10-Pension and other post-retirement benefit plans for additional details.

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Consolidated Statements of Common Shareholders Equity - WGL (Washington Gas Light Company, USD $) In Thousands, except Share data, unless otherwise specified		Washington Gas Light Company USD ($)	Common Stock [Member] Washington Gas Light Company USD ($)	Paid-In Capital Washington Gas Light Company USD ($)	Retained Earnings Washington Gas Light Company USD ($)	Accumulated Other Comprehensive Loss, Net of Taxes Washington Gas Light Company USD ($)
Common shareholders' equity, beginning balance at Sep. 30, 2011		$ 990,135	$ 46,479	$ 473,099	$ 481,219	$ (10,662)
Beginning Balance, shares at Sep. 30, 2011			46,479,536
Net Income		110,046			110,046
OTHER COMPREHENSIVE INCOME (LOSS)		(1,539)				(1,539)
Stock-based compensation	[1]	2,535		2,535
Dividends declared:
Common Stock		(74,114)			(74,114)
Preferred Stock		(1,320)			(1,320)
Common shareholders' equity, ending balance at Sep. 30, 2012		1,025,743	46,479	475,634	515,831	(12,201)
Ending Balance, shares at Sep. 30, 2012			46,479,536
Net Income		72,322			72,322
OTHER COMPREHENSIVE INCOME (LOSS)		1,153				1,153
Stock-based compensation	[1]	2,334		2,334
Dividends declared:
Common Stock		(75,649)			(75,649)
Preferred Stock		(1,320)			(1,320)
Common shareholders' equity, ending balance at Sep. 30, 2013		1,024,583	46,479	477,968	511,184	(11,048)
Ending Balance, shares at Sep. 30, 2013			46,479,536
Net Income		98,324			98,324
OTHER COMPREHENSIVE INCOME (LOSS)		4,635				4,635
Stock-based compensation	[1]	2,652		2,652
Dividends declared:
Common Stock		(78,708)			(78,708)
Preferred Stock		(1,320)			(1,320)
Common shareholders' equity, ending balance at Sep. 30, 2014		$ 1,050,166	$ 46,479	$ 480,620	$ 529,480	$ (6,413)
Ending Balance, shares at Sep. 30, 2014			46,479,536

[1] Stock-based compensation is based on the stock awards of WGL Holdings that are allocated to Washington Gas Light Company for its pro-rata share.

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Consolidated Statements of Common Shareholders Equity (Parenthetical) - WGLH (WGL Holdings, Inc., USD $)	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
WGL Holdings, Inc.
DIVIDENDS DECLARED PER COMMON SHARE	$ 1.7400	$ 1.6600	$ 1.5875

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Stock Based Compensation

12 Months Ended

Sep. 30, 2014

Share-based Compensation [Abstract]

Disclosure of Compensation Related Costs, Share-based Payments [Text Block]

NOTE 11. STOCK-BASED COMPENSATION

STOCK-BASED COMPENSATION FOR KEY EMPLOYEES

We havestock-based awards outstanding in the form of stock options, performance shares and performance units. We have stock options outstanding under our shareholder-approved 1999 Incentive Compensation Plan, as amended and restated (1999 Plan). In March 2007, WGL adopted a shareholder-approved Omnibus Incentive Compensation Plan (Omnibus Plan) to replace, on a prospective basis, the 1999 Plan. Stock options, stock appreciation rights, restricted stock, deferred stock and stock as a bonus in lieu of other awards, dividend equivalents, other stock-based awards and cash awards may be granted under the Omnibus Plan. The Omnibus Plan allows WGL to issue up to 1,700,000 shares of common stock, subject to adjustment as provided by the plan, to persons including officers and key employees, designated by the Human Resources Committee of the Board of Directors. Refer to Note 6—Common Stock—WGL for amounts remaining to be issued under these plans.

During the fiscal year ended September 30, 2014, we granted performance shares and performance units under the Omnibus Plan. We have not issued stock options under either plan since October 2006.As of September 30, 2014, there are prior years' stock option grants outstanding for which the exercise price is equal to the market value of our common stock on the date of the grant.

For both performance shares and performance units, the actual award that may be earned varies based on the total shareholder return of WGL relative to a selected peer group of companies. These performance awards generally vest over three years from the date of grant. Performance sharesearned are paid in shares of common stock of WGL. Performance units are earned pursuant to terms of the grant, are paid in cash and are valued at $1.00 per performance unit. Outstanding stock options vestover three years from the date of the grant and expire ten years thereafter. Performance units, performance shares and stock option awards provide for accelerated vesting upon a change in control of WGL. Additionally, outstanding stock options provide for accelerated vesting upon retirement, death or disability of the recipient. We generally issue new shares of common stock to provide for redemption of performance shares and stock options; however, we may, from time to time, repurchase shares of our common stock on the open market in order to meet these requirements. Both performance shares and stock options are accounted for as equity awards, and performance units are accounted for as liability awards as they are settled in cash.

For the years ended September 30, 2014, 2013 and 2012, we recognized stock-based compensation expense of $3.4 million, $6.5 million and $3.6 million, net of related income tax benefits of $1.3 million, $2.6 million and $1.4 million, respectively.

As of September 30, 2014, total unrecognized compensation expense related to stock-based awards granted was $6.5 million. Performance shares and performance units comprised $4.0 million and $2.5 million of total unrecognized compensation expense, respectively. The total unrecognized compensation expense is expected to be recognized over a weighted average cost period of 1.7 years for performance shares and performance units.

Performance Shares

The following table summarizes information regarding performance share activity during the fiscal year ended September 30, 2014.

Performance Share Activity
	Year Ended
	September 30, 2014
	Number of Shares(a)	Weighted Average Grant-Date Fair Value
Non-vested and outstanding, beginning of year	295,973	$	39.88
Granted	109,076		42.88
Vested	(84,849)		41.14
Cancelled/forfeited	(18,822)		40.47
Non-vested and outstanding, end of year	301,378	$	40.57
(a)The number of common shares issued related to performance shares may range from zero to 200 percent of the number of shares shown in the table above based on our achievement of performance goals for total shareholder return relative to a selected peer group of companies.

The total fair value of the performance shares outstanding at September 30, 2014 for the shares expected to vest in the future was $11.6 million. Thetotal intrinsic value of performance shares vested during the year endedSeptember 30, 2014 was $2.2 million. No performance shares vested during the year ended September 30, 2013. The total intrinsic value of performance shares vested during the year ended September 30, 2012was $3.3 million.

We measure compensation expense related to performance shares based on the fair value of these awards at their date of grant. Compensation expense for performance shares is recognized for awards that ultimately vest and is not adjusted based on the actual achievement of performance goals. We estimated the fair value of performance shares on the date of grant using a Monte Carlo simulation model and the following assumptions:

Fair Value Assumptions
Years Ended September 30,	2014			2013			2012
Expected stock-price volatility		19.10	%		19.40	%		27.80	%
Dividend yield		3.93	%		3.98	%		3.97	%
Weighted average grant-date fair value	$	42.88		$	39.73		$	38.99

Expected stock-price volatility is based on the daily historical volatility of our common shares for the past three fiscal years. The dividend yield represents our annualized dividend yield on the closing market price of our common stock at the date of the grant.

Performance Units

Our performance units are liability awards as they settle in cash; therefore, we measure and record compensation expense for these awards based on their fair value at the end of each period until their vesting date. Consequently, fluctuations in earnings may result that do not occur under the accounting requirements for both our stock options and performance shares.

The following table summarizes information regarding performance unit activity during the fiscal year ended September 30, 2014.

Performance Unit Activity
	Year Ended
	September 30, 2014
	Number of Units
Non-vested and outstanding, beginning of year	11,582,556
Granted	4,658,648
Vested	(3,205,636)
Cancelled/forfeited	(766,647)
Non-vested and outstanding, end of year	12,268,921

The total fair value of performance units outstanding at September 30, 2014 for the units expected to vest in the future was $4.9 million. As of September 30, 2014, 2013 and 2012, we recorded a liability of $2.4 million, $4.9 million and $2.1 million, respectively, related to our performance units. This liability is recorded in “Deferred Credits—other”. During the fiscal year ended September 30, 2014, we paid $2.0 million in cash to settle performance unit awards. During fiscal year ended September 30, 2013, we did not make any cash payments to settle performance unit awards. During the fiscal year ended September 30, 2012, we paid $2.8million in cash to settle performance unit awards.

We estimated the fair value of performance units using a Monte Carlo simulation model. The following table provides the year-end assumptions used to value our performance units:

Fair Value Assumptions
	September 30, 2014
	10/1/2013 Grant	10/1/2012 Grant
Expected stock-price volatility	18.1%	19.5%

Expected stock-price volatility is based on the daily historical volatility of our common shares for a period equal to the remaining term of the performance units.

Stock Options

The following table summarizes information regarding stock option activity during the fiscal year ended September 30, 2014.

Stock Option Activity
	Number of Options	Weighted Average Exercise Price		Weighted Average Remaining Contractual Term (In years)	Aggregate Intrinsic Value (In thousands)
Outstanding at September 30, 2013	26,372	$	31.34	4.01	$	235
Granted	-		-	-		-
Exercised	(21,054)		31.34	-		232
Cancelled/forfeited	-		-	-		-
Outstanding at September 30, 2014	5,318	$	31.34	2.00	$	57
Exercisable at September 30, 2014	5,318	$	31.34	2.00	$	57

We received $0.7 million from the exercise of stock options during the year ended September 30, 2014. There were no stock options exercised during the year ended September 30, 2013 and no related tax benefits realized. We received $0.8 million from the exercise of stock options during the year ended2012. The related tax benefits realized for the fiscal years ended September 30, 2014 and 2012 were $0.1 million and $0.1 million, respectively.

We measure compensation expense related to stock options based on the fair value of these awards at their date of grant. Compensation expense for stock options is recognized for awards that ultimately vest. We estimated the fair value of stock options on the date of the grant using the Black-Scholes option-pricing model.

Expected stock-price volatility is based on the daily historical volatility of our common shares over a period that approximates the expected term of the stock options. The dividend yield represents our annualized dividend yield on the closing market price of our common stock at the date of grant. The risk-free interest rate is based on the zero-coupon U.S. Treasury bond, with a term equal to the expected term of the stock options. The expected option term is based on our historical experience with respect to stock option exercises and expectations about future exercises.

STOCK GRANTS TO DIRECTORS

Non-employee directors receive a portion of their annual retainer fee in the form of common stock through the Directors' Stock Compensation Plan. Up to 270,000 shares of common stock may be awarded under the plan.Shares granted to directors were approximately 17,000,16,600 and 11,900 for the fiscal years ended September 30, 2014,2013 and 2012, respectively. For those years, the weighted average fair value of the stock on the grant dates was $40.06,$40.46, and $44.30, respectively. Shares awarded to the participants; (i) vest immediately and cannot be forfeited; (ii) may be sold or transferred and (iii) have voting and dividend rights. For each of the years ended September 30, 2014 and 2013, WGL recognized stock-based compensation expense related to stock grants of $0.7 million, net of related income tax benefits of $0.3 million. For the year ended September 30, 2012, WGL recognized stock-based compensation expense related to stock grants of $0.5 million, net of related income tax benefits of $0.2 million.

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Preferred Stock

12 Months Ended

Sep. 30, 2014

Preferred Stock [Abstract]

Preferred Stock

NOTE 7. PREFERRED STOCK

Washington Gas has three series of cumulative preferred stock outstanding, and each series is subject to redemption by Washington Gas. All three series have a dividend preference that prohibits Washington Gas from declaring and paying dividends on shares of its common stock unless dividends on all outstanding shares of the preferred stock have been fully paid for all past quarterly dividend periods. In addition, all outstanding shares of preferred stock have a preference as to the amounts that would be distributed in the event of a liquidation or dissolution of Washington Gas. The following table presents this information, as well as call prices for each preferred stock series outstanding.

Preferred Stock
Preferred		Liquidation Preference
Series	Shares		Per Share				Call Price
Outstanding	Outstanding		Involuntary		Voluntary		Per Share
$4.80	150,000	$100		$101		$101
$4.25	70,600	$100		$105		$105
$5.00	60,000	$100		$102		$102

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Share Based Compensation (Narrative) (Details) (USD $) In Millions, except Share data, unless otherwise specified	12 Months Ended
	Sep. 30, 2014		Sep. 30, 2013	Sep. 30, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense recognized	$ 3.4		$ 6.5	$ 3.6
Unrecognized compensation expense	6.5
Weighted-average period remaining to recognize unrecognized compensation expense	1 year 8 months
Tax benefit from compensation expense	1.3		2.6	1.4
Performances Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation expense	4.0
Intrinsic Value Performance Shares Vested	2.2		0	3.3
Minimum percentage of performance shares issued	0.00%
Maximum percentage of performance shares issued	200.00%
Shares granted during the period	109,076	[1]
Weighted-average grant date fair value, vested	$ 41.14
Fair value of shares expected to vest	11.6
Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation expense	2.5
Value of performance units vested	$ 1.00
Fair value of units expected to vest	4.9
Cash To Settle Performance Unit Awards	2.0		0	2.8
Shares granted during the period	4,658,648
Liability for Equity Option Awards Outstanding	2.4		4.9	2.1
Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Cash received from stock options exercised	0.7		0	0.8
Tax benefit realized from exercised stock options	0.1		0	0.1
Omnibus Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares authorized for issue under plan	1,700,000
Directors Stock Compensation Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares authorized for issue under plan	270,000
Compensation expense recognized	0.7		0.7	0.5
Tax benefit from compensation expense	$ 0.3		$ 0.3	$ 0.2
Shares granted during the period	17,000		16,600	11,900
Weighted-average grant date fair value, vested	$ 40.06		$ 40.46	$ 44.30

[1] The number of common shares issued related to performance shares may range from zero to 200 percent of the number of shares shown in the table above based on our achievement of performance goals for total shareholder return relative to a selected peer group of companies.

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Accounts Payable and Other Accrued Liabilities

12 Months Ended

Sep. 30, 2014

Accounts Payable and Other Accrued Liabilities [Abstract]

Accounts Payable and Other Accrued Liabilities

NOTE 3.ACCOUNTS PAYABLE AND OTHER ACCRUED LIABILITIES

The tables below provide details for the amounts included in “Accounts payable and other accrued liabilities” on the balance sheets for both WGL and Washington Gas.

WGL Holdings, Inc.
		September 30,
(In millions)		2014		2013
Accounts payable—trade	$	278.8	$	216.3
Employee benefits and payroll accruals		19.8		23.4
Embedded derivatives and other accrued liabilities		14.6		30.9
Total	$	313.2	$	270.6
Washington Gas Light Company
		September 30,
(In millions)		2014		2013
Accounts payable—trade	$	146.4	$	99.7
Employee benefits and payroll accruals		18.2		21.4
Embedded derivatives and other accrued liabilities		11.9		11.7
Total	$	176.5	$	132.8

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Short-Term Debt (Details) (USD $)	Sep. 30, 2014		Sep. 30, 2013
Line Of Credit Facility [Line Items]
Unsecured revolving credit facility	$ 800,000,000	[1]	$ 800,000,000	[1]
Less: Commercial Paper	453,500,000		373,100,000
Net committed credit available	346,500,000		426,900,000
Short-term debt weighted average interest rate	0.19%		0.19%
Ratio Of Indebtedness To Net Capital Percentage	65.00%
Outstanding bank loans	0		0
Maximum [Member]
Line Of Credit Facility [Line Items]
Ratio of Indebtedness to Net Capital	1.0
Minimum [Member]
Line Of Credit Facility [Line Items]
Ratio of Indebtedness to Net Capital	0.65
WGL Holdings, Inc.
Footnote Details [Abstract]
Revolving credit facility maximum borrowing capacity	550,000,000		550,000,000
Revolving credit facility additional borrowings	100,000,000		100,000,000
Line Of Credit Facility [Line Items]
Less: Commercial Paper	453,500,000		373,100,000
Washington Gas Light Company
Footnote Details [Abstract]
Revolving credit facility maximum borrowing capacity	450,000,000		450,000,000
Revolving credit facility additional borrowings	100,000,000		100,000,000
Line Of Credit Facility [Line Items]
Unsecured revolving credit facility	350,000,000	[1]	350,000,000	[1]
Less: Commercial Paper	89,000,000		124,500,000
Net committed credit available	261,000,000		225,500,000
Short-term debt weighted average interest rate	0.13%		0.13%
Non Utility [Member]
Line Of Credit Facility [Line Items]
Unsecured revolving credit facility	450,000,000	[1],[2]	450,000,000	[1],[2]
Less: Commercial Paper	364,500,000	[2]	248,600,000	[2]
Net committed credit available	$ 85,500,000	[2]	$ 201,400,000	[2]
Short-term debt weighted average interest rate	0.20%		0.21%

[1] Both WGL and Washington Gas have the right to request extensions with the banks’ approval. WGL’s revolving credit facility permits it to borrow an additional $100 million, with the banks’ approval, for a total of $550 million. Washington Gas’ revolving credit facility permits it to borrow an additional $100 million, with the banks’ approval, for a total of $450 million.

[2] WGL Holdings includes all subsidiaries other than Washington Gas Light Company.

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Quarterly Financial Information - Narrative (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended			3 Months Ended		12 Months Ended		3 Months Ended
	Sep. 30, 2014 Washington Gas	Sep. 30, 2013 Washington Gas	Sep. 30, 2012 Washington Gas	Jun. 30, 2014 Abandoned LNG storage project	Sep. 30, 2013 Abandoned LNG storage project	Sep. 30, 2014 Abandoned LNG storage project	Sep. 30, 2013 Abandoned LNG storage project	Dec. 31, 2013 Springfield Operations Center	Sep. 30, 2013 Springfield Operations Center
Impairment loss	$ 2,639	$ 2,600	$ 5,015	$ 1,900	$ 500	$ 1,900	$ 500	$ 800	$ 2,600

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Accounting Policies

12 Months Ended

Sep. 30, 2014

Accounting Policies [Abstract]

Organization Consolidation And Presentation Of Financial Statements Disclosure Text Block

NOTE 1.ACCOUNTING POLICIES

GENERAL

WGL Holdings, Inc. (WGL) is a holding company that owns all of the shares of common stock of Washington Gas Light Company (Washington Gas), a regulated natural gas utility, and all of the shares of common stock of Washington Gas Resources Corporation (Washington Gas Resources), Hampshire Gas Company (Hampshire) and Crab Run Gas Company. Washington Gas Resources owns all of the shares of common stock of four non-utility subsidiaries that include Washington Gas Energy Services, Inc. (WGEServices), Washington Gas Energy Systems, Inc. (WGESystems), WGL Midstream and WGSW, Inc. (WGSW). Except where the content clearly indicates otherwise, “WGL,” “we,” “us” or “our” refers to the holding company or the consolidated entity of WGL Holdings, Inc. and all of its subsidiaries. Unless otherwise noted, these notes apply equally to WGL and Washington Gas.

NATURE OF OPERATIONS

Washington Gas and Hampshire comprise our regulated utility segment. Washington Gas is a public utility that sells and delivers natural gas to more than one million customers primarily in the District of Columbia, and the surrounding metropolitan areas in Maryland and Virginia. Deliveries to firm residential and commercial customers accounted for 78.1% of the total therms delivered to customers by Washington Gas in fiscal year September 30, 2014. Deliveries to interruptible customers accounted for 14.3% and deliveries to customers who use natural gas to generate electricity accounted for 7.6%. These amounts do not include deliveries related to Washington Gas' asset optimization program discussed below. Hampshire operates an underground natural gas storage facility that provides services exclusively to Washington Gas. Hampshire is regulated under a cost of service tariff by the Federal Energy Regulatory Commission (FERC).

The retail energy-marketing segment consists of WGEServices which competes with regulated utilities and other unregulated third party marketers to sell natural gas and electricity directly to residential, commercial, industrial and governmental customers with the objective of earning a profit through competitive pricing. The commodities that WGEServices sells are delivered to retail customers through assets owned by regulated utilities. Washington Gas delivers the majority of natural gas sold by WGEServices, and unaffiliated electric utilities deliver all of the electricity sold. WGEServices owned multiple solar PV distributed generation assets at September 30, 2014, though the results from these activities are presented in the commercial energy systems segment. Other than these facilities, WGEServices does not own or operate any other natural gas or electric generation, production, transmission or distribution assets. At September 30, 2014, WGEServices served approximately157,000 natural gas customers and approximately162,000 electricity customers located in Maryland, Virginia, Delaware, Pennsylvania and the District of Columbia.

The commercial energy systems segment consists of WGESystems, WGSW and the results of operations of affiliate owned commercial distributed energy projects. This segment focuses on clean and energy efficient solutions for its customers, driving earnings through (i) upgrading the mechanical, electrical, water and energy-related infrastructure of large governmental and commercial facilities by implementing both traditional as well as alternative energy technologies; (ii) owning and operating distributed generation assets such as solar PV systems, combined heat and power plants, and natural gas fuel cells and (iii) passive investments in residential and commercial retail solar PV companies. This segment has activities in 15 different states and the District of Columbia, but is concentrated in the mid-Atlantic and northeast regions.

The midstream energy services segment, which consists of the operations of WGL Midstream, engages in investing in and optimizing natural gas pipelines and storage facilities in the Midwest and Eastern United States. WGL Midstreamenters into both physical and financial transactions in a manner intended to utilize the most effective energy risk management products available to mitigate risks while maximizing potential profits from the optimization of these assets under its management.

Refer to Note 16—Operating SegmentReporting for further discussion of our segments.

CONSOLIDATION OF FINANCIAL STATEMENTS

The consolidated financial statements include the accounts of WGL and its subsidiaries during the fiscal years reported. Certain prior period amounts have been recast to conform to current period presentation. Inter-company transactions have been eliminated. Refer to Note 18—Related Party Transactions for a discussion of inter-company transactions. WGL has a variable interest in five investments that qualify as variable interest entities (VIEs). At September 30, 2014, WGL and its subsidiaries are not the primary beneficiary for any of the VIEs, therefore we have not consolidated any of the VIE entities. Our other investment projects are recorded using the cost method and as direct financing leases. Refer to Note 17—Other Investments for a discussion of VIEs and other investments.

USE OF ESTIMATES IN THE PREPARATION OF FINANCIAL STATEMENTS

In accordance with generally accepted accounting principles in the United States of America (GAAP), we make certain estimates and assumptions regarding: (i) reported assets and liabilities; (ii) disclosedcontingent assets and liabilities at the date of the financial statements and (iii) reported revenues, revenues subject to refund, and expenses during the reporting period. Actual results could differ from those estimates.

PROPERTY, PLANT AND EQUIPMENT

Property, plant and equipment (comprised principally of utility plant) are stated at original cost, including labor, materials, taxes and overhead costs incurred during the construction period. The cost of utility plant of Washington Gas includes an allowance for funds used during construction (AFUDC) that is calculated under a formula prescribed by our regulators. Washington Gas capitalizes AFUDC as a component of construction overhead. The before-tax rates for AFUDC for fiscal years September 30, 2014, 2013 and 2012 were 3.36%, 5.43% and 7.40%, respectively.

Washington Gas charges maintenance and repairs directly to operating expenses, except those charges applicable to transportation and power-operated equipment, which it allocates to operating expenses, construction and other accounts based on the use of the equipment. Washington Gas capitalizes betterments and renewal costs, and calculates depreciation applicable to its utility gas plant in service primarily using a straight-line method over the estimated remaining life of the plant. The composite depreciation and amortization rate of the regulated utility segment was 2.77%, 2.86% and 2.87% during fiscal years 2014, 2013 and 2012, respectively. In accordance with regulatory requirements, such rates include a component related to asset removal costs for Washington Gas. These asset removal costs are accrued through depreciation expense with a corresponding credit to “Regulatory liabilities—Accrued asset removal costs.” When Washington Gas retires depreciable utility plant and equipment, it charges the associated original costs to “Accumulated depreciation and amortization” and any related removal costs incurred are charged to “Regulatory liabilities—Accrued asset removal costs.” Washington Gas periodically reviews the adequacy of its depreciation rates by considering estimated remaining lives and other factors. For information about Asset Retirement Obligations (ARO's), refer to the section entitled "Asset Retirement Obligatons".

At September 30, 2014 and 2013, 93.6% and 95.6%, respectively, of WGL's consolidated original cost of property, plant and equipment was related to the regulated utility segment as shown below.

Property, Plant and Equipment at Original Cost
September 30,		2014			2013
($ In millions)		Dollars	%		Dollars	%
Regulated utility segment
Distribution, transmission and storage	$	3,635.3	79.3	$	3,356.1	81.5
General, miscellaneous and intangibles		448.3	9.8		430.6	10.4
Construction work in progress (CWIP)		203.9	4.5		150.8	3.7
Total regulated utility segment		4,287.5	93.6		3,937.5	95.6
Unregulated segments		295.3	6.4		180.6	4.4
Total	$	4,582.8	100.0	$	4,118.1	100.0

IMPAIRMENT OF LONG-LIVED ASSETS

Management regularly reviews property and equipment and other long-lived assets, including certain definite-lived intangible assets and our equity method investments for possible impairment. This review occurs quarterly, or more frequently if events or changes in circumstances indicate the carrying amount of the asset may not be recoverable.

DuringSeptember 30, 2014, 2013 and 2012, Washington Gas recorded impairment charges of $0.8 million, $2.6 million and $5.0 million, respectively, in operation and maintenance expense related to its Springfield Operations Center asset.Washington Gas is actively marketing the unused operations facility for sale. At September 30, 2014 and 2013, Washington Gas recorded a $1.9 million and $0.5 million impairment loss for the unrecoverable portion of the costs incurred associated with an abandoned LNG storage project.

For our equity and cost method investments, an impairment is recorded when the investment has experienced decline in value that is other-than-temporary. Additionally, if the projects in which we hold an investment recognize an impairment loss, we would record our proportionate share of that impairment loss and evaluate the investment for decline in value that is other-than-temporary. There were no events or circumstances during the years ended September 30, 2014,2013 and2012 that resulted in any impairment charges.

OPERATING LEASES

We have classified the lease of our corporate headquarters as an operating lease. We amortize as rent expense the total of all scheduled lease payments (including lease payment escalations) and tenant allowances on a straight-line basis over the term of the lease. For this purpose, the lease term began on the date when the lessor commenced constructing the leasehold improvements which allowed us to occupy our corporate headquarters. Leasehold improvement costs are classified as “Property, Plant and Equipment” on the Balance Sheets, and are being amortized to depreciation and amortization expense on a straight-line basis over the 15-year non-cancelable period of the lease. Refer to Note 13—Commitments andContingencies for financial data for all of our operating leases.

CASH AND CASH EQUIVALENTS

We consider all investments with original maturities of three months or less to be cash equivalents. We did not have any restrictions on our cash balances that would impact the payment of dividends by WGL or our subsidiaries as of September 30, 2014 and 2013.

REVENUE AND COST RECOGNITION

Regulated Utility Operations

Revenues.  For regulated deliveries of natural gas, Washington Gas reads meters and bills customers on a 21 day monthly cycle basis. The billing cycles for customers do not coincide with the accounting periods used for financial reporting purposes; therefore, Washington Gas accrues unbilled revenues for gas delivered, but not yet billed, at the end of each accounting period.

Cost of Gas.  Washington Gas' jurisdictional tariffs contain mechanisms that provide for the recovery of the cost of gas incurred on behalf of firm customers, including related pipeline transportation and storage capacity charges. Under these mechanisms, Washington Gas periodically adjusts its firm customers' rates to reflect increases and decreases in these costs. Under or over-collections of gas costs in the current cycle are charged or credited to deferred charges or credits on the balance sheet as non-current regulatory assets or liabilities. Amounts deferred at the end of the cycle, August 31 of each year, are fully reconciled and transferred to current assets or liabilities under the balance sheet captions “Gas costs and other regulatory assets” and “Gas costs and other regulatory liabilities.” These balances are recovered or refunded to customers over the subsequent 12 month period.

Revenue Taxes.  Revenue taxes such as gross receipts taxes, Public Service Commission (PSC) fees, franchise fees and energy taxes are reported gross in operating revenues. Refer to Note 16—Operating Segment Reporting for amounts recorded related to revenue taxes.

Transportation Gas Imbalance.  Interruptible shippers and third party marketer shippers transport gas to Washington Gas' distribution system as part of the unbundled services offered. The delivered volumes of gas from third party shippers into Washington Gas' distribution system rarely equal the volumes billed to third party marketer customers, resulting in transportation gas imbalances. These imbalances are usually short-term in duration, and Washington Gas monitors the activity and regularly notifies the shippers when their accounts have an imbalance. In accordance with regulatory treatment, Washington Gas does not record a receivable from or liability to third party marketers associated with gas volumes related to these transportation imbalances but, rather, reflects the financial impact as a regulatory asset or liability related to its gas cost adjustment mechanism, thereby eliminating any profit or loss that would occur as a result of the imbalance. The regulatory treatment combines the imbalance for all marketers, including WGEServices, into a single “net” adjustment to the regulatory asset or liability. Refer to Note 18—Related Party Transactions for further discussion of the accounting for these imbalance transactions.

Asset Optimization Program.  Washington Gas optimizes the value of its long-term natural gas transportation and storage capacity resources by entering into physical and financial transactions in the form of forwards, futures and option contracts for periods when these resources are not being used to physically serve utility customers. Refer to “Derivative Activities” below for further discussion of the accounting for derivative transactions entered into under this program. Regulatory sharing mechanisms in all three jurisdictions allow the profit from these transactions to be shared between Washington Gas' customers and shareholders.

All unrealized fair value gains and losses, and margins generated from the physical and financial settlement of these asset optimization contracts are recorded in utility cost of gas or, in the case of amounts to be shared with rate payers, regulatory liabilities.

Non-Utility Operations

Retail Energy-Marketing Segment.WGEServices sells natural gas and electricity on an unregulated basis to residential, commercial and industrial customers both inside and outside the Washington Gas service territory.

WGEServices enters into indexed or fixed-rate contracts with residential, commercial and industrial customers for sales of natural gas and electricity. Customer contracts, which typically have terms less than 24 months, but may extend up to five years, allow WGEServices to bill customers based upon metered gas and electricity usage. Usage is measured either on a cycle basis at customer premises or based on quantities delivered to the local utility, both of which may vary by month. The billing cycles for customers do not coincide with the accounting periods used for financial reporting purposes; therefore, WGEServices accrues unbilled revenues for gas and electricity delivered, but not yet billed, at the end of each accounting period. Revenues are reflected in “Operating Revenues—Non utility.”

WGEServices procures natural gas and electricity supply under contract structures in which it assembles the various components of supply from multiple suppliers to match its customer requirements. The cost of natural gas and electricity for these purchases is recorded using the contracted volumes and prices in “Non-Utility cost of energy-related sales.”

Commercial Energy Systems Segment.WGESystems recognizes income and expenses for all design-build construction contracts using the percentage-of-completion method in “Operating Revenues—Non-utility” and “Non-Utility cost of energy-related sales.”WGESystems also recognizes income from its distributed energy assets based on the terms of the related power purchase agreements. Solar Renewable Energy Certificates (SRECs) are recorded as inventory by WGESystems after every 1,000 Kilowatt-hours (kwh) of electricity are produced by an eligible solar facility. WGESystems recognizes income on the sale of SRECs based on the contractual terms and conditions of the sale. WGSW recognizes income on its investments in distributed energy assets based on the specific terms of its sale leaseback arrangementsand through the hypothetical liquidation at book value approach to the equity method of investment accounting for its investment interest. Other income and expense is recognized from the lease of distributed energy assets associated with the SunEdison and Nextilityassociations.

Midstream Energy Services Segment.WGL Midstream reports its margins in non-utility revenue by netting its cost / loss on physical and financial gas purchase contracts with revenues / gains on physical and financial gas sales contracts.

Other Activities.Washington Gas Resourcesrecognizes income on its investment using the cost approach of investment accounting. Crab Run recognizes income using the equity method of accounting.

STORAGE GAS VALUATION METHODS

For Washington Gas and WGEServices, storage gas inventory is stated at the lower-of-cost or market as determined using the first-in, first-out method. For WGL Midstream, storage gas inventory is stated at the lower-of-cost or market using the weighted average cost method.

For the fiscal year ended September 30, 2014, Washington Gas recorded a decrease to net income due to a lower-of-cost or market adjustment of $0.2million. For the fiscal year ended September 30, 2013, Washington Gas did not record any lower-of-cost or market adjustments. For the fiscal year ended September 30, 2012, Washington Gas recorded a decrease to net income due to a lower-of-cost or market adjustment of $1.4million. For the fiscal years ended September 30, 2014, 2013 and 2012, WGEServices did not record any lower-of-cost or market adjustments. For the fiscal years ended September 30, 2014, 2013 and 2012, WGL Midstream recorded a decrease to net income due to lower-of-cost or market adjustments of $3.0 million, $10.1 million and $22.4 million, respectively.

RATE REFUNDS DUE TO CUSTOMERS

When Washington Gas files a request with certain regulatory commissions to modify customers' rates, it is permitted to charge customers new rates, subject to refund, until the regulatory commission renders a final decision on the amount of the authorized change in rates. During this interim period, Washington Gas records a provision for a rate refund regulatory liability based on the difference between the amount it collects in rates and the amount it expects to recover from a final regulatory decision. Similarly, Washington Gas periodically records provisions for rate refunds related to other transactions. Actual results for these regulatory contingencies are often difficult to predict and could differ significantly from the estimates reflected in the financial statements. Refer to Note 13—Commitments and Contingencies for further discussion of regulatory matters and related contingencies.

WEATHER-RELATED INSTRUMENTS

Periodically, we purchase certain weather-related instruments, such as HDD derivatives and CDD derivatives. We account for these weather related instruments in accordance with Financial Accounting Standards Board Accounting Standards Codification (ASC) Subtopic 815-45, Derivatives and Hedging—Weather Derivatives. For weather insurance policies and HDD derivatives, benefits or costs are ultimately recognized to the extent actual HDDs fall above or below the contractual HDDs for each instrument. Benefits or costs are recognized for CDD derivatives when the average temperature exceeds a contractually stated level during the contract period. Premiums for weather-related instruments are amortized based on the pattern of normal temperature days over the coverage period. Weather-related instruments for which we collect a premium are carried at fair value. Washington Gas' weather related instrument premium expense or benefit is not considered in establishing retail rates. Washington Gas does not purchase such instruments for jurisdictions in which it has received rate mechanisms that compensate it on a normal weather basis. Refer to Note 14—Derivative and Weather-Related Instruments for further discussion of our weather-related instruments.

DERIVATIVE ACTIVITIES

Regulated Utility.Washington Gas enters into both physical and financial derivative contracts for the purchase and sale of natural gas that are subject to mark-to-market accounting. Changes in the fair value of derivative instruments recoverable or refundable to customers and therefore subject to ASC Topic 980, Regulated Operations, are recorded as regulatory assets or liabilities while changes in the fair value of derivative instruments not affected by rate regulation are reflected in earnings.

As part of its asset optimization program, Washington Gas enters into derivative contracts related to the sale and purchase of natural gas at a future price with the primary objective of locking in operating margins that Washington Gas expects to ultimately realize. The derivatives used under this program may cause significant period-to-period volatility in earnings for the portion of net profits retained for shareholders; however, this volatility will not change the margins that Washington Gas expects to realize from these transactions. In accordance with ASC Topic 815, all financially and physically settled contracts under our asset optimization program are reported on a net basis in the statements of income in “Utility cost of gas”.

From time to time, Washington Gas also utilizes derivative instruments that are designed to minimize the risk of interest-rate volatility associated with planned issuances of Medium-Term Notes (MTNs). Gains or losses associated with these derivative transactions are deferred as regulatory assets or liabilities and amortized to interest expense in accordance with regulatory accounting requirements. Refer to Note 14—Derivative and Weather-Related Instruments for further discussion of our derivative activities.

Non-Utility Operations.WGEServices enters into both physical and financial contracts for the purchase and sale of natural gas and electricity. We designate a portion of these physical contracts related to the purchase of natural gas and electricity to serve our customers as “normal purchases and normal sales;” therefore, they are not subject to the mark-to-market accounting requirements of ASC Topic 815. WGL Midstream enters into derivative contracts for the purpose of optimizing its storage and transportation capacity as well as managing the transportation and storage assets on behalf of third parties. The financial contracts and the portion of the physical contracts that qualify as derivative instruments and are subject to the mark-to-market accounting requirements are recorded on the balance sheet at fair value and are reflected in earnings. WGEServices records these derivatives as revenues or expenses depending on the nature of the economically hedged item.WGL Midstream nets financial and physical contracts in revenues.WGL may, from time to time, designate interest rate swaps used to manage the interest rate risk associated with future debt issuances, as cash flow hedges. Any gains or losses arising from the effective portion of cash flow hedges are recorded in other comprehensive income and are amortized using the effective interest rate method into earnings over the same period as the hedged interest payments are made.  Gains or losses arising from the ineffective portion of cash flow hedges are recognized in earnings immediately.

INCOME TAXES

We recognize deferred income tax assets and liabilities for all temporary differences between the financial statement basis and the tax basis of assets and liabilities, including those where regulators prohibit deferred income tax treatment for ratemaking purposes of Washington Gas. Regulatory assets or liabilities, corresponding to such additional deferred income tax assets or liabilities, may be recorded to the extent recoverable from or payable to customers through the ratemaking process. Refer to Note 2—Regulated Operationsfor Washington Gas' regulatory assets and liabilities associated with income taxes due from and to customers at September 30, 2014 and 2013. Amounts applicable to income taxes due from and due to customers primarily represent differences between the book and tax basis of net utility plant in service. We amortize investment tax credits as reductions to income tax expense over the estimated service lives of the related properties. Refer to Note 9—Income Taxes which provides detailed financial information related to our income taxes.

STOCK-BASED COMPENSATION

We account for stock-based compensation expense in accordance with ASC Topic 718, Compensation—Stock Compensation, which requires us to measure and recognize stock-based compensation expense in our financial statements based on the fair value at the date of grant for our equity-classified share-based awards, which include performance shares and stock options granted to certain employees and shares issued to directors. For liability-classified share-based awards, which include performance units, we recognize stock-based compensation expense based on their fair value at the end of each reporting period. For both equity-classified and liability-classified share-based awards, we estimate forfeitures over the requisite service period when recognizing compensation expense; these estimates are periodically adjusted to the extent to which actual forfeitures differ from such estimates. Refer to Note 11—Stock-Based Compensation for further discussion of the accounting for our stock-based compensation plans.

ASSET RETIREMENT OBLIGATIONS

Washington Gas accounts for its AROs in accordance with ASC Subtopic 410-20, Asset Retirement and Environmental Obligations—AssetRetirement Obligations. Our asset retirement obligations include the costs to cut, purge and cap distribution system, remove asbestos and plug storage wells upon their retirement. These standards require recording the estimated retirement cost over the life of the related asset by depreciating the present value of the retirement obligation, measured at the time of the asset's acquisition, and accreting the liability until it is settled. There are timing differences between the ARO-related accretion and depreciation amounts being recorded pursuant to GAAP and the recognition of depreciation expense for legal asset removal costs that we are currently recovering in rates. These timing differences are recorded as a reduction to “Regulatory liabilities—Accrued asset removal costs” in accordance with ASC Topic 980. We do not have any assets that are legally restricted related to the settlement of asset retirement obligations.

WGL Holdings, Inc.
Changes in Asset Retirement Obligations
		September 30,
(In millions)		2014		2013
Asset retirement obligations at beginning of year	$	104.0	$	72.7
Liabilities incurred in the period		4.9		1.2
Liabilities settled in the period		(5.2)		(1.0)
Accretion expense		4.4		3.3
Revisions in estimated cash flows(a)		73.1		27.8
Asset retirement obligations at the end of the year(b)	$	181.2	$	104.0
Washington Gas Light Company
Changes in Asset Retirement Obligations
		September 30,
(In millions)		2014		2013
Asset retirement obligations at beginning of year	$	102.7	$	71.5
Liabilities incurred in the period		4.9		1.1
Liabilities settled in the period		(5.2)		(1.0)
Accretion expense		4.3		3.3
Revisions in estimated cash flows(a)		73.1		27.8
Asset retirement obligations at the end of the year(b)	$	179.8	$	102.7
(a) WGL revised its assumptions regarding the timing and amounts related to its obligation to cut, cap and purge pipeline. The revision is primarily driven by our accelerated pipeline replacement programs.
(b) Includes short-term asset retirement obligations of $6.0 million and $2.7 million for fiscal year 2014 and 2013, respectively.

ACCOUNTING STANDARDS ADOPTED IN FISCAL YEAR 2014

Standard

Description

Date of adoption

Effect on the financial statements or other significant matters

ASU 2011-11, Disclosures about Offsetting Assets and Liabilities (Topic 210)

The standard amends the existing disclosure requirements on offsetting by requiring enhanced disclosures about financial instruments and derivative instruments that are either: (i) offset in accordance with existing guidance or (ii) subject to an enforceable master netting arrangement or similar agreement, irrespective of whether they are offset on the balance sheet

October 1, 2013

As a result of the standards, additional disclosures regarding master netting arrangements were added to Note 14 - Derivative and Weather-Related Instruments. The adoption of these standards did not otherwise affect our financial statements.

ASU 2013-01, Clarifying the Scope of the Disclosures about Offsetting Assets and Liabilities (Topic 210)

The standard limits the scope of the required disclosures to derivatives, repurchase agreements and securities borrowing and securities lending transactions. The disclosures are required irrespective of whether the transactions are offset in the statement of financial position.

ASU 2013-02, Comprehensive Income (Topic 220): Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income

The standard requires entities to (i) present information about reclassificationadjustments from accumulated other comprehensive income (AOCI) to net income in their entirety – the effect on the reclassification on eachaffected net income line item and (ii) for AOCI reclassification items that are not reclassified in their entirety into net income – a cross-referenceto other required US GAAP disclosures. The reclassification information may be presented in a single note or on the face of the financial statements.

October 1, 2013

We have presented information about reclassification adjustments out of accumulated other comprehensive income in a footnote to the financial statements. Refer to Note 19 – Changes in Accumulated Other Comprehensive Income for the details of this disclosure. The adoption of this standard did not otherwise affect our financial statements.

OTHER NEWLY ISSUED ACCOUNTING STANDARDS

Effect on the financial statements or other significant matters

ASU 2013-11, Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists (Topic 740)

The standard amends the existing disclosure requirement byrequiring an unrecognized tax benefit, or a portion of an unrecognized tax benefit to be presented in the financial statements as a reduction to adeferred tax asset in most circumstances.

October 1, 2014

Wedo not expect the adoption of this standard to have a material effect on our financial statements.

ASU 2014-09, Revenue from Contracts with Customers (Topic 606)

The standard establishes a comprehensive revenue recognition model clarifying the method used to determine the timing and requirements for revenue recognition from contracts with customers. The disclosure requirements under the new standard will enable users of financial statements to understand the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers.

October 1, 2017

We are in the process of evaluating the impact the adoption of this standard will have on our financial statements.

ASU 2014-10, Development Stage Entities (Topic 915)

The standard amends the existing disclosure requirement by eliminating certain disclosure requirements relating to those entities. The update also removes certain guidance on evaluating whether a development stage entity has sufficient equity at risk as a criteria used in determining whether an entity is a variable interest entity.

October 1, 2016

We do not expect the adoption of this standard to have a material effect on our financial statements.

ASU 2014-15, Presentation of Financial Statements - Going Concern (Topic 205)

The standard amends the existing disclosure requirement providing guidance about management's responsibility to evaluate whether there is substantial doubt about the entity's ability to continue as a going concern and to provide related footnote disclosures. The new guidance requires that management perform a going concern analysis as of the date that the financial statements are issued and for the analysis to cover the year following the issuance date.

October 1, 2017

We do not expect adoption of this standard to have a material effect on our financial statements.

Standard

Description

Date of adoption

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Regulated Operations

12 Months Ended

Sep. 30, 2014

Regulated Operations [Abstract]

Public Utilities Disclosure

Washington Gas accounts for its regulated operations in accordance with ASC Topic 980. This standard includes accounting principles for companies whose rates are determined by independent third party regulators. When setting rates, regulators may require us to record expense in different periods than may be appropriate for unregulated enterprises. When this occurs, Washington Gas defers the associated costs as assets (regulatory assets) on its balance sheet and records them as expenses on its income statement as it collects the revenues designed to recover these costs through customers' rates. Further, regulators can also impose liabilities upon a company for amounts previously collected from customers and for future outflows that are expected to be incurred in the future (regulatory liabilities).

At September 30, 2014 and 2013, we recorded the following regulatory assets and liabilities on our balance sheets. These assets and liabilities will be recognized as expenses or revenues in future periods as they are reflected in customers' rates.

Regulatory Assets and Liabilities
		Regulatory				Regulatory
(In millions)		Assets				Liabilities
September 30,		2014		2013		2014		2013
Current:
Gas costs due from/to customers(a)	$	-	$	-	$	16.2	$	23.4
Interruptible sharing(a)		3.4		10.7		-		1.9
Revenue normalization mechanisms for Maryland and Virginia(a)		-		0.1		5.5		1.5
Plant recovery mechanisms		0.4		-		0.9		0.2
Total current	$	3.8	$	10.8	$	22.6	$	27.0
Deferred:
Accrued asset removal costs	$	-	$	-	$	327.4	$	321.3
Deferred gas costs(a)		191.3		94.0		-		-
Pension and other post-retirement benefits
Other post-retirement benefit costs—trackers(b)		-		0.7		-		-
Deferred pension costs/income—trackers(b)		45.1		51.0		-		-
ASC Topic 715 unrecognized costs/income(a)(c)
Pensions		147.9		155.1		-		-
Other post-retirement benefits		-		33.8		86.4		-
Total pension and other post-retirement benefits		193.0		240.6		86.4		-
Other
Income tax-related amounts due from/to customers(d)		30.4		24.9		4.8		4.5
Losses/gains on issuance and extinguishments of
debt and interest-rate derivative instruments(a)(e)		12.0		11.6		1.7		0.6
Deferred gain on sale of assets(a)		-		-		1.4		1.7
Rights-of-way fees(a)		1.5		-		-		1.6
Other costs—Business process outsourcing (a)		1.0		1.4		-		-
Nonretirement postemployment benefits(a)(f)		16.3		15.4		-		-
Deferred integrity management expenditures(a)(g)		2.7		-		-		-
Recoverable portion of abandoned LNG facility(a)		5.6		7.9		-		-
Other regulatory expenses(a)		2.1		4.8		9.7		5.1
Total other	$	71.6	$	66.0	$	17.6	$	13.5
Total deferred	$	455.9	$	400.6	$	431.4	$	334.8
Total	$	459.7	$	411.4	$	454.0	$	361.8
(a) Washington Gas does not earn its overall rate of return on these assets. Washington Gas is allowed to recover and required to pay, using short-term interest rates, the carrying costs related to billed gas costs due from and to its customers in the District of Columbia and Virginia jurisdictions.
(b) Relates to the District of Columbia jurisdiction.
(c) Refer to Note 10-Pension and Other Post-Retirement Benefit Plans for a further discussion of these amounts.
(d) This balance represents amounts due from customers for deferred tax liabilities related to tax benefits on deduction flowed directly to customers prior to the adoption of income tax normalization for ratemaking purposes.
(e) The losses or gains on the issuance and extinguishment of debt and interest-rate derivative instruments include unamortized balances from transactions executed in prior fiscal years. These transactions create gains and losses that are amortized over the remaining life of the debt as prescribed by regulatory accounting requirements.
(f) Represents the timing difference between the recognition of workers compensation and short-term disability costs in accordance with generally accepted accounting principles and the way these costs are recovered through rates.
(g)This balance represents amounts for deferred expenditures associated with Washington Gas' Distribution Integrity Management Program (DIMP) in Virginia.

As required by ASC Topic 980, Washington Gas monitors its regulatory and competitive environment to determine whether the recovery of its regulatory assets remains probable. If Washington Gas were to determine that recovery of these assets is no longer probable, it would write off the assets against earnings. We have determined that ASC Topic 980 continues to apply to our regulated operations, and the recovery of our regulatory assets at September 30, 2014 is probable. Refer to Note 13—Commitments and Contingencies for further discussion of our regulated operations.

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Short-Term Debt

12 Months Ended

Sep. 30, 2014

Short-Term Debt [Abstract]

Short-Term Debt

NOTE 4. SHORT-TERM DEBT

WGL and Washington Gas satisfy their short-term financing requirements through the sale of commercial paper or through bank borrowings. Due to the seasonal nature of the regulated utility and retail energy-marketing segments, short-term financing requirements can vary significantly during the year. Revolving credit agreements are maintained to support outstanding commercial paper and to permit short-term borrowing flexibility. WGL's policy is to maintain bank credit facilities in amounts equal to or greater than the expected maximum commercial paper position. The following is a summary of committed credit available at September 30, 2014 and 2013.

Committed Credit Available (In millions)
September 30, 2014	WGL Holdings, Inc.(b)		Washington Gas		Total Consolidated
Committed credit agreements
Unsecured revolving credit facility, expires April 3, 2017(a)	$	450.0	$	350.0	$	800.0
Less: Commercial Paper		(364.5)		(89.0)		(453.5)
Net committed credit available	$	85.5	$	261.0	$	346.5
Weighted average interest rate		0.20%		0.13%		0.19%
September 30, 2013
Committed credit agreements
Unsecured revolving credit facility, expires April 3, 2017(a)	$	450.0	$	350.0	$	800.0
Less: Commercial Paper		(248.6)		(124.5)		(373.1)
Net committed credit available	$	201.4	$	225.5	$	426.9
Weighted average interest rate		0.21%		0.13%		0.19%
(a)Both WGL and Washington Gas have the right to request extensions with the banks’ approval. WGL’s revolving credit facility permits it to borrow an additional $100 million, with the banks’ approval, for a total of $550 million. Washington Gas’ revolving credit facility permits it to borrow an additional $100 million, with the banks’ approval, for a total of $450 million.
(b)WGL Holdings includes all subsidiaries other than Washington Gas Light Company.

At September 30, 2014 and 2013,there were no outstanding bank loans from WGL's or Washington Gas'revolving credit facilities.

Under the terms of the credit agreements, the ratio of consolidated financial indebtedness to consolidated total capitalization may not exceed0.65to 1.0(65%). In addition, WGL and Washington Gas are required to inform lenders of changes in corporate existence, financial conditions, litigation and environmental warranties that might have a material adverse effect. Failure to inform the lenders' agent of these material changes might constitute default under the agreements. Another potential default may be deemed if WGL or Washington Gasfail to pay principal or interest whendue on any other indebtedness. Such defaults, if not remedied, could lead to suspension of further loans and/or acceleration in which obligations become immediately due and payable. At September 30, 2014, WGL and Washington Gas were in compliance with all of the covenants under their revolving credit facilities.

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Common Stock (Details)	Sep. 30, 2014		Sep. 30, 2013
Common Stock Details Narrative [Abstract]
Common Stock, Shares, Outstanding	50,656,553		51,774,204
Common Stock, Number of Shares, Par Value and Other Disclosures [Abstract]
Omnibus Incentive Compensation Plan	999,443	[1]
Dividend Reinvestment and Common Stock Purchase Plan	2,849,012
Employee Savings Plans	637,196
Directors' Stock Compensation Plan	96,650
Total Common Stock Reserves Shares	4,582,301
Footnote Details [Abstract]
Incentive Compensation Plan Stock Options	5,318
Performance Shares	301,378

[1] In March 2007, WGL adopted a shareholder-approved Omnibus Incentive Compensation Plan to replace on a prospective basis the 1999 Incentive Compensation Plan. Included are shares that may be issued which would reduce the number of shares authorized under the Omnibus Incentive Compensation Plan. These shares include 301,378 shares dedicated to performance shares granted but not vested and include 5,318 shares dedicated to stock options issued but not exercised. Refer to Note 11 - Stock-Based Compensation for a discussion regarding our stock-based compensation plans.

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Stock Based Compensation (Table 1) (Details) (USD $)	12 Months Ended
	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2012
Performances Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Non-vested and outstanding, beginning of year	295,973	[1]
Granted	109,076	[1]
Vested	(84,849)	[1]
Cancelled/Forfeited	(18,822)	[1]
Non-vested and outstanding, end of year	301,378	[1]	295,973	[1]
Weighted-average grant date fair value, non-vested and outstanding, beginning of year	$ 39.88
Weighted-average grant date fair value, granted	$ 42.88		$ 39.73		$ 38.99
Weighted-average grant date fair value, vested	$ 41.14
Weighted-average grant date fair value, cancelled/forfeited	$ 40.47
Weighted-average grant date fair value, non-vested and outstanding, end of year	$ 40.57		$ 39.88
Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Non-vested and outstanding, beginning of year	11,582,556
Granted	4,658,648
Vested	(3,205,636)
Cancelled/Forfeited	(766,647)
Non-vested and outstanding, end of year	12,268,921

[1] The number of common shares issued related to performance shares may range from zero to 200 percent of the number of shares shown in the table above based on our achievement of performance goals for total shareholder return relative to a selected peer group of companies.

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Earnings Per Share (Details) (WGL Holdings, Inc., USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended								12 Months Ended
	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
WGL Holdings, Inc.
Earnings Per Share Disclosure [Line Items]
NET INCOME (LOSS) APPLICABLE TO COMMON STOCK	$ 38,038	$ (11,940)	$ 61,213	$ 18,629	$ (51,625)	$ (10,015)	$ 89,505	$ 52,388	$ 105,940	$ 80,253	$ 139,818
Average common shares outstanding-basic									51,759,000	51,697,000	51,522,000
Basic	$ 0.74	$ (0.23)	$ 1.18	$ 0.36	$ (1.00)	$ (0.19)	$ 1.73	$ 1.01	$ 2.05	$ 1.55	$ 2.71
Stock-based compensation plan									11	111	67
Total average common shares outstanding diluted									51,770,000	51,808,000	51,589,000
Diluted EPS	$ 0.74	$ (0.23)	$ 1.18	$ 0.36	$ (1.00)	$ (0.19)	$ 1.73	$ 1.01	$ 2.05	$ 1.55	$ 2.71

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Operating Segment Reporting (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended										12 Months Ended
	Sep. 30, 2014		Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013		Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2012
Regulated Operation [Member]
Segment Reporting Information [Line Items]
Operating Revenues											$ 1,443,800	[1]	$ 1,200,357	[1]	$ 1,137,666	[1]
Operating Expenses:
Cost of energy-related sales											726,879		521,508		421,539
Operation											234,391		243,341		227,362
Maintenance											56,972		49,269		52,494
Depreciation and amortization											104,064		100,438		94,998
Revenue taxes											84,287		81,422		74,244
Other											53,402		52,271		50,822
Total Operating Expenses											1,259,995		1,048,249		921,459
Operating Income (Loss), Total											183,805		152,108		216,207
Equity in earnings of unconsolidated affiliates											0		0		0
Other Income (Expense) - Net											863		1,539		3,085
Interest Expense											37,127		35,631		36,098
Dividends on Washington Gas Light Company preferred stock											1,320		1,320		1,320
INCOME TAX EXPENSE (BENEFIT)											48,181		44,883		72,178
NET INCOME (LOSS) APPLICABLE TO COMMON STOCK											98,040		71,813		109,696
Segment Reporting Information Additional Elements For Bank Presentation [Abstract]
Total Assets	3,979,522					3,486,296					3,979,522		3,486,296		3,516,046
Capital Expenditures	286,323					227,948					286,323		227,948		208,225
Equity Method Investments	0					0					0		0		0
Retail Energy Marketing [Member] | Unregulated Operation [Member]
Segment Reporting Information [Line Items]
Operating Revenues											1,310,279	[1]	1,279,364	[1]	1,267,070	[1]
Operating Expenses:
Cost of energy-related sales											1,238,970		1,164,831		1,139,162
Operation											43,750		49,574		52,161
Maintenance											0		0		0
Depreciation and amortization											756		726		735
Revenue taxes											8,276		6,831		5,776
Other											4,615		4,411		4,070
Total Operating Expenses											1,296,367		1,226,373		1,201,904
Operating Income (Loss), Total											13,912		52,991		65,166
Equity in earnings of unconsolidated affiliates											1		0		0
Other Income (Expense) - Net											103		273		42
Interest Expense											10		13		1
Dividends on Washington Gas Light Company preferred stock											0		0		0
INCOME TAX EXPENSE (BENEFIT)											5,764		20,227		25,876
NET INCOME (LOSS) APPLICABLE TO COMMON STOCK											8,242		33,024		39,331
Segment Reporting Information Additional Elements For Bank Presentation [Abstract]
Total Assets	389,700					403,082					389,700		403,082		361,801
Capital Expenditures	76					730					76		730		984
Equity Method Investments	0					0					0		0		0
Commercial Energy Systems [Member] | Unregulated Operation [Member]
Segment Reporting Information [Line Items]
Operating Revenues											40,679	[1]	35,217	[1]	60,325	[1]
Operating Expenses:
Cost of energy-related sales											20,348		24,450		51,149
Operation											10,419		6,875		5,414
Maintenance											0		0		0
Depreciation and amortization											6,178		2,411		1,261
Revenue taxes											5		7		8
Other											253		303		280
Total Operating Expenses											37,203		34,046		58,112
Operating Income (Loss), Total											3,476		1,171		2,213
Equity in earnings of unconsolidated affiliates											1,953		1,070		947
Other Income (Expense) - Net											1,007		778		(32)
Interest Expense											0		234		1
Dividends on Washington Gas Light Company preferred stock											0		0		0
INCOME TAX EXPENSE (BENEFIT)											1,019		(206)		760
NET INCOME (LOSS) APPLICABLE TO COMMON STOCK											5,417		2,991		2,367
Segment Reporting Information Additional Elements For Bank Presentation [Abstract]
Total Assets	521,570					318,995					521,570		318,995		148,407
Capital Expenditures	108,363					83,667					108,363		83,667		41,818
Equity Method Investments	66,810					54,977					66,810		54,977		23,346
Mistream Energy Services [Member] | Unregulated Operation [Member]
Segment Reporting Information [Line Items]
Operating Revenues											16,555	[1]	(20,390)	[1]	(11,221)	[1]
Operating Expenses:
Cost of energy-related sales											0		0		0
Operation											8,517		8,683		2,860
Maintenance											0		0		0
Depreciation and amortization											124		124		116
Revenue taxes											0		0		0
Other											274		474		240
Total Operating Expenses											8,915		9,281		3,216
Operating Income (Loss), Total											7,640		(29,671)		(14,437)
Equity in earnings of unconsolidated affiliates											771		312		0
Other Income (Expense) - Net											(239)		0		0
Interest Expense											0		417		0
Dividends on Washington Gas Light Company preferred stock											0		0		0
INCOME TAX EXPENSE (BENEFIT)											1,969		(10,951)		(5,347)
NET INCOME (LOSS) APPLICABLE TO COMMON STOCK											6,203		(18,825)		(9,090)
Segment Reporting Information Additional Elements For Bank Presentation [Abstract]
Total Assets	211,824					231,368					211,824		231,368		169,456
Capital Expenditures	0					0					0		0		101
Equity Method Investments	28,076					6,507					28,076		6,507		0
Other Activities [Member] | Unregulated Operation [Member]
Segment Reporting Information [Line Items]
Operating Revenues											0	[1]	0	[1]	0	[1]
Operating Expenses:
Cost of energy-related sales											0		0		0
Operation											11,749		9,344		3,612
Maintenance											0		0		0
Depreciation and amortization											0		0		0
Revenue taxes											0		0		0
Other											84		97		16
Total Operating Expenses											11,833		9,441		3,628
Operating Income (Loss), Total											(11,833)		(9,441)		(3,628)
Equity in earnings of unconsolidated affiliates											469		128		293
Other Income (Expense) - Net											(198)		644		1,097
Interest Expense											601		402		366
Dividends on Washington Gas Light Company preferred stock											0		0		0
INCOME TAX EXPENSE (BENEFIT)											111		(1,124)		(118)
NET INCOME (LOSS) APPLICABLE TO COMMON STOCK											(12,274)		(7,947)		(2,486)
Segment Reporting Information Additional Elements For Bank Presentation [Abstract]
Total Assets	369,816					290,440					369,816		290,440		211,038
Capital Expenditures	0					0					0		0		0
Equity Method Investments	16					413					16		413		0
Corporate Elimination [Member]
Segment Reporting Information [Line Items]
Operating Revenues											(30,366)	[1],[2]	(28,410)	[1]	(28,530)	[1],[2]
Operating Expenses:
Cost of energy-related sales											(30,613)	[2]	(26,458)	[2]	(26,802)	[2]
Operation											75	[2]	(197)	[2]	(1,093)	[2]
Maintenance											0	[2]	0	[2]	0	[2]
Depreciation and amortization											(350)	[2]	(415)	[2]	(634)	[2]
Revenue taxes											0	[2]	0	[2]	0	[2]
Other											0	[2]	0	[2]	(1)	[2]
Total Operating Expenses											(30,888)	[2]	(27,070)	[2]	(28,530)	[2]
Operating Income (Loss), Total											522	[2]	(1,340)	[2]	0	[2]
Equity in earnings of unconsolidated affiliates											0	[2]	0	[2]	0	[2]
Other Income (Expense) - Net											0	[2]	(686)	[2]	(38)	[2]
Interest Expense											0	[2]	(686)	[2]	(38)	[2]
Dividends on Washington Gas Light Company preferred stock											0	[2]	0	[2]	0	[2]
INCOME TAX EXPENSE (BENEFIT)											210	[2]	(537)	[2]	0	[2]
NET INCOME (LOSS) APPLICABLE TO COMMON STOCK											312	[2]	(803)	[2]	0	[2]
Segment Reporting Information Additional Elements For Bank Presentation [Abstract]
Total Assets	(615,933)	[2]				(470,121)	[2]				(615,933)	[2]	(470,121)	[2]	(295,801)	[2]
Capital Expenditures	0	[2]				0	[2]				0	[2]	0	[2]	0	[2]
Equity Method Investments	0	[2]				0	[2]				0	[2]	0	[2]	0	[2]
WGL Holdings, Inc.
Segment Reporting Information [Line Items]
Operating Revenues	458,900		467,500	1,174,250	680,297	409,901		478,118	891,383	686,736	2,780,947	[1]	2,466,138	[1]	2,425,310	[1]
Operating Expenses:
Cost of energy-related sales											1,955,584		1,684,331		1,585,048
Operation											308,901		317,620		290,316
Maintenance											56,972		49,269		52,494
Depreciation and amortization											110,772		103,284		96,476
Revenue taxes											92,568		88,260		80,028
Other											58,628		57,556		55,427
Total Operating Expenses											2,583,425		2,300,320		2,159,789
Operating Income (Loss), Total	69,566		(9,489)	104,733	32,712	(75,270)		(9,111)	155,584	94,616	197,522		165,818		265,521
Equity in earnings of unconsolidated affiliates											3,194		1,510		1,240
Other Income (Expense) - Net											1,536		2,548		4,154
Interest Expense											37,738		36,011		36,428
Dividends on Washington Gas Light Company preferred stock											1,320		1,320		1,320
INCOME TAX EXPENSE (BENEFIT)											57,254		52,292		93,349
NET INCOME (LOSS) APPLICABLE TO COMMON STOCK	38,038		(11,940)	61,213	18,629	(51,625)		(10,015)	89,505	52,388	105,940		80,253		139,818
Segment Reporting Information Additional Elements For Bank Presentation [Abstract]
Total Assets	4,856,499					4,260,060					4,856,499		4,260,060		4,110,947
Capital Expenditures	394,762					312,345					394,762		312,345		251,128
Equity Method Investments	$ 94,902					$ 61,897					$ 94,902		$ 61,897		$ 23,346

[1] Operating revenues are reported gross of revenue taxes. Revenue taxes of both the regulated utility and the retail energy-marketing segments include gross receipt taxes. Revenue taxes of the regulated utility segment also include PSC fees, franchise fees and energy taxes. Operating revenue amounts in the "Eliminations" column represent total intersegment revenues associated with sales from the regulated utility segment to the retail energy-marketing segment. Midstream Energy Services' cost of energy related sales is netted with its gross revenues.

[2] Intersegment eliminations net income includes a timing difference between Commercial Energy Systems' recognition of revenue for the sale of Solar Renewable Energy Credits (SRECs) to Retail Energy-Marketing and Retail Energy's Marketing's recognition of the associate expense. Retail Energy-Marketing has recorded a portion of the SREC's purchased as inventory to be used in future periods at which time they will be expensed.

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Long Term Debt - Issuances and Retirements (Details) (USD $) In Millions, unless otherwise specified					12 Months Ended
	Sep. 30, 2014 Issuances [Member]	Sep. 30, 2013 Issuances [Member]	Sep. 30, 2014 Retirements [Member]	Sep. 30, 2013 Retirements [Member]	Sep. 30, 2014 November 7, 2013 Retirements [Member]	Sep. 30, 2014 September 10, 2014 Retirements [Member]	Sep. 30, 2014 December 5, 2013 Issuances [Member]		Sep. 30, 2014 September 12, 2014 Issuances [Member]
Issuance and Retirements [Line Items]
Principal	$ 175.0	$ 0	$ 67.0	$ 0	$ 37.0	$ 30.0	$ 75.0		$ 100.0
Nominal Maturity Date					Nov. 07, 2013	Sep. 10, 2014	Dec. 15, 2043		Sep. 15, 2044
Interest Rate					4.88%	5.17%	5.00%	[1]	4.22%	[2]
Footnote Details [Abstract]
Estimated Effective Interest Rate							4.95%		4.27%

[1] The estimated effective cost of the issued notes, including consideration of issuances fees and hedge costs, is 4.95%.

[2] The estimated effective cost of the issued notes, including consideration of issuances fees and hedge costs, is 4.27%.

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Derivative and Weather Related Instruments (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2012
Asset Optimization [Abstract]
Gain (Loss) on Asset Optimization Transactions Net Pretax	$ (35.4)		$ (33.2)		$ 28.3
Unrealized Gains (Loss) On Asset Optimization Derivative Instruments Net Pretax	(66.2)		(45.4)		15.9
Interest Rate Derivatives [Abstract]
Discussion Of Interest Rate Derivative Risk Management Policy	WGL utilizes derivative instruments that are designed to minimize the risk of interest-rate volatility associated with future debt issuances. During September 2014, WGL entered into interest rate swaps associated with an expected $150 million debt issuance. WGL elected cash flow hedge accounting for its interest rate derivative instruments.
Ineffective portion of cash flow hedge-net	0.2
WGEServices
Derivative, Collateral [Abstract]
Right to Reclaim Cash	5.7		12.1
Collateral Already Posted Aggregate Fair Value	5.3		3.6
WGL Midstream
Derivative, Collateral [Abstract]
Right to Reclaim Cash	11.4		8.1
WGL Holdings, Inc.
Absolute Notional Amounts of Open Positions on Derivative Instruments
Interest Rate Swap Notional Principal Value	150.0		75.0	[1]
Warrant Transaction Volume of Shares	4.6		4.6
Balance Sheet Classification of Derivative Instruments
Netting of Collateral	12.0		0.9
Total	(306.3)	[2]	(126.6)	[2]
WGL Holdings, Inc. | Derivative Instruments Designated as Hedging Instruments
Balance Sheet Classification of Derivative Instruments
Gross Derivative Assets	0		0
Gross Derivative Liabilities	(1.7)		0
WGL Holdings, Inc. | Derivative Instruments Not Designated as Hedging Instruments
Balance Sheet Classification of Derivative Instruments
Gross Derivative Assets	72.6		120.3
Gross Derivative Liabilities	(389.2)		(247.8)
WGL Holdings, Inc. | Current assets- derivatives
Balance Sheet Classification of Derivative Instruments
Netting of Collateral	0		(2.7)
Total	18.3	[2]	35.3	[2]
WGL Holdings, Inc. | Current assets- derivatives | Derivative Instruments Designated as Hedging Instruments
Balance Sheet Classification of Derivative Instruments
Gross Derivative Assets	0		0
Gross Derivative Liabilities	0		0
WGL Holdings, Inc. | Current assets- derivatives | Derivative Instruments Not Designated as Hedging Instruments
Balance Sheet Classification of Derivative Instruments
Gross Derivative Assets	20.8		57.3
Gross Derivative Liabilities	(2.5)		(19.3)
WGL Holdings, Inc. | Non current assets- derivatives
Balance Sheet Classification of Derivative Instruments
Netting of Collateral	0		0
Total	18.7	[2]	26.3	[2]
WGL Holdings, Inc. | Non current assets- derivatives | Derivative Instruments Designated as Hedging Instruments
Balance Sheet Classification of Derivative Instruments
Gross Derivative Assets	0		0
Gross Derivative Liabilities	0		0
WGL Holdings, Inc. | Non current assets- derivatives | Derivative Instruments Not Designated as Hedging Instruments
Balance Sheet Classification of Derivative Instruments
Gross Derivative Assets	18.7		57.4
Gross Derivative Liabilities	0		(31.1)
WGL Holdings, Inc. | Accounts Payable And OtherAccrued Liabilities [Member]
Balance Sheet Classification of Derivative Instruments
Netting of Collateral	0		0
Total	0	[2]	1.5	[2]
WGL Holdings, Inc. | Accounts Payable And OtherAccrued Liabilities [Member] | Derivative Instruments Designated as Hedging Instruments
Balance Sheet Classification of Derivative Instruments
Gross Derivative Assets	0		0
Gross Derivative Liabilities	0		0
WGL Holdings, Inc. | Accounts Payable And OtherAccrued Liabilities [Member] | Derivative Instruments Not Designated as Hedging Instruments
Balance Sheet Classification of Derivative Instruments
Gross Derivative Assets	0		1.5
Gross Derivative Liabilities	0		0
WGL Holdings, Inc. | Current liabilities- Derivatives
Balance Sheet Classification of Derivative Instruments
Netting of Collateral	8.0		0.9
Total	(48.6)	[2]	(48.4)	[2]
WGL Holdings, Inc. | Current liabilities- Derivatives | Derivative Instruments Designated as Hedging Instruments
Balance Sheet Classification of Derivative Instruments
Gross Derivative Assets	0		0
Gross Derivative Liabilities	(1.7)		0
WGL Holdings, Inc. | Current liabilities- Derivatives | Derivative Instruments Not Designated as Hedging Instruments
Balance Sheet Classification of Derivative Instruments
Gross Derivative Assets	15.4		4.1
Gross Derivative Liabilities	(70.3)		(53.4)
WGL Holdings, Inc. | Non current liabilities- derivatives
Balance Sheet Classification of Derivative Instruments
Netting of Collateral	4.0		2.7
Total	(294.7)	[2]	(141.3)	[2]
WGL Holdings, Inc. | Non current liabilities- derivatives | Derivative Instruments Designated as Hedging Instruments
Balance Sheet Classification of Derivative Instruments
Gross Derivative Assets	0		0
Gross Derivative Liabilities	0		0
WGL Holdings, Inc. | Non current liabilities- derivatives | Derivative Instruments Not Designated as Hedging Instruments
Balance Sheet Classification of Derivative Instruments
Gross Derivative Assets	17.7		0
Gross Derivative Liabilities	(316.4)		(144.0)
WGL Holdings, Inc. | Asset Optimization [Member]
Absolute Notional Amounts of Open Positions on Derivative Instruments
Natural Gas Derivative Transaction, Volume	20,593,300,000		13,289,600,000
WGL Holdings, Inc. | Retail Sales [Member]
Absolute Notional Amounts of Open Positions on Derivative Instruments
Natural Gas Derivative Transaction, Volume	44,700,000		98,900,000
Electricity Derivative Transaction, Volume	3,831,400,000		4,790,200,000
WGL Holdings, Inc. | Other Risk Management Activities [Member]
Absolute Notional Amounts of Open Positions on Derivative Instruments
Natural Gas Derivative Transaction, Volume	1,641,300,000		1,803,600,000
Electricity Derivative Transaction, Volume	16,734,100,000		17,647,900,000
Washington Gas Light Company
Derivative, Collateral [Abstract]
Right to Reclaim Cash	8.2		3.0
Derivative, Collateral, Obligation to Return Cash	2.5		4.6
Absolute Notional Amounts of Open Positions on Derivative Instruments
Interest Rate Swap Notional Principal Value	0		75.0	[1]
Warrant Transaction Volume of Shares	0		0
Balance Sheet Classification of Derivative Instruments
Gross Derivative Assets	26.2	[3]	68.0	[3]
Gross Derivative Liabilities	(308.4)	[3]	(175.7)	[3]
Netting of Collateral	0.9	[3]	(2.7)	[3]
Total	(281.3)	[2],[3]	(110.4)	[2],[3]
Washington Gas Light Company | Current assets- derivatives
Balance Sheet Classification of Derivative Instruments
Gross Derivative Assets	3.9	[3]	19.3	[3]
Gross Derivative Liabilities	0	[3]	(12.3)	[3]
Netting of Collateral	0	[3]	(2.7)	[3]
Total	3.9	[2],[3]	4.3	[2],[3]
Washington Gas Light Company | Non current assets- derivatives
Balance Sheet Classification of Derivative Instruments
Gross Derivative Assets	9.5	[3]	47.2	[3]
Gross Derivative Liabilities	0	[3]	(31.1)	[3]
Netting of Collateral	0	[3]	0	[3]
Total	9.5	[2],[3]	16.1	[2],[3]
Washington Gas Light Company | Current liabilities- Derivatives
Balance Sheet Classification of Derivative Instruments
Gross Derivative Assets	8.6	[3]	1.5	[3]
Gross Derivative Liabilities	(43.2)	[3]	(26.2)	[3]
Netting of Collateral	0.7	[3]	0	[3]
Total	(33.9)	[2],[3]	(24.7)	[2],[3]
Washington Gas Light Company | Non current liabilities- derivatives
Balance Sheet Classification of Derivative Instruments
Gross Derivative Assets	4.2	[3]	0	[3]
Gross Derivative Liabilities	(265.2)	[3]	(106.1)	[3]
Netting of Collateral	0.2	[3]	0	[3]
Total	$ (260.8)	[2],[3]	$ (106.1)	[2],[3]
Washington Gas Light Company | Asset Optimization [Member]
Absolute Notional Amounts of Open Positions on Derivative Instruments
Natural Gas Derivative Transaction, Volume	13,740,900,000		11,115,800,000
Washington Gas Light Company | Retail Sales [Member]
Absolute Notional Amounts of Open Positions on Derivative Instruments
Natural Gas Derivative Transaction, Volume	0		0
Electricity Derivative Transaction, Volume	0		0
Washington Gas Light Company | Other Risk Management Activities [Member]
Absolute Notional Amounts of Open Positions on Derivative Instruments
Natural Gas Derivative Transaction, Volume	1,398,200,000		1,455,700,000
Electricity Derivative Transaction, Volume	0		0

[1] The fair value of our interest rate swaps was minimal at September 30, 2013.

[2] WGL has elected to offset the fair value of recognized derivative instruments against the right to reclaim or the obligation to return collateral for derivative instruments executed under the same master netting arrangement in accordance with ASC 815. All recognized derivative contracts and associated financial collateral subject to a master netting arrangement or similar that is eligible for offset under ASC 815 have been presented net in the balance sheet.

[3] Washington Gas did not have any derivative instruments outstanding that were designated as hedging instruments at September 30, 2014, or 2013.

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Quarterly Financial Information

12 Months Ended

Sep. 30, 2014

Quarterly Financial Information Disclosure [Abstract]

Quarterly Financial Information [Text Block]

SUPPLEMENTARY FINANCIAL INFORMATION (Unaudited)

QUARTERLY FINANCIAL DATA

All adjustments necessary for a fair presentation have been included in the quarterly information provided below. Due to the seasonal nature of our business, we report substantial variations in operations on a quarterly basis.

##XSQuarter Ended
(In thousands, except per share data)	December 31			March 31		June 30	September 30
Fiscal Year 2014
WGL Holdings, Inc.
Operating revenues	$	680,297	$	1,174,250	$	467,500	$	458,900
Operating income (loss)	$	32,712	$	104,733	$	(9,489)	$	69,566
Net income (loss) applicable to common stock	$	18,629	$	61,213	$	(11,940)	$	38,038
Earnings (loss) per average share of common stock:
Basic	$	0.36	$	1.18	$	(0.23)	$	0.74
Diluted	$	0.36	$	1.18	$	(0.23)	$	0.74
Washington Gas Light Company
Operating revenues	$	390,415	$	716,808	$	197,752	$	138,825
Operating income	$	65,229	$	88,038	$	4,326	$	24,530
Net income (loss) applicable to common stock	$	38,477	$	49,176	$	(521)	$	9,872
Fiscal Year 2013
WGL Holdings, Inc.
Operating revenues	$	686,736	$	891,383	$	478,118	$	409,901
Operating income (loss)	$	94,616	$	155,584	$	(9,111)	$	(75,270)
Net income (loss) applicable to common stock	$	52,388	$	89,505	$	(10,015)	$	(51,625)
Earnings (loss) per average share of common stock:
Basic	$	1.01	$	1.73	$	(0.19)	$	(1.00)
Diluted	$	1.01	$	1.73	$	(0.19)	$	(1.00)
Washington Gas Light Company
Operating revenues	$	355,817	$	535,950	$	180,882	$	127,708
Operating income (loss)	$	72,037	$	134,358	$	(368)	$	(55,421)
Net income (loss) applicable to common stock	$	38,387	$	76,935	$	(4,531)	$	(39,789)

During the first quarter of fiscal year 2014, Washington Gas recorded an impairment charge of $0.8 million related to the Springfield Operations Center. During the third quarter of fiscal year 2014, Washington Gas recorded a $1.9 million impairment charge on a proposed LNG storage facility. During the fourth quarter of fiscal year 2013, Washington Gas recorded an impairment charge of $2.6 million related to the Springfield Operations Center and a $0.5 million impairment charge on a proposed LNG storage facility. Refer to Note 1 - Accounting Policiesof the Notes to Consolidated Financial Statements for further discussion of the impairments.

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Related Party Transactions (Tables)

12 Months Ended

Sep. 30, 2014

Related Party Transactions [Abstract]

Receivables and Payables from Associated Companies

Washington Gas Light Company
Receivables / Payables from Associated Companies
(In millions)	September 30, 2014		September 30, 2013
Receivables from Associated Companies	$	4.8	$	7.2
Payables to Associated Companies	$	54.7	$	20.6

Washington Gas - Gas Balancing Service Charges
		Years Ended September 30,
(In millions)		2014		2013		2012
Gas balancing service charge	$	26.6	$	25.0	$	26.8

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Income Taxes

12 Months Ended

Sep. 30, 2014

Income Tax Disclosure [Abstract]

Income Taxes

NOTE 9. INCOME TAXES

WGL files consolidated, federal, combined unitary including California, District of Columbia, West Virginia and various other state income tax returns. We are no longer subject to income tax examinations by the Internal Revenue Service (IRS) for years before September 30, 2011. Substantially all state income tax years in major jurisdictions are closed for years before September 30, 2010.

WGL and each of its subsidiaries also participate in a tax sharing agreement that establishes the method for allocating tax benefits from losses that are utilized on the consolidated income tax return. The consolidated tax is apportioned among the subsidiaries on the separate return method and losses of the parent, WGL, are allocated to the subsidiaries that have taxable income. In fiscal year 2014, Washington Gas shared $2.9 million of tax benefits from the tax sharing agreement that was reflected as a tax decrease on Washington Gas' statements of income. During fiscal years 2013 and 2012, Washington Gas realized $1.3 million and $0.3 million of tax savings as a result of this tax sharing agreement. The effect of this allocation of benefits to Washington Gas has no effect on our consolidated financial statements. State income tax returns are filed on a separate company basis in most states where we have operations and/or a requirement to file. Beginning with the fiscal year ended September 30, 2012, we filed a combined unitary return for California, District of Columbia and West Virginia due to recent law changes.

Washington Gas provides certain healthcare benefits for active and retired employees (the Plan). Washington Gas is self-insured for the majority of healthcare costs. Because the Plan provides prescription drug benefits equal to or greater than Medicare Part D (Med D) coverage, Washington Gas qualified for a non-taxable subsidy from the federal government, which has had the effect of lowering other post retirement employee benefit expense (OPEB) and Washington Gas' effective tax rate.

Since the year ended September 30, 2004, Washington Gas reflected the favorable tax benefit (“the Med D tax benefit”) of the non-taxable subsidy in its effective tax rate. The Patient Protection and Affordable Care Act and the Health Care and Education Reconciliation Act (collectively the “PPACA”) became law which eliminated future Med D tax benefits for Washington Gas' tax years beginning after September 30, 2013. During the fiscal year ended September 30, 2010, regulatory assets were increased by $42.2 million to reflect the probable recovery of the higher future tax expense from utility customers and an immaterial amount of tax expense was recorded related to the effect of the PPACA on our non-utility business. Based on positions taken by the SCC of VA in Washington Gas' rate case during the fiscal year ended September 30, 2011, we determined that it was not probable that the SCC of VA would permit recovery of this asset. Therefore, the Virginia portion of the regulatory asset related to the Med D benefit was charged to tax expense which resulted in an increase in the effective tax rate for the fiscal year ended September 30, 2011. Washington Gas charged the Maryland portion of the Med D regulatory asset to tax expense during the fiscal year ended September 30, 2012, based on positions taken by the PSC of MD in Washington Gas' rate case during the fiscal year that didn't permit recovery. Washington Gas received an order in the first quarter of the current fiscal year end September 30, 2014 in its recent rate case from the PSC of MD that will allow recovery of the Med D regulatory asset over a 5-year amortization period. Therefore the tax benefit has been recognized to reinstate the regulatory asset which results in a decrease in the effective rate for the fiscal year ended September 30, 2014. The Med D adjustments results in an effective tax rate at September 30, 2014 of 34.8%. The Med D adjustment results in an effective rate for Washington Gas at September 30, 2014 of 32.6%. In June 2013, the District of Columbia approved a 5-year amortization of the regulatory asset relating to Med D, which should have a minimal impact to the effective tax rate over the period allowed.

On September 13, 2013, the U.S. Treasury Department issued final income tax regulations to address the costs incurred in acquiring, producing, or improving tangible property. The regulations are effective for WGL and Washington Gas for the tax year beginning October 1, 2014. WGL and Washington Gas have assessed the financial impact of these regulations, and we do not expect the guidance to have a material impact on the financial statements. Any changes in method of accounting for income tax purposes required to conform to the final regulations will be made for the taxable year ending September 30, 2015.

The tables below provide the following for WGL and Washington Gas: (i) the components of income tax expense; (ii) a reconciliation between the statutory federal income tax rate and the effective income tax rate and (iii) the components of accumulated deferred income tax assets and liabilities at September 30, 2014 and 2013.

WGL Holdings, Inc.
Components of Income Tax Expense
	Years Ended September 30,
(In thousands)		2014		2013		2012
INCOME TAX EXPENSE
Current:
Federal	$	29,976	$	41,425	$	(13,188)
State		5,149		11,258		(30)
Total current		35,125		52,683		(13,218)
Deferred:
Federal
Accelerated depreciation		35,747		33,394		45,506
Other		(18,014)		(31,173)		44,727
State
Accelerated depreciation		9,822		6,795		9,412
Other		(1,760)		(7,585)		8,054
Total deferred		25,795		1,431		107,699
Amortization of investment tax credits		(3,666)		(1,822)		(1,132)
Total income tax expense	$	57,254	$	52,292	$	93,349

WGL Holdings, Inc.
Reconciliation Between the Statutory Federal Income Tax Rate and Effective Tax Rate
		Years Ended September 30,
($ In thousands)		2014				2013				2012
Income taxes at statutory federal income tax rate	$	57,580	35.00	%	$	46,853	35.00	%	$	82,070	35.00	%
Increase (decrease) in income taxes resulting from:
Accelerated depreciation less amount deferred		1,875	1.14			2,106	1.57			1,178	0.50
Amortization of investment tax credits		(3,666)	(2.23)			(1,822)	(1.36)			(1,132)	(0.48)
Cost of removal		(4,902)	(2.98)			(2,356)	(1.76)			(2,291)	(0.98)
State income taxes-net of federal benefit		8,734	5.31			7,448	5.56			12,068	5.15
Medicare Part D adjustment		(3,621)	(2.20)			-	-			2,827	1.21
Other items-net		1,254	0.76			63	0.05			(1,371)	(0.59)
Total income tax expense and effective tax rate	$	57,254	34.80	%	$	52,292	39.06	%	$	93,349	39.81	%

WGL Holdings, Inc.
Components of Deferred Income Tax Assets (Liabilities)
		September 30,
(In thousands)		2014				2013
ACCUMULATED DEFERRED INCOME TAXES	Current		Non-current		Current		Non-current
Deferred income tax assets:
Pensions	$	-	$	24,349	$	-	$	17,362
Other post-retirement benefits		-		-		-		18,510
Uncollectible accounts		9,268		-		8,127		-
Inventory overheads		6,591		-		6,431		-
Capital gains/losses-net		-		-		2		-
Valuation allowance		-		-		(2)		-
Employee compensation and benefits		6,306		37,873		5,876		37,301
Customer advances		-		197		-		197
Derivatives		6,503		31,555		-		7,872
Deferred gas costs		-		4,218		4,911		-
Solar grant/investment tax credit		-		39,184		-		17,415
Other		814		1,225		816		2,530
Total assets		29,482		138,601		26,161		101,187
Deferred income tax liabilities:
Other post-retirement benefits		-		38,299		-		-
Accelerated depreciation and other plant related items		-		669,040		-		596,754
Losses/gains on reacquired debt		-		1,426		-		1,567
Income taxes recoverable through future rates		-		65,374		-		112,222
Deferred gas costs		2,818		-		-		4,667
Derivatives		-		-		1,639		-
Partnership basis differences		-		25,370		-		15,784
Total liabilities		2,818		799,509		1,639		730,994
Net accumulated deferred income tax assets (liabilities)	$	26,664	$	(660,908)	$	24,522	$	(629,807)

Washington Gas Light Company
Components of Income Tax Expense
		Years Ended September 30,
(In thousands)		2014		2013		2012
INCOME TAX EXPENSE
Current:
Federal	$	37,098	$	40,492	$	(13,155)
State		4,262		7,515		(3,332)
Total current		41,360		48,007		(16,487)
Deferred:
Federal
Accelerated depreciation		34,833		34,518		45,661
Other		(30,523)		(35,982)		27,851
State
Accelerated depreciation		9,540		6,770		9,423
Other		(6,800)		(8,221)		6,197
Total deferred		7,050		(2,915)		89,132
Amortization of investment tax credits		(876)		(895)		(898)
Total income tax expense	$	47,534	$	44,197	$	71,747

Washington Gas Light Company
Reconciliation Between the Statutory Federal Income Tax Rate and Effective Tax Rate
		Years Ended September 30,
($ In thousands)		2014				2013				2012
Income taxes at statutory federal income tax rate	$	51,050	35.00	%	$	40,782	35.00	%	$	63,628	35.00	%
Increase (decrease) in income taxes resulting from:
Accelerated depreciation less amount deferred		1,875	1.29			2,106	1.81			1,178	0.65
Amortization of investment tax credits		(876)	(0.60)			(895)	(0.77)			(898)	(0.49)
Cost of removal		(4,902)	(3.36)			(2,356)	(2.02)			(2,291)	(1.26)
State income taxes-net of federal benefit		6,711	4.60			5,487	4.71			8,916	4.90
Consolidated tax sharing allocation		(2,862)	(1.96)			(1,290)	(1.11)			(309)	(0.17)
Medicare Part D adjustment		(3,621)	(2.48)			-	-			2,827	1.56
Other items-net		159	0.09			363	0.31			(1,304)	(0.72)
Total income tax expense and effective tax rate	$	47,534	32.58	%	$	44,197	37.93	%	$	71,747	39.47	%

Washington Gas Light Company
Components of Deferred Income Tax Assets (Liabilities)
		Years Ended September 30,
(In thousands)		2014				2013
ACCUMULATED DEFERRED INCOME TAXES	Current		Non-current		Current		Non-current
Deferred income tax assets:
Pensions	$	-	$	23,738	$	-	$	16,768
Other post-retirement benefits		-		-		-		18,474
Uncollectible accounts		7,618		-		6,948		-
Inventory overheads		6,591		-		6,431		-
Employee compensation and benefits		5,902		27,961		5,756		27,125
Customer advances		-		197		-		197
Derivatives		4,809		31,555		2,138		7,872
Deferred gas costs		-		4,218		4,911		-
Investment tax credit		-		312		-		312
Other		814		-		816		1,727
Total assets		25,734		87,981		27,000		72,475
Deferred income tax liabilities:
Other post-retirement benefits		-		38,065		-		-
Accelerated depreciation and other plant related items		-		602,376		-		565,996
Losses/gains on reacquired debt		-		1,426		-		1,567
Income taxes recoverable through future rates		-		65,128		-		111,698
Deferred gas costs		2,818		-		-		4,667
Other		-		932		-		-
Total liabilities		2,818		707,927		-		683,928
Net accumulated deferred income tax assets (liabilities)	$	22,916	$	(619,946)	$	27,000	$	(611,453)

In June 2014, we filed our tax return for the year ended September 30, 2013.

The following table summarizes the change in unrecognized tax benefits during fiscal year 2014, 2013, 2012 and our total unrecognized tax benefits at September 30, under the provisions of ASC Topic 740, Income Taxes:

Unrecognized Tax Benefits
(In thousands)		2014		2013		2012
Total unrecognized tax benefits, October 1,	$	25,051	$	22,082	$	20,699
Increases in tax positions relating to current year		10,512		5,251		3,396
Decreases in tax positions relating to prior year		(2,950)		(2,282)		(2,013)
Total unrecognized tax benefits, September 30,	$	32,613	$	25,051	$	22,082

During the year, the unrecognized tax benefits for WGL and Washington Gas increased by approximately $7.6 million relating to uncertain tax positions, primarily due to the change in tax accounting for repairs. If the amounts of unrecognized tax benefits are eventually realized, it would not materially impact the effective tax rate. It is reasonably possible that the amount of the unrecognized tax benefit with respect to some of WGL'sand Washington Gas'uncertain tax positions will increase or decrease in the next 12 months. The IRS completed its audit of the tax years related to the change in accounting method for repairs without proposing any changes, however, they could re-examine this issue in the future.

WGL and Washington Gas recognize any accrued interest associated with uncertain tax positions in interest expense and recognizes any accrued penalties associated with uncertain tax positions in other expenses in the statements of income. During the fiscal year ended September 30, 2014, we reversed minimal interest and during the fiscal year ended September 30, 2013 we accrued minimal interest expenses on uncertain tax positions. During the fiscal year ended September 30, 2012, we reversed $1.6 million for interest on uncertain tax positions.

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Derivative and Weather Related Instruments

12 Months Ended

Sep. 30, 2014

Derivative and Weather-Related Instruments [Abstract]

Derivative and Weather-Related Instruments

NOTE 14.DERIVATIVE AND WEATHER-RELATED INSTRUMENTS

DERIVATIVE INSTRUMENTS

Regulated Utility Operations

Washington Gas enters into contracts related to the sale and purchase of natural gas that qualify as derivative instruments and are accounted for under ASC Topic 815. These derivative instruments are recorded at fair value on our balance sheet and Washington Gas does not designate any derivatives as hedges under ASC Topic 815. Washington Gas' derivative instruments relate to: (i) Washington Gas' asset optimization program; (ii) managing price risk associated with the purchase of gas to serve utility customers and (iii) managing interest rate risk.

Asset Optimization. Washington Gas optimizes the value of its long-term natural gas transportation and storage capacity resources during periods when these resources are not being used to physically serve utility customers. Specifically, Washington Gas utilizes its transportation capacity assets to benefit from favorable natural gas prices between different geographic locations and its storage capacity assets to benefit from favorable natural gas prices between different time periods. As part of this asset optimization program, Washington Gas enters into physical and financial derivative transactions in the form of forward, futures and option contracts with the primary objective of locking in operating margins that Washington Gas will ultimately realize. The derivatives used under this program are subject to mark-to-market accounting treatment while the capacity and transportation resources are not.

Regulatory sharing mechanisms allow the profit from these transactions to be shared between Washington Gas' shareholders and customers; therefore, any changes in fair value are recorded through earnings, or as regulatory assets or liabilities to the extent that gains and losses associated with these derivative instruments will be included in the rates charged to customers when they are realized. Valuation changes for the portion of net profits to be retained for shareholders may cause significant period-to-period volatility in earnings from unrealized gains and losses. This volatility does not change the locked-in operating margins that Washington Gas expects to ultimately realize from these transactions through the use of its storage and transportation capacity resources.

All physically and financially settled contracts under our asset optimization program are reported on a net basis in the statements of income in “Utility cost of gas." Total net margins recorded to “Utility cost of gas” after sharing and management fees associated with all asset optimization transactions for the fiscal year ended September 30, 2014 was a netloss of $35.4 million including an unrealized loss of $66.2 million. During the fiscal year ended September 30, 2013 we recorded a net loss of $33.2 million including an unrealized loss of $45.4million. During the fiscal year ended September 30, 2012 we recorded a net gain of $28.3 million including an unrealized gain of $15.9 million.

Managing Price Risk. To manage price risk associated with acquiring natural gas supply for utility customers, Washington Gas enters into forward contracts, option contracts, financial contracts and other contracts, as authorized by its regulators. These instruments are accounted for as derivative instruments. Any gains and losses associated with these derivatives are recorded as regulatory liabilities or assets, respectively, to reflect the rate treatment for these economic hedging activities.

Managing Interest-Rate Risk. Washington Gas utilizes derivative instruments that are designed to minimize the risk of interest-rate volatility associated with planned issuances of debt securities. Any gains and losses associated with these types of derivatives are recorded as regulatory liabilities or assets, respectively, and amortized in accordance with regulatory requirements, typically over the life of the newly issued debt.

Non-Utility Operations

Managing Price Risk.WGEServices enters into certain derivative contracts as part of managing the price risk associated with the sale and purchase of natural gas and electricity. WGL Midstream enters into derivative contracts for the purpose of optimizing its storage and transportation capacity as well as managing the transportation and storage assets on behalf of third parties. As the storage and transportation capacities utilized by WGL Midstream are not considered to be derivative instruments, they are not recorded at fair value on our consolidated balance sheets. Washington Gas Resources has warrants to purchase stock from certain of its solar investments that are accounted for as derivative instruments. Derivative instruments are recorded at fair value on our consolidated balance sheets. WGEServices, WGL Midstream and Washington Gas Resources do not designate these derivatives as hedges under ASC Topic 815; therefore, changes in the fair value of these derivative instruments are reflected in the earnings of our non-utility operations and may cause significant period-to-period volatility in earnings.

Managing Interest-Rate Risk. WGL utilizes derivative instruments that are designed to minimize the risk of interest-rate volatility associated with future debt issuances. During September 2014, WGL entered into interest rate swaps associated with an expected $150 million debt issuance. WGL elected cash flow hedge accounting for its interest rate derivative instruments. Therefore, the effective portion of the gains and losses on the hedge are recorded within other comprehensive income and are expected to be amortized over the life of the debt (through 2044). The amount of ineffectiveness recorded to earnings for the period from the cash flow hedge was $0.2 million.

Consolidated Operations

Reflected in the tables below is information for WGL as well as Washington Gas. The information for WGL includes derivative instruments for both utility and non-utility operations.

At September 30, 2014 and 2013, respectively, the absolute notional amounts of our derivatives are as follows:

Absolute Notional Amounts
of Open Positions on Derivative Instruments
September 30, 2014	Notional Amounts
Derivative transactions	WGL Holdings		Washington Gas
Natural Gas (In millions of therms)
Asset Optimization		20,593.3		13,740.9
Retail sales		44.7		-
Other risk-management activities		1,641.3		1,398.2
Electricity (In millions of kWhs)
Retail sales		3,831.4		-
Other risk-management activities		16,734.1		-
Warrants (In millions of shares)		4.6		-
Interest Rate Swaps (In millions of dollars)		150.0		-

Absolute Notional Amounts
of Open Positions on Derivative Instruments
September 30, 2013		Notional Amounts
Derivative transactions	WGL Holdings		Washington Gas
Natural Gas (In millions of therms)
Asset Optimization		13,289.6		11,115.8
Retail sales		98.9		-
Other risk-management activities		1,803.6		1,455.7
Electricity (In millions of kWhs)
Retail sales		4,790.2		-
Other risk-management activities		17,647.9		-
Warrants (In millions of shares)		4.6		-
Interest Rate Swaps (In millions of dollars)(a)		75.0		75.0
(a)The fair value of our interest rate swaps was minimal at September 30, 2013.

As of September 30, 2014, the increase in volume of asset optimization related derivatives is primarily the result of new long-term gas purchasecontracts for WGL Midstream.

The following tables present the balance sheet classification for all derivative instruments as of September 30, 2014 and 2013.

WGL Holdings, Inc.
Balance Sheet Classification of Derivative Instruments
(In millions)	Derivative Instruments Not Designated as Hedging Instruments				Derivative Instruments Designated as Hedging Instruments
As of September 30, 2014	Gross Derivative Assets		Gross Derivative Liabilities		Gross Derivative Assets		Gross Derivative Liabilities		Netting of Collateral		Total(a)
Current Assets—Derivatives	$	20.8	$	(2.5)	$	-	$	-	$	-	$	18.3
Deferred Charges and Other Assets—Derivatives		18.7		-		-		-		-		18.7
Current Liabilities—Derivatives		15.4		(70.3)		-		(1.7)		8.0		(48.6)
Deferred Credits—Derivatives		17.7		(316.4)		-		-		4.0		(294.7)
Total	$	72.6	$	(389.2)	$	-	$	(1.7)	$	12.0	$	(306.3)
As of September 30, 2013
Current Assets—Derivatives	$	57.3	$	(19.3)	$	-	$	-	$	(2.7)	$	35.3
Deferred Charges and Other Assets—Derivatives		57.4		(31.1)		-		-		-		26.3
Accounts Payable and Other Accrued Liabilities		1.5		-		-		-		-		1.5
Current Liabilities—Derivatives		4.1		(53.4)		-		-		0.9		(48.4)
Deferred Credits—Derivatives		-		(144.0)		-		-		2.7		(141.3)
Total	$	120.3	$	(247.8)	$	-	$	-	$	0.9	$	(126.6)

Washington Gas Light Company
Balance Sheet Classification of Derivative Instruments(b)
(In millions)
As of September 30, 2014	Gross Derivative Assets		Gross Derivative Liabilities		Netting of Collateral		Total(a)
Current Assets—Derivatives	$	3.9	$	-	$	-	$	3.9
Deferred Charges and Other Assets—Derivatives		9.5		-		-		9.5
Current Liabilities—Derivatives		8.6		(43.2)		0.7		(33.9)
Deferred Credits—Derivatives		4.2		(265.2)		0.2		(260.8)
Total	$	26.2	$	(308.4)	$	0.9	$	(281.3)
As of September 30, 2013
Current Assets—Derivatives	$	19.3	$	(12.3)	$	(2.7)	$	4.3
Deferred Charges and Other Assets—Derivatives		47.2		(31.1)		-		16.1
Current Liabilities—Derivatives		1.5		(26.2)		-		(24.7)
Deferred Credits—Derivatives		-		(106.1)		-		(106.1)
Total	$	68.0	$	(175.7)	$	(2.7)	$	(110.4)
(a)WGL has elected to offset the fair value of recognized derivative instruments against the right to reclaim or the obligation to return collateral for derivative instruments executed under the same master netting arrangement in accordance with ASC 815. All recognized derivative contracts and associated financial collateral subject to a master netting arrangement or similar that is eligible for offset under ASC 815 have been presented net in the balance sheet.
(b)Washington Gas did not have any derivative instruments outstanding that were designated as hedging instruments at September 30, 2014, or 2013.

The following tables present all gains and losses associated with derivative instruments for the years ended September 30, 2014, 2013 and 2012.

WGL Holdings, Inc. Gains and Losses on Derivative Instruments
(In millions)
Fiscal Year Ended September 30,		2014		2013		2012
Recorded to income
Operating revenues—non-utility	$	(47.9)	$	(9.9)	$	19.2
Utility cost of gas		(87.3)		(45.9)		22.3
Non-utility cost of energy-related sales		36.2		(2.4)		(34.2)
Other income-net		(1.1)		0.2		0.9
Interest expense		(0.2)		-		-
Recorded to regulatory assets
Gas costs		(143.3)		(115.1)		42.2
Other		0.2		-		-
Recorded to other comprehensive income(a)		(1.5)		-		-
Total	$	(244.9)	$	(173.1)	$	50.4
(a)This pre-tax unrealized gain represents the effective portion of our cash flow hedge. Upon settlement of the hedge, the realized gain or loss, to the extent effective, will be amortized as an adjustment to the interest expense. We expect this amortization to be minimal for fiscal 2015.

Washington Gas Gains and Losses on Derivative Instruments
(In millions)
Fiscal Year Ended September 30,		2014		2013		2012
Recorded to income
Utility cost of gas	$	(87.3)	$	(45.9)	$	22.3
Recorded to regulatory assets
Gas costs		(143.3)		(115.1)		42.2
Other		0.2		-		-
Total	$	(230.4)	$	(161.0)	$	64.5

Collateral

WGL utilizes standardized master netting agreements, which facilitate the netting of cash flows into a single net exposure for a given counterparty. As part of these master netting agreements, cash, letters of credit and parental guarantees may be required to be posted or obtained from counterparties in order to mitigate credit risk related to both derivatives and non-derivative positions. Under WGL's offsetting policy, collateral balances are offset against the related counterparties' derivative positions to the extent the application would not result in the over-collateralization of those derivative positions on the balance sheet. At September 30, 2014, Washington Gas, WGEServices and WGL Midstream posted $8.2 million, $5.7 million and $11.4 million, respectively, of collateral deposits with counterparties that were not offset against open and settled derivative contracts. At September 30, 2013, Washington Gas, WGEServices and WGL Midstream posted $3.0 million, $12.1 million and $8.1 million, respectively, of collateral deposits with counterparties that were not offset against open and settled derivative contracts. In addition, at September 30, 2014 and 2013, Washington Gas held $2.5 million and $4.6 million of cash collateral, respectively, representing an obligation to counterparties that was not offset against open and settled derivative contracts. Any collateral posted that is not offset against open and settled derivative contracts is included in “Other prepayments” in the accompanying balance sheet. Collateral received and not offset against open and settled derivative contracts is included in “Customer deposits and advance payments” in the accompanying balance sheet.

Certain derivative instruments of Washington Gas, WGEServices and WGL Midstream contain contract provisions that require collateral to be posted if the credit rating of Washington Gas or WGL falls below certain levels or if counterparty exposure to WGEServices or WGL Midstream exceeds a certain level. Due to counterparty exposure levels, at September 30, 2014, WGEServicesposted $5.3million of collateral related to its derivative liabilities that contained credit-related contingent features. At September 30, 2013, WGEServices posted $3.6 million of collateral related to these aforementioned derivative liabilities. Washington Gas and WGL Midstream were not required to post any collateral related to its derivative liabilities that contained credit-related contingent features at September 30, 2014and 2013. The following table shows the aggregate fair value of all derivative instruments with credit-related contingent features that are in a liability position, as well as the maximum amount of collateral that would be required if the most intrusive credit-risk-related contingent features underlying these agreements were triggered on September 30, 2014 and 2013, respectively.

Potential Collateral Requirements for Derivative Liabilities
with Credit-risk-Contingent Features
(In millions)	WGL Holdings , Inc.		Washington Gas
September 30, 2014
Derivative liabilities with credit-risk-contingent features	$	28.8	$	20.6
Maximum potential collateral requirements		16.5		16.1
September 30, 2013
Derivative liabilities with credit-risk-contingent features	$	77.0	$	44.7
Maximum potential collateral requirements		33.6		1.7

Washington Gas, WGEServices and WGL Midstream do not enter into derivative contracts for speculative purposes.

Concentration of Credit Risk

We are exposed to credit risk from derivative instruments with wholesale counterpartieswhich is represented by the fair value of these instruments at the reporting date. We actively monitor and work to minimize counterparty concentration risk through various practices. At September 30, 2014, three counterparties each represented over 10% of Washington Gas' credit exposure to wholesale derivative counterparties for a total credit risk of $16.7 million; two counterparties represented over 10% of WGEServices'credit exposure to wholesale derivative counterparties for a total credit risk of $4.1 million; and three counterparties each represented over 10% of WGL Midstream's credit exposure to wholesale counterparties for a total credit risk of $13.6 million.

WEATHER-RELATED INSTRUMENTS

Washington Gas did not use any weather-related instruments during the year ended September 30, 2014. During the fiscal years ended September 30, 2013 and 2012, Washington Gas used HDD weather–related instruments to manage its financial exposure to variations from normal weather in the District of Columbia. Under these contracts, Washington Gas purchased protection against net revenue shortfalls due to warmer-than-normal weather and sold to its counterparty the right to receive the benefit when weather is colder than normal. Washington Gas electedto value all weather-related instruments at fair value.

Gains and losses associated with Washington Gas' weather-related instruments are recorded to “Operation and maintenance” expense. During the years ended September 30, 2013 and 2012, Washington Gas recorded a pre-tax net gain of $0.8 millionand $7.9 millionrespectively, related to weather derivatives.

WGEServices utilizes weather-related instruments for managing the financial effects of weather risks. These instruments cover a portion of WGEServices' estimated revenue or energy-related cost exposure to variations in heating or cooling degree days. These contracts provide for payment to WGEServices of a fixed-dollar amount for every degree day over or under specific levels during the calculation period depending upon the type of contract executed. Duringthe years ended September 30, 2014, 2013 and 2012,WGEServices recorded a pre-tax gain of $3.4 million,a pre-tax loss of $0.8 million and a pre-tax gain of $11.8 million,respectively, related to these instruments.

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Fair Value Measurements (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
WGL Holdings, Inc.
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	$ 72.6	$ 120.3
Liabilities	(390.9)	(247.8)
WGL Holdings, Inc. | Natural Gas Related Derivatives [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	56.4	93.8
Liabilities	(368.2)	(217.8)
WGL Holdings, Inc. | Electricity Related Derivatives [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	16.2	25.4
Liabilities	(21.0)	(30.0)
WGL Holdings, Inc. | Interest Rate Derivative
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	0	0
Liabilities	(1.7)	0
WGL Holdings, Inc. | Warrant
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	0	1.1
Liabilities	0	0
WGL Holdings, Inc. | Level 1 [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	0	0
Liabilities	0	0
WGL Holdings, Inc. | Level 1 [Member] | Natural Gas Related Derivatives [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	0	0
Liabilities	0	0
WGL Holdings, Inc. | Level 1 [Member] | Electricity Related Derivatives [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	0	0
Liabilities	0	0
WGL Holdings, Inc. | Level 1 [Member] | Interest Rate Derivative
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	0	0
Liabilities	0	0
WGL Holdings, Inc. | Level 1 [Member] | Warrant
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	0	0
Liabilities	0	0
WGL Holdings, Inc. | Level 2 [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	23.0	72.3
Liabilities	(41.6)	(48.1)
WGL Holdings, Inc. | Level 2 [Member] | Natural Gas Related Derivatives [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	22.7	72.3
Liabilities	(39.8)	(41.1)
WGL Holdings, Inc. | Level 2 [Member] | Electricity Related Derivatives [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	0.3	0
Liabilities	(0.1)	(7.0)
WGL Holdings, Inc. | Level 2 [Member] | Interest Rate Derivative
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	0	0
Liabilities	(1.7)	0
WGL Holdings, Inc. | Level 2 [Member] | Warrant
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	0	0
Liabilities	0	0
WGL Holdings, Inc. | Level 3 [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	49.6	48.0
Liabilities	(349.3)	(199.7)
WGL Holdings, Inc. | Level 3 [Member] | Natural Gas Related Derivatives [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	33.7	21.5
Liabilities	(328.4)	(176.7)
WGL Holdings, Inc. | Level 3 [Member] | Electricity Related Derivatives [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	15.9	25.4
Liabilities	(20.9)	(23.0)
WGL Holdings, Inc. | Level 3 [Member] | Interest Rate Derivative
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	0	0
Liabilities	0	0
WGL Holdings, Inc. | Level 3 [Member] | Warrant
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	0	1.1
Liabilities	0	0
Washington Gas Light Company
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	26.2	68.0
Liabilities	(308.4)	(175.7)
Washington Gas Light Company | Natural Gas Related Derivatives [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	26.2	68.0
Liabilities	(308.4)	(175.7)
Washington Gas Light Company | Level 1 [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	0	0
Liabilities	0	0
Washington Gas Light Company | Level 1 [Member] | Natural Gas Related Derivatives [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	0	0
Liabilities	0	0
Washington Gas Light Company | Level 2 [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	13.5	51.0
Liabilities	(25.1)	(25.1)
Washington Gas Light Company | Level 2 [Member] | Natural Gas Related Derivatives [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	13.5	51.0
Liabilities	(25.1)	(25.1)
Washington Gas Light Company | Level 3 [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	12.7	17.0
Liabilities	(283.3)	(150.6)
Washington Gas Light Company | Level 3 [Member] | Natural Gas Related Derivatives [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Abstract]
Assets	12.7	17.0
Liabilities	$ (283.3)	$ (150.6)

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Fair Value Measurements (Tables)

12 Months Ended

Sep. 30, 2014

Quantitative Information about Level 3 Fair Value Measurements

Quantitative Information about Level 3 Fair Value Measurements
(In millions)	Net Fair Value September 30, 2014	Valuation Techniques	Unobservable Inputs	Range
WGL Holdings, Inc.	(In millions)
Natural gas related derivatives	($294.7)	Discounted Cash Flow	Natural Gas Basis Price (per dekatherm)	($2.101) -	$6.154
		Option Model	Natural Gas Basis Price (per dekatherm)	($1.675) -	$6.154
			Annualized Volatility of Spot Market Natural Gas	30.9% -	589.6%
Electricity related derivatives	($5.0)	Discounted Cash Flow	Electricity Congestion Price (per megawatt hour)	($2.85) -	$90.95
		Internal Model	Electricity Congestion Price (per megawatt hour)
		Option Model	Electricity Congestion Price (per megawatt hour)
			Annualized Volatility of Electricity Prices
Washington Gas Light Company
Natural gas related derivatives	($270.6)	Discounted Cash Flow	Natural Gas Basis Price (per dekatherm)	($2.101) -	$6.154

Quantitative Information about Level 3 Fair Value Measurements
(In millions)	Net Fair Value September 30, 2013	Valuation Techniques	Unobservable Inputs	Range
WGL Holdings, Inc.	(In millions)
Natural gas related derivatives	($155.2)	Discounted Cash Flow	Natural Gas Basis Price (per dekatherm)	($1.780) -	$2.205
		Option Model	Natural Gas Basis Price (per dekatherm)	($0.181) -	$0.628
			Annualized Volatility of Spot Market Natural Gas	34.6% -	276.6%
Electricity related derivatives	$2.4	Discounted Cash Flow	Electricity Congestion Price (per megawatt hour)	($1.995) -	$64.150
Washington Gas Light Company
Natural gas related derivatives	($133.6)	Discounted Cash Flow	Natural Gas Basis Price (per dekatherm)	($1.780) -	$2.205
		Option Model	Natural Gas Basis Price (per dekatherm)	$0.024 -	$0.628
			Annualized Volatility of Spot Market Natural Gas	46.8% -	276.6%

WGL Holdings, Inc.

Fair Value Measurements Under the Fair Value Hierarchy

WGL Holdings, Inc.
Fair Value Measurements Under the Fair Value Hierarchy
(In millions)	Level 1		Level 2		Level 3		Total
At September 30, 2014
Assets
Natural gas related derivatives	$	-	$	22.7	$	33.7	$	56.4
Electricity related derivatives		-		0.3		15.9		16.2
Total Assets	$	-	$	23.0	$	49.6	$	72.6
Liabilities
Natural gas related derivatives	$	-	$	(39.8)	$	(328.4)	$	(368.2)
Electricity related derivatives		-		(0.1)		(20.9)		(21.0)
Interest rate derivatives		-		(1.7)		-		(1.7)
Total Liabilities	$	-	$	(41.6)	$	(349.3)	$	(390.9)

At September 30, 2013
Assets
Natural gas related derivatives	$	-	$	72.3	$	21.5	$	93.8
Electricity related derivatives		-		-		25.4		25.4
Warrants		-		-		1.1		1.1
Total Assets	$	-	$	72.3	$	48.0	$	120.3
Liabilities
Natural gas related derivatives	$	-	$	(41.1)	$	(176.7)	$	(217.8)
Electricity related derivatives		-		(7.0)		(23.0)		(30.0)
Total Liabilities	$	-	$	(48.1)	$	(199.7)	$	(247.8)

Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs

WGL Holdings, Inc. Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs
(In millions)		Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Fiscal Year Ended September 30, 2014
Balance at October 1, 2013	$	(155.2)	$	2.4	$	-	$	1.1	$	(151.7)
Realized and unrealized gains (losses)
Recorded to income		(72.6)		(5.7)		-		(1.1)		(79.4)
Recorded to regulatory assets - gas costs		(113.6)		-		-		-		(113.6)
Transfers out of Level 3		1.7		-		-		-		1.7
Purchases		-		5.2		-		-		5.2
Settlements		45.0		(6.9)		-		-		38.1
Balance at September 30, 2014	$	(294.7)	$	(5.0)	$	-	$	-	$	(299.7)

WGL Holdings, Inc. Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs
(In millions)		Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Fiscal Year Ended September 30, 2013
Balance at October 1, 2012	$	39.6	$	2.8	$	(0.5)	$	0.9	$	42.8
Realized and unrealized gains (losses)
Recorded to income		(72.4)		(23.8)		1.2		0.2		(94.8)
Recorded to regulatory assets - gas costs		(115.3)		-		-		-		(115.3)
Transfers out of Level 3		(17.4)		-		(0.7)		-		(18.1)
Purchases		-		5.7		-		-		5.7
Settlements		10.3		17.7		-		-		28.0
Balance at September 30, 2013	$	(155.2)	$	2.4	$	-	$	1.1	$	(151.7)

Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements

WGL Holdings, Inc. Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Fiscal Year Ended September 30, 2014
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Operating revenues—non-utility	$	(2.3)	$	(22.1)	$	-	$	-	$	(24.4)
Utility cost of gas		(69.4)		-		-		-		(69.4)
Other income-net		-		-		-		(1.1)		(1.1)
Non-utility cost of energy-related sales		(0.9)		16.4		-		-		15.5
Total	$	(72.6)	$	(5.7)	$	-	$	(1.1)	$	(79.4)

WGL Holdings, Inc. Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Fiscal Year Ended September 30, 2013
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Operating revenues—non-utility	$	(27.0)	$	(9.1)	$	-	$	-	$	(36.1)
Utility cost of gas		(45.8)		-		-		-		(45.8)
Other income-net		-		-		-		0.2		0.2
Non-utility cost of energy-related sales		0.4		(14.7)		-		-		(14.3)
Operation and maintenance expense		-		-		1.2		-		1.2
Total	$	(72.4)	$	(23.8)	$	1.2	$	0.2	$	(94.8)

WGL Holdings, Inc. Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Fiscal Year Ended September 30, 2012
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Operating revenues—non-utility	$	3.0	$	(14.2)	$	-	$	-	$	(11.2)
Utility cost of gas		14.3		-		-		-		14.3
Other income-net		-		-		-		0.9		0.9
Non-utility cost of energy-related sales		4.8		(33.5)		-		-		(28.7)
Operation and maintenance expense		-		-		7.9		-		7.9
Total	$	22.1	$	(47.7)	$	7.9	$	0.9	$	(16.8)

Unrealized Gains (Losses) Recorded for Level 3 Measurements

WGL Holdings, Inc. Unrealized Gains (Losses) Recorded for Level 3 Measurements
Fiscal Year Ended September 30, 2014
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Recorded to income
Operating revenues—non-utility	$	(5.0)	$	(33.8)	$	-	$	-	$	(38.8)
Utility cost of gas		(60.6)		-		-		-		(60.6)
Non-utility cost of energy-related sales		3.7		30.0		-		-		33.7
Other income-net		-		-		-		(1.1)		(1.1)
Recorded to regulatory assets—gas costs		(109.9)		-		-		-		(109.9)
Total	$	(171.8)	$	(3.8)	$	-	$	(1.1)	$	(176.7)

WGL Holdings, Inc. Unrealized Gains (Losses) Recorded for Level 3 Measurements
Fiscal Year Ended September 30, 2013
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Recorded to income
Operating revenues—non-utility	$	(25.3)	$	6.6	$	-	$	-	$	(18.7)
Utility cost of gas		(44.3)		-		-		-		(44.3)
Non-utility cost of energy-related sales		0.2		(1.1)		-		-		(0.9)
Other income-net		-		-		-		0.2		0.2
Recorded to regulatory assets—gas costs		(111.6)		-		-		-		(111.6)
Total	$	(181.0)	$	5.5	$	-	$	0.2	$	(175.3)

WGL Holdings, Inc. Unrealized Gains (Losses) Recorded for Level 3 Measurements
Fiscal Year Ended September 30, 2012
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Derivatives		Warrants		Total
Recorded to income
Operating revenues—non-utility	$	4.3	$	4.8	$	-	$	-	$	9.1
Utility cost of gas		13.8		-		-		-		13.8
Non-utility cost of energy-related sales		0.8		14.0		-		-		14.8
Other income-net		-		-		-		0.9		0.9
Operation and maintenance expense		-		-		0.2		-		0.2
Recorded to regulatory assets—gas costs		23.2		-		-		-		23.2
Total	$	42.1	$	18.8	$	0.2	$	0.9	$	62.0

Fair Value of Financial Instruments

WGL Holdings, Inc. Fair Value of Financial Instruments
At September 30,	2014				2013
(In millions)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
Money market funds (a)	$	9.7	$	9.7	$	6.5	$	6.5
Other short- term investments(a)	$	-	$	-	$	0.1	$	0.1
Commercial paper (b)	$	453.5	$	453.5	$	373.1	$	373.1
Long-term debt(c)	$	679.2	$	809.3	$	524.1	$	630.2

Washington Gas Light Company

Fair Value Measurements Under the Fair Value Hierarchy

Washington Gas Light Company
Fair Value Measurements Under the Fair Value Hierarchy
(In millions)	Level 1		Level 2		Level 3		Total
At September 30, 2014
Assets
Natural gas related derivatives	$	-	$	13.5	$	12.7	$	26.2
Total Assets	$	-	$	13.5	$	12.7	$	26.2
Liabilities
Natural gas related derivatives	$	-	$	(25.1)	$	(283.3)	$	(308.4)
Total Liabilities	$	-	$	(25.1)	$	(283.3)	$	(308.4)

At September 30, 2013
Assets
Natural gas related derivatives	$	-	$	51.0	$	17.0	$	68.0
Total Assets	$	-	$	51.0	$	17.0	$	68.0
Liabilities
Natural gas related derivatives	$	-	$	(25.1)	$	(150.6)	$	(175.7)
Total Liabilities	$	-	$	(25.1)	$	(150.6)	$	(175.7)

Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs

Washington Gas Light Company Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs
(In millions)		Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Fiscal Year Ended September 30, 2014
Balance at October 1, 2013	$	(133.6)	$	-	$	-	$	-	$	(133.6)
Realized and unrealized gains (losses)
Recorded to income		(69.4)		-		-		-		(69.4)
Recorded to regulatory assets - gas costs		(113.6)		-		-		-		(113.6)
Transfers out of Level 3		1.7		-		-		-		1.7
Settlements		44.3		-		-		-		44.3
Balance at September 30, 2014	$	(270.6)	$	-	$	-	$	-	$	(270.6)

Washington Gas Light Company Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs
(In millions)		Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Fiscal Year Ended September 30, 2013
Balance at October 1, 2012	$	35.6	$	-	$	(0.5)	$	-	$	35.1
Realized and unrealized gains (losses)
Recorded to income		(45.9)		-		1.2		-		(44.7)
Recorded to regulatory assets - gas costs		(115.3)		-		-		-		(115.3)
Transfers out of Level 3		(17.4)		-		(0.7)		-		(18.1)
Settlements		9.4		-		-		-		9.4
Balance at September 30, 2013	$	(133.6)	$	-	$	-	$	-	$	(133.6)

Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements

Washington Gas Light Company Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Fiscal Year Ended September 30, 2014
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Utility cost of gas	$	(69.4)	$	-	$	-	$	-	$	(69.4)
Total	$	(69.4)	$	-	$	-	$	-	$	(69.4)

Washington Gas Light Company Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Fiscal Year Ended September 30, 2013
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Utility cost of gas	$	(45.9)	$	-	$	-	$	-	$	(45.9)
Operation and maintenance expense		-		-		1.2		-		1.2
Total	$	(45.9)	$	-	$	1.2	$	-	$	(44.7)

Washington Gas Light Company Realized and Unrealized Gains (Losses) Recorded for Level 3 Measurements
Fiscal Year Ended September 30, 2012
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Utility cost of gas	$	14.3	$	-	$	-	$	-	$	14.3
Operation and maintenance expense		-		-		7.9		-		7.9
Total	$	14.3	$	-	$	7.9	$	-	$	22.2

Unrealized Gains (Losses) Recorded for Level 3 Measurements

Washington Gas Light Company Unrealized Gains (Losses) Recorded for Level 3 Measurements
Fiscal Year Ended September 30, 2014
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Recorded to income
Utility cost of gas	$	(60.6)	$	-	$	-	$	-	$	(60.6)
Recorded to regulatory assets—gas costs		(109.9)		-		-		-		(109.9)
Total	$	(170.5)	$	-	$	-	$	-	$	(170.5)

Washington Gas Light Company Unrealized Gains (Losses) Recorded for Level 3 Measurements
Fiscal Year Ended September 30, 2013
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Recorded to income
Utility cost of gas	$	(44.3)	$	-	$	-	$	-	$	(44.3)
Recorded to regulatory assets—gas costs		(111.6)		-		-		-		(111.6)
Total	$	(155.9)	$	-	$	-	$	-	$	(155.9)

Washington Gas Light Company Unrealized Gains (Losses) Recorded for Level 3 Measurements
Fiscal Years Ended September 30, 2012
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Recorded to income
Utility cost of gas	$	13.8	$	-	$	-	$	-	$	13.8
Operation and maintenance expense		-		-		0.2		-		0.2
Recorded to regulatory assets—gas costs		23.2		-		-		-		23.2
Total	$	37.0	$	-	$	0.2	$	-	$	37.2

Fair Value of Financial Instruments

Washington Gas Light Company Fair Value of Financial Instruments
At September 30,	2014				2013
(In millions)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
Money market funds (a)	$	4.3	$	4.3	$	3.1	$	3.1
Other short- term investments(a)	$	-	$	-	$	0.1	$	0.1
Commercial paper (b)	$	89.0	$	89.0	$	124.5	$	124.5
Long-term debt(c)	$	679.2	$	809.3	$	524.1	$	630.2
(a)Balance located in cash and cash equivalents in the accompanying balance sheets. These amounts may be offset by outstanding checks.
(b)Balance is located in notes payable in the accompanying balance sheets.
(c)Less current maturities and unamortized discounts.

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Other Investments - Location Table (Details) (USD $)	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
VIEs
ASSETS
Investments in unconsolidated affiliates	$ 72,600,000	$ 55,400,000
Investments in direct financing leases, capital leases	18,200,000	23,400,000
Deferred charges and other assets - derivatives	0	0
Net Investment in Direct Financing Lease, Current	1,700,000	5,800,000
Total assets	92,500,000	84,600,000
LIABILITIES
Other		8,500,000
Total liabilities		8,500,000
INCOME STATEMENT
Equity in earnings of unconsolidated affiliates	2,200,000	1,000,000
Depreciation and amortization	200,000	100,000
Other income - net	2,600,000	1,400,000
Net income	4,600,000	2,300,000
Non-VIEs
ASSETS
Investments in unconsolidated affiliates	27,900,000	12,100,000
Investments in direct financing leases, capital leases	0	0
Deferred charges and other assets - derivatives	0	1,100,000
Net Investment in Direct Financing Lease, Current	0	0
Total assets	27,900,000	13,200,000
LIABILITIES
Other		0
Total liabilities		0
INCOME STATEMENT
Equity in earnings of unconsolidated affiliates	1,000,000	500,000
Depreciation and amortization	0	0
Other income - net	0	0
Net income	1,000,000	500,000
Total
ASSETS
Investments in unconsolidated affiliates	100,500,000	67,500,000
Investments in direct financing leases, capital leases	18,200,000	23,400,000
Deferred charges and other assets - derivatives	0	1,100,000
Net Investment in Direct Financing Lease, Current	1,700,000	5,800,000
Total assets	120,400,000	97,800,000
LIABILITIES
Other		8,500,000
Total Liabilities		8,500,000
INCOME STATEMENT
Equity in earnings of unconsolidated affiliates	3,200,000	1,500,000
Depreciation and amortization	200,000	100,000
Other income - net	2,600,000	1,400,000
Net income	$ 5,600,000	$ 2,800,000

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Derivative and Weather Related Instruments (Tables)

12 Months Ended

Sep. 30, 2014

Absolute Notional Amounts of Open Positions on Derivative Instruments

Absolute Notional Amounts
of Open Positions on Derivative Instruments
September 30, 2014	Notional Amounts
Derivative transactions	WGL Holdings		Washington Gas
Natural Gas (In millions of therms)
Asset Optimization		20,593.3		13,740.9
Retail sales		44.7		-
Other risk-management activities		1,641.3		1,398.2
Electricity (In millions of kWhs)
Retail sales		3,831.4		-
Other risk-management activities		16,734.1		-
Warrants (In millions of shares)		4.6		-
Interest Rate Swaps (In millions of dollars)		150.0		-

Absolute Notional Amounts
of Open Positions on Derivative Instruments
September 30, 2013		Notional Amounts
Derivative transactions	WGL Holdings		Washington Gas
Natural Gas (In millions of therms)
Asset Optimization		13,289.6		11,115.8
Retail sales		98.9		-
Other risk-management activities		1,803.6		1,455.7
Electricity (In millions of kWhs)
Retail sales		4,790.2		-
Other risk-management activities		17,647.9		-
Warrants (In millions of shares)		4.6		-
Interest Rate Swaps (In millions of dollars)(a)		75.0		75.0
(a)The fair value of our interest rate swaps was minimal at September 30, 2013.

Potential Collateral Requirements for Derivative Liabilities with Credit-risk-Contingent Features

Potential Collateral Requirements for Derivative Liabilities
with Credit-risk-Contingent Features
(In millions)	WGL Holdings , Inc.		Washington Gas
September 30, 2014
Derivative liabilities with credit-risk-contingent features	$	28.8	$	20.6
Maximum potential collateral requirements		16.5		16.1
September 30, 2013
Derivative liabilities with credit-risk-contingent features	$	77.0	$	44.7
Maximum potential collateral requirements		33.6		1.7

WGL Holdings, Inc.

Balance Sheet Classification of Derivative Instruments

WGL Holdings, Inc.
Balance Sheet Classification of Derivative Instruments
(In millions)	Derivative Instruments Not Designated as Hedging Instruments				Derivative Instruments Designated as Hedging Instruments
As of September 30, 2014	Gross Derivative Assets		Gross Derivative Liabilities		Gross Derivative Assets		Gross Derivative Liabilities		Netting of Collateral		Total(a)
Current Assets—Derivatives	$	20.8	$	(2.5)	$	-	$	-	$	-	$	18.3
Deferred Charges and Other Assets—Derivatives		18.7		-		-		-		-		18.7
Current Liabilities—Derivatives		15.4		(70.3)		-		(1.7)		8.0		(48.6)
Deferred Credits—Derivatives		17.7		(316.4)		-		-		4.0		(294.7)
Total	$	72.6	$	(389.2)	$	-	$	(1.7)	$	12.0	$	(306.3)
As of September 30, 2013
Current Assets—Derivatives	$	57.3	$	(19.3)	$	-	$	-	$	(2.7)	$	35.3
Deferred Charges and Other Assets—Derivatives		57.4		(31.1)		-		-		-		26.3
Accounts Payable and Other Accrued Liabilities		1.5		-		-		-		-		1.5
Current Liabilities—Derivatives		4.1		(53.4)		-		-		0.9		(48.4)
Deferred Credits—Derivatives		-		(144.0)		-		-		2.7		(141.3)
Total	$	120.3	$	(247.8)	$	-	$	-	$	0.9	$	(126.6)

Gains and (Losses) on Derivative Instruments

WGL Holdings, Inc. Gains and Losses on Derivative Instruments
(In millions)
Fiscal Year Ended September 30,		2014		2013		2012
Recorded to income
Operating revenues—non-utility	$	(47.9)	$	(9.9)	$	19.2
Utility cost of gas		(87.3)		(45.9)		22.3
Non-utility cost of energy-related sales		36.2		(2.4)		(34.2)
Other income-net		(1.1)		0.2		0.9
Interest expense		(0.2)		-		-
Recorded to regulatory assets
Gas costs		(143.3)		(115.1)		42.2
Other		0.2		-		-
Recorded to other comprehensive income(a)		(1.5)		-		-
Total	$	(244.9)	$	(173.1)	$	50.4
(a)This pre-tax unrealized gain represents the effective portion of our cash flow hedge. Upon settlement of the hedge, the realized gain or loss, to the extent effective, will be amortized as an adjustment to the interest expense. We expect this amortization to be minimal for fiscal 2015.

Washington Gas Light Company

Balance Sheet Classification of Derivative Instruments

Washington Gas Light Company
Balance Sheet Classification of Derivative Instruments(b)
(In millions)
As of September 30, 2014	Gross Derivative Assets		Gross Derivative Liabilities		Netting of Collateral		Total(a)
Current Assets—Derivatives	$	3.9	$	-	$	-	$	3.9
Deferred Charges and Other Assets—Derivatives		9.5		-		-		9.5
Current Liabilities—Derivatives		8.6		(43.2)		0.7		(33.9)
Deferred Credits—Derivatives		4.2		(265.2)		0.2		(260.8)
Total	$	26.2	$	(308.4)	$	0.9	$	(281.3)
As of September 30, 2013
Current Assets—Derivatives	$	19.3	$	(12.3)	$	(2.7)	$	4.3
Deferred Charges and Other Assets—Derivatives		47.2		(31.1)		-		16.1
Current Liabilities—Derivatives		1.5		(26.2)		-		(24.7)
Deferred Credits—Derivatives		-		(106.1)		-		(106.1)
Total	$	68.0	$	(175.7)	$	(2.7)	$	(110.4)
(a)WGL has elected to offset the fair value of recognized derivative instruments against the right to reclaim or the obligation to return collateral for derivative instruments executed under the same master netting arrangement in accordance with ASC 815. All recognized derivative contracts and associated financial collateral subject to a master netting arrangement or similar that is eligible for offset under ASC 815 have been presented net in the balance sheet.
(b)Washington Gas did not have any derivative instruments outstanding that were designated as hedging instruments at September 30, 2014, or 2013.

Gains and (Losses) on Derivative Instruments

Washington Gas Gains and Losses on Derivative Instruments
(In millions)
Fiscal Year Ended September 30,		2014		2013		2012
Recorded to income
Utility cost of gas	$	(87.3)	$	(45.9)	$	22.3
Recorded to regulatory assets
Gas costs		(143.3)		(115.1)		42.2
Other		0.2		-		-
Total	$	(230.4)	$	(161.0)	$	64.5

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Changes in Accumulated Other Comprehensive Income Table (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2012
WGL Holdings, Inc.
Accumulated Other Comprehensive Income (Loss) Net Of Tax [Roll Forward]
Beginning Balance	$ (11,048)		$ (12,201)
Qualified cash flow hedging instruments	(1,548)	[1]	0		0
Change in prior service cost (credit)	6,095	[2],[3]	(1,671)	[2]	(640)
Amortization of actuarial gain (loss)	1,594	[2]	3,399	[2]	(2,125)
Amortization of transition obligation	0	[2]	238	[2]	239
Current-period other comprehensive income	6,141		1,966		(2,526)
Income tax expense related to other comprehensive income	3,054	[3]	813		(987)
Ending Balance	(7,961)		(11,048)		(12,201)
Washington Gas Light Company
Accumulated Other Comprehensive Income (Loss) Net Of Tax [Roll Forward]
Beginning Balance	(11,048)		(12,201)
Change in prior service cost (credit)	6,095	[2],[3]	(1,671)	[2]	(640)
Amortization of actuarial gain (loss)	1,594	[2]	3,399	[2]	(2,125)
Amortization of transition obligation	0	[2]	238	[2]	239
Current-period other comprehensive income	7,689		1,966		(2,526)
Income tax expense related to other comprehensive income	3,054	[3]	813		(987)
Ending Balance	$ (6,413)		$ (11,048)		$ (12,201)

[1] (c ) Cash flow hedging instruments represent interest rate swap agreements on debt issuances. Refer to Note 14 - Derivative and Weather-related Instruments for further discussion of the interest rate swap agreements.

[2] (a) These accumulated other comprehensive income components are included in the computation of net periodic benefit cost. Refer to Note 10-Pension and other post-retirement benefit plans for additional details.

[3] (b) The majority of the 2014 change to the prior service cost component of other comprehensive income is related to the impact of the OPEB plan amendment and re-measurement. Refer to Note 10-Pension and other post-retirement benefit plans for additional details.

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Consolidated Statements of Cash Flows (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Sep. 30, 2014 WGL Holdings, Inc.	Sep. 30, 2013 WGL Holdings, Inc.	Sep. 30, 2012 WGL Holdings, Inc.	Sep. 30, 2014 Washington Gas Light Company	Sep. 30, 2013 Washington Gas Light Company	Sep. 30, 2012 Washington Gas Light Company
OPERATING ACTIVITIES
Net income	$ 107,260	$ 81,573	$ 141,138	$ 98,324	$ 72,322	$ 110,046
ADJUSTMENTS TO RECONCILE NET INCOME TO NET CASH PROVIDED BY OPERATING ACTIVITIES
Depreciation and amortization	110,772	103,284	96,476	102,713	99,188	93,811
Amortization of:
Other regulatory assets and liabilities-net	610	574	881	610	911	881
Debt related costs	886	873	894	886	527	894
Deferred income taxes-net	25,795	1,431	107,699	7,050	(2,915)	89,132
Accrued/deferred pension and other post-retirement benefit cost	33,384	36,127	(60,459)	33,670	35,707	(58,645)
Compensation expense related to stock-based awards	4,105	3,050	4,122	3,185	2,292	3,394
Provision for doubtful accounts	14,252	9,258	18,316	11,839	7,183	12,794
Impairment loss	2,639	2,600	5,015	2,639	2,600	5,015
Other non-cash charges (credits)-net	(3,079)	2,536	(5,151)	8,838	7,615	(2,726)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable and unbilled revenues-net	(1,769)	12,105	(65,329)	(39,253)	(464)	(19,041)
Gas costs and other regulatory assets/liabilities-net	2,623	36,359	(13,650)	2,623	36,359	(13,650)
Storage gas	13,689	(64,283)	7,386	(23,857)	(17,400)	51,228
Prepaid Taxes	(42,128)	33,506	(36,643)	(1,269)	31,937	(32,546)
Accounts payable and other accrued liabilities	21,326	2,017	(16,683)	49,429	(24,949)	27,214
Customer deposits and advance payments	1,164	(22,166)	11,181	1,164	(22,166)	11,181
Accrued taxes	(1,923)	(6,980)	6,111	(770)	6,272	(3,721)
Unamortized investment tax credits	56,639	19,296	14,736
Other current assets	(16,130)	(2,513)	(5,768)	(5,089)	5,843	2,964
Other current liabilities	(1,062)	22,106	27,297	(526)	19,253	3,676
Deferred gas costs-net	(97,383)	(113,474)	36,309	(97,383)	(113,474)	36,309
Deferred assets-other	(7,525)	(133)	(51,889)	(10,073)	(757)	(43,553)
Deferred liabilities-other	(3,130)	45	(5,230)	(3,007)	(966)	(23,887)
Derivatives	178,104	163,571	(1,858)	170,744	137,559	(3,608)
Pension and other post-retirement benefits	(16,602)	(4,417)	10,613	(16,973)	(4,261)	10,786
Other-net	(350)	1,679	(7,915)	(359)	(4,167)	(1,673)
Net Cash Provided by (Used in) Operating Activities	382,167	318,024	217,599	295,155	274,049	256,275
FINANCING ACTIVITIES
Common stock issued	714	0	631
Long-term debt issued	175,253	4,157	0	175,253	4,157	0
Long-term debt retired	(67,000)	(2,295)	(77,000)	(67,000)	(2,295)	(77,000)
Debt issuance costs	(1,543)	0	(123)	(1,543)	0	0
Notes payable issued (retired)-net	80,400	125,400	208,279	(35,500)	25,700	98,778
Dividends on common stock and preferred stock	(85,901)	(86,078)	(77,182)	(79,665)	(76,522)	(75,239)
Repurchase of common stock	(56,136)	0	0
Other financing activities-net	(560)	5,156	564	(1,749)	336	2,533
Net Cash Provided by (Used in) Financing Activities	45,227	46,340	55,169	(10,204)	(48,624)	(50,928)
INVESTING ACTIVITIES
Capital expenditures (excluding AFUDC)	(394,762)	(312,345)	(251,128)	(283,891)	(225,426)	(206,699)
Investments in non-utility interests	(31,415)	(62,894)	(24,636)
Distributions from non-utility interests	4,116	4,090	8,927
Net Cash Used in Investing Activities	(422,061)	(371,149)	(266,837)	(283,891)	(225,426)	(206,699)
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	5,333	(6,785)	5,931	1,060	(1)	(1,352)
Cash and Cash Equivalents at Beginning of Year	3,478	10,263	4,332	0	1	1,353
Cash and Cash Equivalents at End of Year	8,811	3,478	10,263	1,060	0	1
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Income taxes paid (refunded) - net	20,110	(10,741)	23,915	19,007	(15,799)	29,625
Interest paid	36,991	35,471	36,777	36,380	35,091	36,447
SUPPLEMENTAL DISCLOSURES OF NON-CASH INVESTING AND FINANCING ACTIVITIES
Project debt financing activities - net	253	1,386	2,004	253	1,386	2,004
Capital expenditure accruals included in accounts payable and other accrued liabilities	55,164	32,040	34,980	46,331	16,429	22,909
Dividends paid in common stock	$ 5,312	$ 6,863	$ 5,260

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Environmental Matter (Narrative) (Details) (Washington Gas Light Company)	12 Months Ended
	Sep. 30, 2014
Number of Sites	10
Accrual For Environmental Costs
Number of Sites	4
District of Columbia
Recovery of environmental response costs	Rate orders issued by the PSC of DC allow Washington Gas a three-year recovery of prudently incurred environmental response costs, and allow Washington Gas to defer additional costs incurred between rate cases
Maryland
Recovery of environmental response costs	Regulatory orders issued by the PSC of MD allow Washington Gas to recover the costs associated with the sites applicable to Maryland over the period ending in 2025
Virginia
Recovery of environmental response costs	Regulatory orders from the SCC of VA have generally allowed the recovery of prudent environmental remediation costs to the extent they were included in the underlying financial data supporting an application for rate change

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Consolidated Statements of Common Shareholders Equity - WGLH (WGL Holdings, Inc., USD $) In Thousands, except Share data, unless otherwise specified	WGL Holdings, Inc. USD ($)	Common Stock [Member] WGL Holdings, Inc. USD ($)	Paid-In Capital WGL Holdings, Inc. USD ($)	Retained Earnings WGL Holdings, Inc. USD ($)	Accumulated Other Comprehensive Loss, Net of Taxes WGL Holdings, Inc. USD ($)
Common shareholders' equity, beginning balance at Sep. 30, 2011	$ 1,202,715	$ 557,594	$ 7,731	$ 648,052	$ (10,662)
Beginning Balance, shares at Sep. 30, 2011		51,365,337
Net Income	141,138			141,138
OTHER COMPREHENSIVE INCOME (LOSS)	(1,539)				(1,539)
Dividend Reinvestment	6,317	6,317
Dividend Reinvestment, Shares		152,435
Repurchase of common stock	0
Stock-based compensation	4,088	3,687	401
Stock-based compensation, Shares		93,875
Dividends Abstract
Common Stock	(81,843)			(81,843)
Preferred Stock	(1,320)			(1,320)
Common shareholders' equity, ending balance at Sep. 30, 2012	1,269,556	567,598	8,132	706,027	(12,201)
Ending Balance, shares at Sep. 30, 2012		51,611,647
Net Income	81,573			81,573
OTHER COMPREHENSIVE INCOME (LOSS)	1,153				1,153
Dividend Reinvestment	6,254	6,254
Dividend Reinvestment, Shares		145,920
Repurchase of common stock	0
Stock-based compensation	3,187	609	2,578
Stock-based compensation, Shares		16,637
Dividends Abstract
Common Stock	(85,858)			(85,858)
Preferred Stock	(1,320)			(1,320)
Common shareholders' equity, ending balance at Sep. 30, 2013	1,274,545	574,461	10,710	700,422	(11,048)
Ending Balance, shares at Sep. 30, 2013		51,774,204
Net Income	107,260			107,260
OTHER COMPREHENSIVE INCOME (LOSS)	3,087				3,087
Dividend Reinvestment	4,649	4,649
Dividend Reinvestment, Shares		114,883
Repurchase of common stock	(56,136)	(56,136)
Repurchase of common stock, Shares		(1,304,504)
Stock-based compensation	4,095	2,958	1,137
Stock-based compensation, Shares		71,970
Dividends Abstract
Common Stock	(89,604)			(89,604)
Preferred Stock	(1,320)			(1,320)
Common shareholders' equity, ending balance at Sep. 30, 2014	$ 1,246,576	$ 525,932	$ 11,847	$ 716,758	$ (7,961)
Ending Balance, shares at Sep. 30, 2014		50,656,553

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Regulated Operations (Details) (USD $)	Sep. 30, 2014		Sep. 30, 2013
Asset Recoverable Gas Costs
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities, Current	$ 16,200,000	[1]	$ 23,400,000	[1]
Interruptible Sharing
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	3,400,000	[1]	10,700,000	[1]
Regulatory Liabilities, Current	0	[1]	1,900,000	[1]
Conservation And Rate Making Efficiency Adjustment
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	0	[1]	100,000	[1]
Regulatory Liabilities, Current	5,500,000	[1]	1,500,000	[1]
Plant Recovery Mechanisms
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	400,000		0
Regulatory Liabilities, Current	900,000		200,000
Total current
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	3,800,000		10,800,000
Regulatory Liabilities, Current	22,600,000		27,000,000
Accrued Asset Removal Costs
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Liability, Noncurrent	327,400,000		321,300,000
Deferred Fuel Costs
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	191,300,000	[1]	94,000,000	[1]
Other post-retirement benefits
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	0	[2]	700,000	[2]
Deferred pension costs/income-trackers
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	45,100,000	[2]	51,000,000	[2]
Unrecognized Pension Cost
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	147,900,000	[1],[3]	155,100,000	[1],[3]
Unrecognized Other Post Retirement Benefits
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	0	[1],[3]	33,800,000	[1],[3]
Regulatory Liability, Noncurrent	86,400,000	[1],[3]	0	[1],[3]
Total pension and other post-retirement benefits
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	193,000,000		240,600,000
Regulatory Liability, Noncurrent	86,400,000		0
Income tax-related amounts due from to customers
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	30,400,000	[4]	24,900,000	[4]
Regulatory Liability, Noncurrent	4,800,000	[4]	4,500,000	[4]
Deferred Gain (Loss) on Early Extinguishment of Debt
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	12,000,000	[1],[5]	11,600,000	[1],[5]
Regulatory Liability, Noncurrent	1,700,000	[1],[5]	600,000	[1],[5]
Deferred Gain On Sale Of Assets
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Liability, Noncurrent	1,400,000	[1]	1,700,000	[1]
Rights Of Way Fee
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	1,500,000	[1]	0	[1]
Regulatory Liability, Noncurrent	0	[1]	1,600,000	[1]
Other Costs Business Process Outsourcing
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	1,000,000	[1]	1,400,000	[1]
Non Retirement Postemployment Benefits
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	16,300,000	[1],[6]	15,400,000	[1],[6]
Deferred integrity management expenditures
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	2,700,000	[1],[7]	0	[1],[7]
Recoverable portion of abandoned LNG facility
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	5,600,000	[1]	7,900,000	[1]
Other Regulatory Expenses
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	2,100,000	[1]	4,800,000	[1]
Regulatory Liability, Noncurrent	9,700,000	[1]	5,100,000	[1]
Total Other
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	71,600,000		66,000,000
Regulatory Liability, Noncurrent	17,600,000		13,500,000
Total Deferred
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	455,900,000		400,600,000
Regulatory Liability, Noncurrent	431,400,000		334,800,000
Total
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	459,700,000		411,400,000
Regulatory Liabilities	$ 454,000,000		$ 361,800,000

[1] Washington Gas does not earn its overall rate of return on these assets. Washington Gas is allowed to recover and required to pay, using short-term interest rates, the carrying costs related to billed gas costs due from and to its customers in the District of Columbia and Virginia jurisdictions.

[2] Relates to the District of Columbia jurisdiction.

[3] Refer to Note 10-Pension and Other Post-Retirement Benefit Plans for a further discussion of these amounts.

[4] This balance represents amounts due from customers for deferred tax liabilities related to tax benefits on deduction flowed directly to customers prior to the adoption of income tax normalization for ratemaking purposes.

[5] The losses or gains on the issuance and extinguishment of debt and interest-rate derivative instruments include unamortized balances from transactions executed in prior fiscal years. These transactions create gains and losses that are amortized over the remaining life of the debt as prescribed by regulatory accounting requirements.

[6] Represents the timing difference between the recognition of workers compensation and short-term disability costs in accordance with generally accepted accounting principles and the way these costs are recovered through rates.

[7] This balance represents amounts for deferred expenditures associated with Washington Gas' Distribution Integrity Management Program (DIMP) in Virginia.

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Pension and Other Post-retirement Benefit Plans (Table 9) (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Changes in fair value of the Level 3 assets [Abstract]
Fair Value of plan assets at beginning of year	$ 21.1	$ 18.7
Assets still held at year end	2.7	2.4
Fair value of plan assets at end of year	$ 23.8	$ 21.1

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Related Party Transactions (Details) (USD $)	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
WGEServices
Related Party Transaction [Line Items]
Related Party Gas Imbalance - Receivable	$ 24,709	$ 1,000,000
Washington Gas Light Company
Related Party Transaction [Line Items]
Related Party Transaction, Revenues from Transactions with Related Party	26,600,000	25,000,000	26,800,000
Due from Related Parties, Current	4,800,000	7,200,000
Due to Related Parties, Current	54,700,000	20,600,000
Related Party Purchased Receivables	$ 7,700,000	$ 106,600,000

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Income Taxes (Tax Rate Reconciliation) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2012
WGL Holdings, Inc.
Income taxes at statutory federal tax rate	$ 57,580	$ 46,853	$ 82,070
Accelerated depreciation less amount deferred	1,875	2,106	1,178
Amortization of investment tax credits	(3,666)	(1,822)	(1,132)
Cost Of Removal	(4,902)	(2,356)	(2,291)
State income taxes-net of federal benefit	8,734	7,448	12,068
Medicare D subsidy	3,621	0	(2,827)
Other items-net	1,254	63	(1,371)
Income Tax Expense (Benefit), Continuing Operations, Total	57,254	52,292	93,349
Statutory federal income tax rate (%)	35.00%	35.00%	35.00%
Accelerated depreciation less amount deferred (%)	1.14%	1.57%	0.50%
Amortization of investment tax credits (%)	(2.23%)	(1.36%)	(0.48%)
Cost of removal (%)	(2.98%)	(1.76%)	(0.98%)
State income taxes-net of federal benefit (%)	5.31%	5.56%	5.15%
Medicare D adjustment (%)	(2.20%)	0.00%	1.21%
Other items-net (%)	0.76%	0.05%	(0.59%)
Effective Income Tax Rate, Continuing Operations, Total	34.80%	39.06%	39.81%
Washington Gas Light Company
Income taxes at statutory federal tax rate	51,050	40,782	63,628
Accelerated depreciation less amount deferred	1,875	2,106	1,178
Amortization of investment tax credits	(876)	(895)	(898)
Cost Of Removal	(4,902)	(2,356)	(2,291)
State income taxes-net of federal benefit	6,711	5,487	8,916
Consolidated tax sharing allocation	(2,862)	(1,290)	(309)
Medicare D subsidy	3,621	0	(2,827)
Other items-net	159	363	(1,304)
Income Tax Expense (Benefit), Continuing Operations, Total	$ 47,534	$ 44,197	$ 71,747
Statutory federal income tax rate (%)	35.00%	35.00%	35.00%
Accelerated depreciation less amount deferred (%)	1.29%	1.81%	0.65%
Amortization of investment tax credits (%)	(0.60%)	(0.77%)	(0.49%)
Cost of removal (%)	(3.36%)	(2.02%)	(1.26%)
State income taxes-net of federal benefit (%)	4.60%	4.71%	4.90%
Consolidated tax sharing allocation (%)	(1.96%)	(1.11%)	(0.17%)
Medicare D adjustment (%)	(2.48%)	0.00%	1.56%
Other items-net (%)	0.09%	0.31%	(0.72%)
Effective Income Tax Rate, Continuing Operations, Total	32.58%	37.93%	39.47%

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Fair Value Measurements

12 Months Ended

Sep. 30, 2014

Fair Value Measurements [Abstract]

Fair Value Measurements

NOTE 15.FAIR VALUE MEASUREMENTS

Recurring Basis

We measure the fair value of our financial assets and liabilities using a combination of the income and market approach in accordance with ASC Topic 820. These financial assets and liabilities primarily consist of (i) derivatives recorded on our balance sheet under ASC Topic 815, (ii) weather-relatedinstruments and (iii)short-term investments, commercial paper and long-term debt outstanding required to be disclosed at fair value. Under ASC Topic 820, fair value is defined as the exit price, representing the amount that would be received in the sale of an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. To value our financial instruments, we use market data or assumptions that market participants would use, including assumptions about credit risk (both our own credit risk and the counterparty's credit risk) and the risks inherent in the inputs to valuation.

We enter into derivative contracts in the futures and over-the-counter (OTC) wholesale and retail markets. These markets are the principal markets for the respective wholesale and retail contracts. Our relevant market participants are our existing counterparties and others who have participated in energy transactions at our delivery points. These participants have access to the same market data as WGL. We value our derivative contracts based on an “in-exchange” premise, and valuations are generally based on pricing service data or indicative broker quotes depending on the market location. We measure the net credit exposure at the counterparty level where the right to set-off exists. The net exposure is determined using the mark-to-market exposure adjusted for collateral, letters of credit and parent guarantees. We use published default rates from Standard & Poor's Ratings Services and Moody's Investors Service as inputs for determining credit adjustments.

ASC Topic 820 establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority to unobservable inputs. The three levels of the fair value hierarchy under ASC Topic 820 are described below:

Level 1.  Level 1 of the fair value hierarchy consists of assets or liabilities that are valued using observable inputs based upon unadjusted quoted prices in active markets for identical assets or liabilities at the reporting date. Level 1 assets and liabilities primarily include exchange traded derivatives and securities.

Level 2.  Level 2 of the fair value hierarchy consists of assets or liabilities that are valued using directly or indirectly observable inputs either corroborated with market data or based on exchange traded market data. Level 2 includes fair values based on industry-standard valuation techniques that consider various assumptions: (i) quoted forward prices, including the use of mid-market pricing within a bid/ask spread; (ii) discount rates; (iii) implied volatility and (iv) other economic factors. Substantially all of these assumptions are observable throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the relevant market. At September 30, 2014 and 2013, Level 2 financial assets and liabilities included energy-related derivatives such as financial contracts, options and physical forward contracts for deliveries at active market locations.

Level 3.  Level 3 of the fair value hierarchy consists of assets or liabilities that are valued using significant unobservable inputs at the reporting date. These unobservable assumptions reflect our assumptions about estimates that market participants would use in pricing the asset or liability, including natural gas basis prices, annualized volatilities of natural gas prices, and electricity congestion prices. A significant change to any one of these inputs in isolation could result in a significant upward or downward fluctuation in the fair value measurement. These inputs may be used with industry standard valuation methodologies that result in our best estimate of fair value for the assets or liabilities at the reporting date.

Our Risk Analysis and Mitigation (RA&M) Group determines the valuation policies and procedures.  The RA&M Group reports to WGL'sChief Financial Officer.  In accordance with WGL's valuation policy, we may utilize a variety of valuation methodologies to fair value Level 3 derivative contracts including internally developed valuation inputs and pricing models.  The prices used in our valuations are corroborated using multiple pricing sources, and we periodically conduct assessments to determine whether each valuation model is appropriate for its intended purpose. The RA&M Group also evaluates changes in fair value measurements on a daily basis.

At September 30, 2014 and 2013, Level 3 derivative assets and liabilities included: (i) physical contracts valued at illiquid market locations with no observable market data; (ii) long-dated positions where observable pricing is not available over the life of the contract; (iii) contracts valued using historical spot price volatility assumptions; (iv) valuations using indicative broker quotes for inactive market locations and (v) non-publicly traded stock warrants.

The following tables set forth financial instruments recorded at fair value as of September 30, 2014 and 2013, respectively. A financial instrument's classification within the fair value hierarchy is based on the lowest level of any input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy.

WGL Holdings, Inc.
Fair Value Measurements Under the Fair Value Hierarchy
(In millions)	Level 1		Level 2		Level 3		Total
At September 30, 2014
Assets
Natural gas related derivatives	$	-	$	22.7	$	33.7	$	56.4
Electricity related derivatives		-		0.3		15.9		16.2
Total Assets	$	-	$	23.0	$	49.6	$	72.6
Liabilities
Natural gas related derivatives	$	-	$	(39.8)	$	(328.4)	$	(368.2)
Electricity related derivatives		-		(0.1)		(20.9)		(21.0)
Interest rate derivatives		-		(1.7)		-		(1.7)
Total Liabilities	$	-	$	(41.6)	$	(349.3)	$	(390.9)

At September 30, 2013
Assets
Natural gas related derivatives	$	-	$	72.3	$	21.5	$	93.8
Electricity related derivatives		-		-		25.4		25.4
Warrants		-		-		1.1		1.1
Total Assets	$	-	$	72.3	$	48.0	$	120.3
Liabilities
Natural gas related derivatives	$	-	$	(41.1)	$	(176.7)	$	(217.8)
Electricity related derivatives		-		(7.0)		(23.0)		(30.0)
Total Liabilities	$	-	$	(48.1)	$	(199.7)	$	(247.8)

Washington Gas Light Company
Fair Value Measurements Under the Fair Value Hierarchy
(In millions)	Level 1		Level 2		Level 3		Total
At September 30, 2014
Assets
Natural gas related derivatives	$	-	$	13.5	$	12.7	$	26.2
Total Assets	$	-	$	13.5	$	12.7	$	26.2
Liabilities
Natural gas related derivatives	$	-	$	(25.1)	$	(283.3)	$	(308.4)
Total Liabilities	$	-	$	(25.1)	$	(283.3)	$	(308.4)

At September 30, 2013
Assets
Natural gas related derivatives	$	-	$	51.0	$	17.0	$	68.0
Total Assets	$	-	$	51.0	$	17.0	$	68.0
Liabilities
Natural gas related derivatives	$	-	$	(25.1)	$	(150.6)	$	(175.7)
Total Liabilities	$	-	$	(25.1)	$	(150.6)	$	(175.7)

The following table includes quantitative information about the significant unobservable inputs used in the fair value measurement of our Level 3 financial instruments and the respective fair values of the net derivative asset and liability positions, by contract type, as of September 30, 2014and 2013.

Quantitative Information about Level 3 Fair Value Measurements
(In millions)	Net Fair Value September 30, 2014	Valuation Techniques	Unobservable Inputs	Range
WGL Holdings, Inc.	(In millions)
Natural gas related derivatives	($294.7)	Discounted Cash Flow	Natural Gas Basis Price (per dekatherm)	($2.101) -	$6.154
		Option Model	Natural Gas Basis Price (per dekatherm)	($1.675) -	$6.154
			Annualized Volatility of Spot Market Natural Gas	30.9% -	589.6%
Electricity related derivatives	($5.0)	Discounted Cash Flow	Electricity Congestion Price (per megawatt hour)	($2.85) -	$90.95
		Internal Model	Electricity Congestion Price (per megawatt hour)
		Option Model	Electricity Congestion Price (per megawatt hour)
			Annualized Volatility of Electricity Prices
Washington Gas Light Company
Natural gas related derivatives	($270.6)	Discounted Cash Flow	Natural Gas Basis Price (per dekatherm)	($2.101) -	$6.154

Quantitative Information about Level 3 Fair Value Measurements
(In millions)	Net Fair Value September 30, 2013	Valuation Techniques	Unobservable Inputs	Range
WGL Holdings, Inc.	(In millions)
Natural gas related derivatives	($155.2)	Discounted Cash Flow	Natural Gas Basis Price (per dekatherm)	($1.780) -	$2.205
		Option Model	Natural Gas Basis Price (per dekatherm)	($0.181) -	$0.628
			Annualized Volatility of Spot Market Natural Gas	34.6% -	276.6%
Electricity related derivatives	$2.4	Discounted Cash Flow	Electricity Congestion Price (per megawatt hour)	($1.995) -	$64.150
Washington Gas Light Company
Natural gas related derivatives	($133.6)	Discounted Cash Flow	Natural Gas Basis Price (per dekatherm)	($1.780) -	$2.205
		Option Model	Natural Gas Basis Price (per dekatherm)	$0.024 -	$0.628
			Annualized Volatility of Spot Market Natural Gas	46.8% -	276.6%

The following tables are a summary of the changes in the fair value of our derivative instruments that are measured at net fair value on a recurring basis in accordance with ASC Topic 820 using significant Level 3 inputs during the years ended September 30, 2014 and 2013, respectively.

WGL Holdings, Inc. Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs
(In millions)		Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Fiscal Year Ended September 30, 2014
Balance at October 1, 2013	$	(155.2)	$	2.4	$	-	$	1.1	$	(151.7)
Realized and unrealized gains (losses)
Recorded to income		(72.6)		(5.7)		-		(1.1)		(79.4)
Recorded to regulatory assets - gas costs		(113.6)		-		-		-		(113.6)
Transfers out of Level 3		1.7		-		-		-		1.7
Purchases		-		5.2		-		-		5.2
Settlements		45.0		(6.9)		-		-		38.1
Balance at September 30, 2014	$	(294.7)	$	(5.0)	$	-	$	-	$	(299.7)

WGL Holdings, Inc. Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs
(In millions)		Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Fiscal Year Ended September 30, 2013
Balance at October 1, 2012	$	39.6	$	2.8	$	(0.5)	$	0.9	$	42.8
Realized and unrealized gains (losses)
Recorded to income		(72.4)		(23.8)		1.2		0.2		(94.8)
Recorded to regulatory assets - gas costs		(115.3)		-		-		-		(115.3)
Transfers out of Level 3		(17.4)		-		(0.7)		-		(18.1)
Purchases		-		5.7		-		-		5.7
Settlements		10.3		17.7		-		-		28.0
Balance at September 30, 2013	$	(155.2)	$	2.4	$	-	$	1.1	$	(151.7)

Washington Gas Light Company Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs
(In millions)		Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Fiscal Year Ended September 30, 2014
Balance at October 1, 2013	$	(133.6)	$	-	$	-	$	-	$	(133.6)
Realized and unrealized gains (losses)
Recorded to income		(69.4)		-		-		-		(69.4)
Recorded to regulatory assets - gas costs		(113.6)		-		-		-		(113.6)
Transfers out of Level 3		1.7		-		-		-		1.7
Settlements		44.3		-		-		-		44.3
Balance at September 30, 2014	$	(270.6)	$	-	$	-	$	-	$	(270.6)

Washington Gas Light Company Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs
(In millions)		Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Fiscal Year Ended September 30, 2013
Balance at October 1, 2012	$	35.6	$	-	$	(0.5)	$	-	$	35.1
Realized and unrealized gains (losses)
Recorded to income		(45.9)		-		1.2		-		(44.7)
Recorded to regulatory assets - gas costs		(115.3)		-		-		-		(115.3)
Transfers out of Level 3		(17.4)		-		(0.7)		-		(18.1)
Settlements		9.4		-		-		-		9.4
Balance at September 30, 2013	$	(133.6)	$	-	$	-	$	-	$	(133.6)

Transfers between different levels of the fair value hierarchy may occur based on the level of observable inputs used to value the instruments from period to period. It is our policy to show both transfers into and out of the different levels of the fair value hierarchy at the fair value as of the beginning of the reporting period. For WGL and Washington Gas net derivative assets transferred out of Level 3 during the fiscal year ended September 30, 2014 reflected an increase in the observable market inputs used to value those instruments.

The table below sets forth the line items on the statements of income to which amounts are recorded for the fiscal years ended September 30, 2014, 2013 and 2012, related to fair value measurements using significant level 3 inputs.

WGL Holdings, Inc. Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Fiscal Year Ended September 30, 2014
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Operating revenues—non-utility	$	(2.3)	$	(22.1)	$	-	$	-	$	(24.4)
Utility cost of gas		(69.4)		-		-		-		(69.4)
Other income-net		-		-		-		(1.1)		(1.1)
Non-utility cost of energy-related sales		(0.9)		16.4		-		-		15.5
Total	$	(72.6)	$	(5.7)	$	-	$	(1.1)	$	(79.4)

WGL Holdings, Inc. Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Fiscal Year Ended September 30, 2013
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Operating revenues—non-utility	$	(27.0)	$	(9.1)	$	-	$	-	$	(36.1)
Utility cost of gas		(45.8)		-		-		-		(45.8)
Other income-net		-		-		-		0.2		0.2
Non-utility cost of energy-related sales		0.4		(14.7)		-		-		(14.3)
Operation and maintenance expense		-		-		1.2		-		1.2
Total	$	(72.4)	$	(23.8)	$	1.2	$	0.2	$	(94.8)

WGL Holdings, Inc. Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Fiscal Year Ended September 30, 2012
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Operating revenues—non-utility	$	3.0	$	(14.2)	$	-	$	-	$	(11.2)
Utility cost of gas		14.3		-		-		-		14.3
Other income-net		-		-		-		0.9		0.9
Non-utility cost of energy-related sales		4.8		(33.5)		-		-		(28.7)
Operation and maintenance expense		-		-		7.9		-		7.9
Total	$	22.1	$	(47.7)	$	7.9	$	0.9	$	(16.8)

Washington Gas Light Company Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Fiscal Year Ended September 30, 2014
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Utility cost of gas	$	(69.4)	$	-	$	-	$	-	$	(69.4)
Total	$	(69.4)	$	-	$	-	$	-	$	(69.4)

Washington Gas Light Company Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Fiscal Year Ended September 30, 2013
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Utility cost of gas	$	(45.9)	$	-	$	-	$	-	$	(45.9)
Operation and maintenance expense		-		-		1.2		-		1.2
Total	$	(45.9)	$	-	$	1.2	$	-	$	(44.7)

Washington Gas Light Company Realized and Unrealized Gains (Losses) Recorded for Level 3 Measurements
Fiscal Year Ended September 30, 2012
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Utility cost of gas	$	14.3	$	-	$	-	$	-	$	14.3
Operation and maintenance expense		-		-		7.9		-		7.9
Total	$	14.3	$	-	$	7.9	$	-	$	22.2

Unrealized gains (losses) for the fiscal years ended September 30, 2014, September 30, 2013 and September 30, 2012 attributable to derivative assets and liabilities measured using significant Level 3 inputs were recorded as follows, respectively:

WGL Holdings, Inc. Unrealized Gains (Losses) Recorded for Level 3 Measurements
Fiscal Year Ended September 30, 2014
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Recorded to income
Operating revenues—non-utility	$	(5.0)	$	(33.8)	$	-	$	-	$	(38.8)
Utility cost of gas		(60.6)		-		-		-		(60.6)
Non-utility cost of energy-related sales		3.7		30.0		-		-		33.7
Other income-net		-		-		-		(1.1)		(1.1)
Recorded to regulatory assets—gas costs		(109.9)		-		-		-		(109.9)
Total	$	(171.8)	$	(3.8)	$	-	$	(1.1)	$	(176.7)

WGL Holdings, Inc. Unrealized Gains (Losses) Recorded for Level 3 Measurements
Fiscal Year Ended September 30, 2013
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Recorded to income
Operating revenues—non-utility	$	(25.3)	$	6.6	$	-	$	-	$	(18.7)
Utility cost of gas		(44.3)		-		-		-		(44.3)
Non-utility cost of energy-related sales		0.2		(1.1)		-		-		(0.9)
Other income-net		-		-		-		0.2		0.2
Recorded to regulatory assets—gas costs		(111.6)		-		-		-		(111.6)
Total	$	(181.0)	$	5.5	$	-	$	0.2	$	(175.3)

WGL Holdings, Inc. Unrealized Gains (Losses) Recorded for Level 3 Measurements
Fiscal Year Ended September 30, 2012
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Derivatives		Warrants		Total
Recorded to income
Operating revenues—non-utility	$	4.3	$	4.8	$	-	$	-	$	9.1
Utility cost of gas		13.8		-		-		-		13.8
Non-utility cost of energy-related sales		0.8		14.0		-		-		14.8
Other income-net		-		-		-		0.9		0.9
Operation and maintenance expense		-		-		0.2		-		0.2
Recorded to regulatory assets—gas costs		23.2		-		-		-		23.2
Total	$	42.1	$	18.8	$	0.2	$	0.9	$	62.0

Washington Gas Light Company Unrealized Gains (Losses) Recorded for Level 3 Measurements
Fiscal Year Ended September 30, 2014
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Recorded to income
Utility cost of gas	$	(60.6)	$	-	$	-	$	-	$	(60.6)
Recorded to regulatory assets—gas costs		(109.9)		-		-		-		(109.9)
Total	$	(170.5)	$	-	$	-	$	-	$	(170.5)

Washington Gas Light Company Unrealized Gains (Losses) Recorded for Level 3 Measurements
Fiscal Year Ended September 30, 2013
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Recorded to income
Utility cost of gas	$	(44.3)	$	-	$	-	$	-	$	(44.3)
Recorded to regulatory assets—gas costs		(111.6)		-		-		-		(111.6)
Total	$	(155.9)	$	-	$	-	$	-	$	(155.9)

Washington Gas Light Company Unrealized Gains (Losses) Recorded for Level 3 Measurements
Fiscal Years Ended September 30, 2012
(In millions)	Natural Gas Related Derivatives		Electricity Related Derivatives		Weather Related Instruments		Warrants		Total
Recorded to income
Utility cost of gas	$	13.8	$	-	$	-	$	-	$	13.8
Operation and maintenance expense		-		-		0.2		-		0.2
Recorded to regulatory assets—gas costs		23.2		-		-		-		23.2
Total	$	37.0	$	-	$	0.2	$	-	$	37.2

The following table presents the carrying amounts and estimated fair values of our financial instruments at September 30, 2014 and 2013.

WGL Holdings, Inc. Fair Value of Financial Instruments
At September 30,	2014				2013
(In millions)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
Money market funds (a)	$	9.7	$	9.7	$	6.5	$	6.5
Other short- term investments(a)	$	-	$	-	$	0.1	$	0.1
Commercial paper (b)	$	453.5	$	453.5	$	373.1	$	373.1
Long-term debt(c)	$	679.2	$	809.3	$	524.1	$	630.2
Washington Gas Light Company Fair Value of Financial Instruments
At September 30,	2014				2013
(In millions)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
Money market funds (a)	$	4.3	$	4.3	$	3.1	$	3.1
Other short- term investments(a)	$	-	$	-	$	0.1	$	0.1
Commercial paper (b)	$	89.0	$	89.0	$	124.5	$	124.5
Long-term debt(c)	$	679.2	$	809.3	$	524.1	$	630.2
(a)Balance located in cash and cash equivalents in the accompanying balance sheets. These amounts may be offset by outstanding checks.
(b)Balance is located in notes payable in the accompanying balance sheets.
(c)Less current maturities and unamortized discounts.

Our money market funds are Level 1 valuations and their carrying amount approximates fair value. Other short-term investments are primarily overnight investment accounts; therefore, their carrying amount approximates fair value based on Level 2 inputs. The maturity of our commercial paper outstanding at both September 30, 2014 and 2013 is under 30 days. Due to the short term nature of these notes, the carrying cost of our commercial paper approximates fair value using Level 2 inputs. Washington Gas' long-term debt is not actively traded. The fair value of long-term debt was estimated based on the quoted market prices of the U.S. Treasury issues having a similar term to maturity, adjusted for Washington Gas' credit quality. Our long-term debt fair value measurement is classified as Level 3.

Non Recurring Basis

During the fiscal year ended September 30, 2014, Washington Gas recorded an impairment ofits previous operations center by reducing the carrying amount of $22.3 million down to its fair value of $21.5 million, resulting in an impairment charge of $0.8 million based on the progress made towards selling the facility.During the fiscal year ended September 30, 2013, Washington Gas recorded an impairment ofthis facility by reducing thecarrying amount of $24.9 million down to its fair value of $22.3 million, resulting in an impairment charge of $2.6 million based on the progress made towards selling the facility. During the fiscal year ended September 30, 2012, Washington Gas recorded an impairment of this facility by reducing the carrying amount of $29.9 million down to its fair value of $24.9 million, resulting in an impairment charge of $5.0 million.The fair value of this facility is a Level 3 measurement. At September 30, 2012, the facility was valued using the discounted cash value model that incorporatedthe anticipated sale proceeds indicated through a comparable analysis, incorporating expected market trends, and the estimated costs to carry the asset until a sale is completed. The current fiscal year valuation is based on the progress in the efforts to sell the property.

On July 7, 2014, the SCC of VA disallowed full recovery of carrying costs related to an abandonedLNG storagefacility. As a result, Washington Gas recorded an impairment charge of $1.9 million. During the fiscal year ended September 30, 2013, Washington Gas recorded an impairment charge of $0.5 million to theabandoned LNG storage facility.

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Pension and Other Post-retirement Benefit Plans (Table2) (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	$ 865.2	$ 788.8
Accumulated benefit obligation	801.9	737.2
Non-funded DB Serp [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	50.7	47.8
Accumulated benefit obligation	46.2	43.9
Non-funded DB Serp Restoration [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	1.2	0.8
Accumulated benefit obligation	$ 0.7	$ 0.5

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Accounts Payable and Other Accrued Liabilities (Tables)

12 Months Ended

Sep. 30, 2014

WGL Holdings, Inc.

Accounts Payable and Other Accrued Liabilities

WGL Holdings, Inc.
		September 30,
(In millions)		2014		2013
Accounts payable—trade	$	278.8	$	216.3
Employee benefits and payroll accruals		19.8		23.4
Embedded derivatives and other accrued liabilities		14.6		30.9
Total	$	313.2	$	270.6

Washington Gas Light Company

Accounts Payable and Other Accrued Liabilities

Washington Gas Light Company
		September 30,
(In millions)		2014		2013
Accounts payable—trade	$	146.4	$	99.7
Employee benefits and payroll accruals		18.2		21.4
Embedded derivatives and other accrued liabilities		11.9		11.7
Total	$	176.5	$	132.8

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Earnings Per Share

12 Months Ended

Sep. 30, 2014

Earnings Per Share [Abstract]

Earnings Per Share

NOTE 8.EARNINGS PER SHARE

Basic EPS is computed by dividing net income by the weighted average number of common shares outstanding during the reported period. Diluted EPS assumes the issuance of common shares pursuant to stock-based compensation plans at the beginning of the applicable period unless the effect of such issuance would be anti-dilutive (refer to Note 11—Stock-Based Compensation). The following table reflects the computation of our basic and diluted EPS for the fiscal years ended September 30, 2014, 2013 and 2012.

Basic and Diluted EPS
	Years Ended September 30,
(In thousands, except per share data)		2014		2013		2012
Basic earnings per average common share:
Net income applicable to common stock	$	105,940	$	80,253	$	139,818
Average common shares outstanding—basic		51,759		51,697		51,522
Basic earnings per average common share	$	2.05	$	1.55	$	2.71
Diluted earnings per average common share:
Net income applicable to common stock	$	105,940	$	80,253	$	139,818
Average common shares outstanding—basic		51,759		51,697		51,522
Stock-based compensation plans		11		111		67
Total average common shares outstanding—diluted		51,770		51,808		51,589
Diluted earnings per average common share	$	2.05	$	1.55	$	2.71

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Fair Value Measurements (Nonrecurring Basis) (Details) (USD $)	3 Months Ended		12 Months Ended
	Dec. 31, 2013 Springfield Operations Center	Sep. 30, 2013 Springfield Operations Center	Sep. 30, 2014 WGL Holdings, Inc.	Sep. 30, 2013 WGL Holdings, Inc.	Sep. 30, 2012 WGL Holdings, Inc.	Sep. 30, 2014 Washington Gas Light Company	Sep. 30, 2013 Washington Gas Light Company	Sep. 30, 2012 Washington Gas Light Company	Sep. 30, 2014 Washington Gas Light Company Springfield Operations Center	Sep. 30, 2013 Washington Gas Light Company Springfield Operations Center	Sep. 30, 2012 Washington Gas Light Company Springfield Operations Center	Sep. 30, 2014 Washington Gas Light Company Abandoned LNG Facility	Sep. 30, 2013 Washington Gas Light Company Abandoned LNG Facility
Fair Value Measurements [Line Items]
Carrying Amount Of Long Lived Assets Held For Use									$ 22,300,000	$ 24,900,000	$ 29,900,000
Fair Value Of Long Lived Assets Held For Use									21,500,000	22,300,000	24,900,000
Impairment loss	$ 800,000	$ 2,600,000	$ 2,639,000	$ 2,600,000	$ 5,015,000	$ 2,639,000	$ 2,600,000	$ 5,015,000	$ 800,000	$ 2,600,000	$ 5,000,000	$ 1,900,000	$ 500,000