Washington Gas Light (WGLCP) 10-Q 2 Aug 19 2019 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - $ / shares	6 Months Ended
	Jun. 30, 2019	Jul. 31, 2019
Document and Entity Information [Abstract]
Entity Registrant Name	Washington Gas Light Company
Entity Central Index Key	0000104819
Document Type	10-Q
Document Period End Date	Jun. 30, 2019
Amendment Flag	false
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q2
Current Fiscal Year End Date	--12-31
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		46,479,536
Par Value Per Share	$ 1

Balance Sheet

Balance Sheet - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018
Property, Plant and Equipment
At original cost	$ 5,906,669	$ 5,702,927
Accumulated depreciation and amortization	(1,572,807)	(1,513,590)
Net property, plant and equipment	4,333,862	4,189,337
Current Assets
Cash and cash equivalents	0	6,082
Receivables
Accounts receivable	218,422	292,871
Gas costs and other regulatory assets	12,530	6,020
Unbilled revenues	65,481	189,497
Allowance for doubtful accounts	(33,239)	(29,461)
Net receivables	263,194	458,927
Materials and supplies—principally at average cost	18,428	19,727
Storage gas	66,229	103,929
Prepaid taxes	24,221	27,193
Other prepayments	24,203	28,232
Receivables from associated companies	5,897	4,819
Derivatives	4,128	19,488
Other	4,378	20,347
Total current assets	410,678	688,744
Deferred Charges and Other Assets
Gas costs	60,630	141,636
Pension and other post-retirement benefits	79,928	86,493
Other	93,964	99,105
Prepaid post-retirement benefits	252,972	249,462
Right of use asset	41,802	0
Derivatives	10,262	11,318
Other	51,327	50,490
Total deferred charges and other assets	590,885	638,504
Total Assets	5,335,425	5,516,585
Capitalization
Common shareholder’s equity	1,604,804	1,562,573
Preferred stock	28,173	28,173
Long-term debt	1,035,098	1,035,033
Total capitalization	2,668,075	2,625,779
Current Liabilities
Current maturities of long-term debt	50,000	50,000
Notes payable and project financing	218,000	311,460
Accounts payable and other accrued liabilities	196,609	288,376
Wages payable	22,059	22,629
Accrued interest	14,615	14,504
Dividends declared	25,330	24,567
Customer deposits and advance payments	36,502	54,370
Gas costs and other regulatory liabilities	48,872	75,151
Accrued taxes	28,051	28,451
Payables to associated companies	56,299	95,228
Operating lease liability	4,647	0
Derivatives	8,244	20,295
Other	7,263	7,507
Total current liabilities	716,491	992,538
Deferred Credits
Unamortized investment tax credits	2,904	3,233
Deferred income taxes	481,373	454,248
Accrued pensions and benefits	163,219	156,210
Asset retirement obligations	305,903	300,769
Regulatory liabilities
Accrued asset removal costs	257,699	264,556
Other post-retirement benefits	113,658	121,345
Excess deferred taxes and other	427,506	431,913
Operating lease liability	55,341	0
Derivatives	93,311	116,847
Other	49,945	49,147
Total deferred credits	1,950,859	1,898,268
Commitments and Contingencies (Note 10)
Total Capitalization and Liabilities	$ 5,335,425	$ 5,516,585

Statement of Operations

Statement of Operations - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Income Statement [Abstract]
OPERATING REVENUES	$ 198,484	$ 199,512	$ 792,137	$ 731,552
OPERATING EXPENSES
Utility cost of gas	55,589	56,063	297,852	261,359
Operation and maintenance	88,236	85,210	199,238	179,015
Depreciation and amortization	37,051	34,043	72,240	67,511
General taxes and other assessments	27,746	30,845	80,365	81,338
Total Operating Expenses	208,622	206,161	649,695	589,223
OPERATING INCOME	(10,138)	(6,649)	142,442	142,329
Other income (expense) —net	(757)	193	3,765	1,787
Interest expense	14,641	14,455	29,517	29,127
INCOME (LOSS) BEFORE INCOME TAXES	(25,536)	(20,911)	116,690	114,989
INCOME TAX EXPENSE (BENEFIT)	(4,945)	(9,412)	24,285	18,404
NET INCOME (LOSS)	(20,591)	(11,499)	92,405	96,585
Dividends on preferred stock	330	330	660	660
NET INCOME (LOSS) APPLICABLE TO COMMON STOCK	$ (20,921)	$ (11,829)	$ 91,745	$ 95,925

Statement of Comprehensive Inco

Statement of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Statement of Comprehensive Income [Abstract]
NET INCOME (LOSS)	$ (20,591)	$ (11,499)	$ 92,405	$ 96,585
Pension and other post-retirement benefit plans
Change in prior service cost	(161)	(273)	(323)	(546)
Change in actuarial net gain (loss)	(2,848)	530	2,056	1,060
Total pension and other post-retirement benefit plans	(3,009)	257	1,733	514
INCOME TAX EXPENSE RELATED TO OTHER COMPREHENSIVE INCOME	770	69	1,247	143
OTHER COMPREHENSIVE INCOME (LOSS)	(3,779)	188	486	371
COMPREHENSIVE INCOME (LOSS)	$ (24,370)	$ (11,311)	$ 92,891	$ 96,956

Statements of Cash Flows

Statements of Cash Flows - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
OPERATING ACTIVITIES
Net income	$ 92,405	$ 96,585
ADJUSTMENTS TO RECONCILE NET INCOME TO NET CASH PROVIDED BY OPERATING ACTIVITIES
Depreciation and amortization	72,240	67,511
Amortization of:
Other regulatory assets and liabilities—net	3,558	3,601
Debt related costs	723	794
Deferred income taxes-net	24,614	36,409
Accrued/deferred pension and other post-retirement benefit cost	1,356	5,490
Compensation expense related to stock-based awards	1,682	6,367
Provision for doubtful accounts	9,526	12,226
Unrealized (gain) loss on derivative contracts	(6,635)	(8,509)
Amortization of investment tax credits	(329)	(358)
Other non-cash charges (credits)—net	677	(571)
Changes in operating assets and liabilities (Note 15)	105,438	175,083
Net Cash From Operating Activities	305,255	394,628
FINANCING ACTIVITIES
Debt issuance costs	(209)	(101)
Notes payable issued (retired)—net	(78,000)	(162,000)
Dividends on common stock and preferred stock	(49,897)	(44,456)
Net Cash From Financing Activities	(128,106)	(206,557)
INVESTING ACTIVITIES
Capital expenditures (excluding AFUDC)	(199,839)	(167,538)
Net Cash From Investing Activities	(199,839)	(167,538)
INCREASE (DECREASE) IN CASH, CASH EQUIVALENTS AND RESTRICTED CASH	(22,690)	20,533
Cash, Cash Equivalents, and Restricted Cash at Beginning of the Period	71,423	6,652
Cash, Cash equivalents and Restricted Cash at End of the Period	$ 48,733	$ 27,185

Accounting Policies

Accounting Policies	6 Months Ended
	Jun. 30, 2019
Accounting Policies [Abstract]
Business Description and Accounting Policies [Text Block]	ACCOUNTING POLICIES Basis of Presentation Washington Gas is an indirect, majority owned subsidiary of, among other entities, AltaGas and WGL. On July 6, 2018, a merger of WGL into AltaGas was consummated (the Merger). In connection with the Merger, WGL, the former parent entity of Washington Gas, formed a wholly owned subsidiary, Wrangler SPE LLC (Wrangler), a bankruptcy remote, special purpose entity to own the common stock of Washington Gas, which survived the Merger as an indirect, wholly owned subsidiary of AltaGas. In addition, WGL owns all of the shares of common stock of Washington Gas Resources Corporation (Washington Gas Resources) and Hampshire Gas Company (Hampshire). Washington Gas Resources owns all of the shares of common stock of four non-utility subsidiaries that include WGL Energy Services, Inc. (WGL Energy Services), WGL Energy Systems, Inc. (WGL Energy Systems), WGL Midstream, Inc. (WGL Midstream) and WGSW, Inc. (WGSW). Additionally, several subsidiaries of WGL own interests in other entities. Except where the content clearly indicates otherwise, any reference in this report to “Washington Gas,” “we,” “our” or the “Company,” refers to Washington Gas Light Company. References to “WGL” refer to WGL Holdings, Inc. and all of its subsidiaries. The condensed financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (SEC). Therefore, certain financial information and note disclosures accompanying annual financial statements prepared in accordance with generally accepted accounting principles in the United States of America (GAAP) are omitted in this interim report. The interim condensed financial statements and accompanying notes should be read in conjunction with the Financial Statements on Form 10-K/T for Washington Gas for the three months ended December 31, 2018. Due to the seasonal nature of our business, the results of operations for the periods presented in this report are not necessarily indicative of actual results for the full years ending December 31, 2019 and 2018. The information presented in this report on Form 10-Q are presented solely for the registrant Washington Gas on a stand-alone basis. The accompanying unaudited condensed financial statements for Washington Gas reflect all normal recurring adjustments that are necessary, in our opinion, to present fairly the results of operations in accordance with GAAP. For a complete description of our accounting policies, refer to Note 1- Accounting Policies of the Notes to Financial Statements of the Form 10-K/T for the three months ended December 31, 2018. Leases Lessee We determine if an arrangement is a lease and the lease classification at inception. For our lessee operating leases, a right-of-use (ROU) asset and a lease liability is recognized at the commencement date based on the present value of lease payments over the lease term. We use the rate implicit in the lease to determine the present value of the lease payments when the rate is readily determinable or we use our incremental borrowing rate. Our ROU assets are adjusted for lease incentives, any lease payments made in advance, and initial direct costs incurred . Lease expenses are recognized on a straight-line basis over the lease term. Our lease terms may include options to extend or terminate the lease when it is reasonably certain that we will exercise that option. For our lessee building and certain equipment leases, we do not separate the lease and non-lease components. For our multiple office location leases classified as operating leases, the lease term begins on the date when construction of the leasehold improvements can start and has allowed us to occupy the respective locations. Leasehold improvement costs are classified as “Property, Plant, and Equipment” on the balance sheet, and are being amortized to “Depreciation and amortization” expense on a straight-line basis over the non-cancelable period of the leases. Lessor We determine if an arrangement is a lease and the lease classification at inception. Lease payments under operating leases are recognized on a straight-line basis over the lease term. For our building leases, we do not separate the lease and non-lease components. Accounting Standards Adopted during the Period and Other Newly Issued Accounting Standards The following tables represent Accounting Standards Updates (ASUs) adopted by Washington Gas during the six months ended June 30, and other newly issued accounting standards that will be adopted by Washington Gas in the future. ACCOUNTING STANDARDS ADOPTED IN CALENDAR YEAR 2019 Standard Description Date of adoption Effect on the financial statements or other significant matters ASU 2016-02, Leases (Topic 842), ASU 2018-01, Land Easement Practical Expedient for Transition to Topic 842, ASU 2018-11, Targeted Improvements, and ASU 2018-20, Narrow-Scope Improvements for Lessors ASU 2016-02 requires recognition of a right-to-use asset and lease liability by lessees on the statement of financial position and disclosure of key information about leasing arrangements. Lessor accounting remains substantially unchanged but the standard modifies what qualifies as a sales-type and direct financing lease and eliminated real-estate specific provisions. The standard requires application using a modified retrospective approach. January 1, 2019 Leases, with terms longer than 12 months, for which Washington Gas is the lessee have been reflected on the balance sheet by recording an increase to non- current assets and an increase to deferred credits net of the current portion that is recorded in current liabilities. Upon adoption, Washington Gas recorded lease liabilities of $58.9 million and a right-of-use asset of $43.2 million, net of lease incentives and prepaid or deferred rent balances of $15.7 million. Washington Gas utilized the transition practical expedients which allow entities to not have to reassess whether an arrangement contains a lease and the lease classification under the provisions of ASC Topic 842, land easements, and not separating out the lease and non-lease components for certain classes of assets. As a result of the transition practical expedients, Washington Gas’ operating leases on transition are consistent with its conclusions under ASC 840. Washington Gas has also elected to present prior comparative information under ASC 840. See Note 3 - Leases for further information and the new required lease disclosures. ASU 2017-12, Derivatives and Hedging (Topic 815): Targeted improvements to Accounting for Hedging Activities and ASU 2018-16, Inclusion of the Secured Overnight Financing Rate (SOFR) Overnight Index Swap (OIS) Rate as a Benchmark Interest Rate for Hedge Accounting Purposes ASU 2017-12 amends the hedge accounting and recognition requirements by expanding an entity’s ability to hedge non-financial and financial risk components and reduce the complexity in fair value hedges of interest rate risk. Additionally, this standard eliminates the requirement to separately measure and disclose the ineffective portion of the hedge with the entire change in the fair value of a hedging instrument to be presented in the same statement of operations line as the hedged item. Early adoption is permitted. ASU 2018-16 adds the OIS rate based on SOFR as a fifth U.S. benchmark interest rate for hedge accounting purposes. This standard should be adopted in conjunction with ASU 2017-12 if not early adopted. January 1, 2019 The guidance will only have an impact on new transactions that are entered into and where hedge accounting is elected. ASU 2018-15, Intangibles-Goodwill and Other-Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract (a consensus of the FASB Emerging Issues Task Force) The update aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements to capitalize implementation costs incurred to develop or obtain internal-use software (and hosting arrangements that include an internal-use software license). Capitalized implementation costs should be presented in the statement of financial position as a prepaid expense and amortized over the term of the hosting arrangement, presented in the statements of operations in the same line items as prepayment of fees associated with the hosting arrangement. The updates in this standard may be applied on a prospective or retrospective basis. Early adoption is permitted. January 1, 2019 We early adopted this standard on a prospective basis. The adoption of this ASU did not have a material effect on our financial statements. OTHER NEWLY ISSUED ACCOUNTING STANDARDS Standard Description Required date of adoption Effect on the financial statements or other significant matters ASU 2016-13, Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments, including other subsequent ASUs clarifying the guidance. For credit losses on financial instruments, this standard changes the current incurred loss impairment methodology to an expected loss methodology and requires consideration of a broader range of reasonable and supportable information to determine credit loss estimates. Early adoption is permitted. January 1, 2020 We are in the process of evaluating the impact the adoption of this standard will have on our financial statements. ASU 2018-13, Fair Value Measurement (Topic 820): Disclosure Framework—Changes to the Disclosure Requirements for Fair Value Measurement This update modifies the disclosure requirements on fair value measurements. Early adoption is permitted. January 1, 2020 It is not expected that the adoption of this standard will have a material effect on our financial statements. ASU 2018-17, Consolidation (Topic 810): Targeted Improvements to Related Party Guidance for Variable Interest Entities This standard provides a private-company scope exception to the VIE guidance for certain entities under common control and clarify that indirect interest held through related parties under common control will be considered on a proportional basis when determining whether fees paid to decision makers and service providers are variable interests. Early adoption is permitted. January 1, 2020 We are in the process of evaluating this new accounting standard but it is expected that the adoption of this standard will not have a material effect on our financial statements. ASU 2019-01, Leases (Topic 842) Codification Improvements This update addresses the determination of the fair value of the underlying asset by lessors that are not manufacturers or dealers, provides guidance for the presentation of the statement of cash flows for sales-type and direct financing leases, and clarifies transition disclosures related to Topic 250. January 1, 2020 We do not anticipate that adoption of this standard will have a material effect on our financial statements. ASU 2018-14, Compensation—Retirement Benefits—Defined Benefit Plans—General (Subtopic 715-20): Disclosure Framework—Changes to the Disclosure Requirements for Defined Benefit Plans This standard modifies the disclosure requirements related to defined benefit pension and other postretirement plans. Early adoption is permitted. December 31, 2020 We do not anticipate that adoption of this standard will have a material effect on our financial statements.

Revenue from Contracts With Cus

Revenue from Contracts With Customers	6 Months Ended
	Jun. 30, 2019
Revenue from Contract with Customer [Abstract]
Revenue from Contracts with Customers	REVENUE FROM CONTRACTS WITH CUSTOMERS The Company adopted ASU 2014-09, Revenue from Contracts with Customers (Accounting Standard Codification (ASC) 606) and subsequent ASUs clarifying the guidance on October 1, 2018, using the modified retrospective method of adoption. Under this approach, prior year results are not required to be restated. Adoption of this standard did not change the timing or pattern of revenue recognition and a cumulative-effect adjustment was not recorded upon adoption. As a result, comparative disclosures for operating results for the three and six months ended June 30, 2019 are not applicable because implementing the new standard did not change the timing or pattern of revenue recognition . The significant impact of adopting this standard are the additional disclosures around the nature, and uncertainty of revenue and cash flows arising from contracts with customers. The Company recognizes revenue from contracts with customers to depict the transfer of goods or services to customers at an amount it expects to be entitled to in exchange for those goods or services. Washington Gas sells natural gas and distribution services to residential, commercial, industrial and governmental customers through regulated tariff rates approved by regulatory commissions in the jurisdictions where it operates (District of Columbia, Maryland, and Virginia) . Customers are billed monthly based on regular meter readings. Customer billings are based on two main components: (i) a fixed service fee and (ii) a variable fee based on usage. For customers who choose to purchase their natural gas from Washington Gas, the bill will include a usage based charge for the cost of the commodity. Revenue is recognized over time as the natural gas is delivered or as the service is performed. As meter readings are performed on a cycle basis, Washington Gas recognizes accrued revenue for any services rendered to its customers but not billed at month-end. The tariff sales are generally considered daily or “at-will” contracts as customers may cancel their service at any time (subject to notification requirements in the tariff), and revenue generally represents the amount Washington Gas is entitled to invoice. There are certain contracts that have terms of one year or longer. For these contracts, revenue is recognized based on the amount Washington Gas is entitled to bill the customer. Customers have the choice to purchase natural gas from competitive service providers. Washington Gas charges the competitive service providers balancing fees to manage the natural gas transportation imbalances. Where regulations require, Washington Gas issues customers a consolidated bill to include the natural gas supplied by the competitive service providers and distribution of natural gas. Washington Gas recognizes revenue only for distribution services that it has provided to the customer, and the balancing fees for the services provided to the competitive service provider. We disaggregate revenue by type of service. The following table disaggregates revenue for the three and six months ended June 30, 2019 . Disaggregated Revenue by Type of Service (In millions) Three Months Ended June 30, 2019 Six Months Ended June 30, 2019 Revenue from contracts with customers Gas and transportation sales Gas sold and delivered $ 132.4 $ 594.4 Gas delivered for others 43.9 153.3 Other 9.9 23.6 Other revenues 1.7 2.8 Total revenue from contracts with customers $ 187.9 $ 774.1 Other sources of revenue Revenue from alternative revenue programs (a) $ 7.2 $ 11.3 Leasing revenue (b) 0.2 0.3 Other 3.2 6.4 Total revenue from other sources 10.6 18.0 Total Operating Revenue $ 198.5 $ 792.1 (a) Washington Gas has determined that its Revenue Normalization Adjustment (RNA), Weather Normalization Adjustment (WNA), and Conservation and Ratemaking Efficiency (CARE) Ratemaking Adjustment (CRA) billing adjustment mechanisms and accelerated pipe replacement programs are alternative revenue programs and accounted for under ASC Topic 980. (b) Revenue generated from Washington Gas lessor operating leases accounted for under ASC Topic 842, Leases. See Note 3-Leases for further information on leases. Washington Gas accrues unbilled revenues for gas delivered, but not yet billed at the end of each accounting period due to our customer billing cycles. “Unbilled revenues” represent performance obligations that have been satisfied and to which Washington Gas has an unconditional right to payment, except for contract assets related to Washington Gas’ area-wide contract, which requires project acceptance by federal government for the right to payment to occur. As of June 30, 2019 , contract assets of $38.0 million have been recorded for financed projects within “Unbilled revenues” on the Condensed Balance Sheets. Washington Gas did not have any contract liabilities at June 30, 2019 . The Company does not have transaction price amounts allocated to future performance obligations. The Company applies the practical expedient available under ASC Topic 606 and does not disclose information about the remaining performance obligations for (i) contracts with an original expected length of one year or less, (ii) contracts for which revenue is recognized at the amount to which the Company has the right to invoice for performance completed, and (iii) contracts with variable consideration that is allocated entirely to a wholly unsatisfied performance obligation or to a wholly unsatisfied promise to transfer a distinct good or service that forms part of a single performance obligation.

Leases

Leases	6 Months Ended
	Jun. 30, 2019
Leases [Abstract]
Lessee and Lessor, Operating Leases	LEASES On January 1, 2019, t he Company adopted ASU 2016-02, Leases (ASC 842) and the following subsequent ASUs which amended the guidance: ASU 2018-01, Land Easement Practical Expedient for Transition to Topic 842, ASU 2018-10, Codification Improvements, and ASU 2018-11, Leases Targeted Improvements, and ASU 2018-20, Narrow-Scope Improvements for Lessors. The new leasing standard requires lessees to recognize a ROU asset and lease liability for leases classified as an operating lease. The significant effects of adopting this standard and the qualitative and quantitative disclosures required to enable users of the financial statements to assess the amount, timing, and uncertainty of cash flows arising from leases are included in Note 1- Accounting Policies and below. Adoption of the new standard had a material impact to our balance sheet but did not have a material impact to our statement of operations. On January 1, 2019, the Company recorded ROU assets of $ 43.2 million (net of lease incentives and prepaid or deferred rent of $ 15.7 million ), current lease liability of $ 2.8 million and non current lease liability of $ 56.1 million related to our operating leases. The Company currently does not have finance leases. We elected to implement the new leasing standard retrospectively at the beginning of the period of adoption through a cumulative-effect adjustment. Under this approach, prior year results are not required to be restated and disclosures associated with prior periods are reported under ASC 840. Lessee Leases The Company elected to use the transition practical expedient which allows an entity not to reassess whether any expired or existing contracts are, or contain, leases; the lease classification for any expired or existing leases; and the initial direct costs for any existing leases. The practical expedient also allows an entity not to reassess whether existing or expired land easements that were not previously accounted for as a lease under Topic 840 was also elected. The Company elected not to separate lease and non-lease components for its building leases and has elected not to record a ROU asset and lease liability for short-term leases. Short-term leases are defined as leases with a term of 12 months or less at the commencement date, including extension options that are reasonably certain of being exercised, and do not include an option to purchase the underlying asset. Short-term lease costs for the period were not material. Washington Gas has operating leases for our corporate headquarters and other corporate offices, communication tower space, and certain office equipment. Our leases have remaining lease terms from 1 to 22 years. Some of the leases include options to extend the lease terms for 1 to 5 years with prior written notice or automatically renew if either party does not provide intent to terminate. The leases generally have options to terminate with notice prior to the end of the lease term based on the contract terms. Refer to Note 13- Related Party Transactions for discussion of leases with associated companies. The following table provides our expected operating lease payments as of June 30, 2019 . Maturity of Operating Lease Liabilities (In millions) June 30, 2019 2019 $ 1.9 2020 5.9 2021 5.5 2022 5.4 2023 5.4 Thereafter 51.9 Total lease payments $ 76.0 Less: Interest (16.0 ) Present Value of Lease Liabilities $ 60.0 The following table provides supplemental cash flow information related to operating leases for the three and six months ended June 30, 2019 . Supplemental Cash Flow Information Related to Operating Leases ($ in millions) Three Months Ended June 30, Six Months Ended June 30, 2019 Cash paid for amounts included in the lease liabilities in the operating cash flows $ 0.5 $ 1.0 Operating lease cost (including variable lease costs of $0.4 million and $1.0 million, respectively) $ 1.7 $ 3.6 Right-of-use assets obtained in exchange for new operating lease liabilities $ 1.1 $ 1.1 At June 30, 2019, the weighted average remaining lease term for operating leases was 13.7 years , and the weighted average discount rate was 3.32% . Lessor Leases The Company also has lessor leases for land, office space and communication tower space that are classified as operating leases. The accounting for these operating leases remained unchanged upon the adoption of ASC 842. Washington Gas has elected not to separate the lease and non-lease components for its building leases. Our leases have remaining lease terms ranging from less than a year to 82 years. Some of the leases include options to extend the lease terms for 1 to 5 years with prior written notice or automatically renew if the lessee does not provide intent not to renew. The leases generally have options to terminate the leases with notice prior to the end of the lease term based on the contract terms. The lease agreements do not contain material residual value guarantees. The following table summarizes the future operating lease payments to be received associated with these leases. Maturity of Operating Lease Payments (a) (In millions) June 30, 2019 2019 $ 0.4 2020 0.7 2021 0.6 2022 0.6 2023 0.6 Thereafter 58.4 Total lease payments $ 61.3 (a) The payments are presented on an undiscounted basis The property, plant and equipment associated with these leases are not material. For information on the lease income recognized during the period, see the Disaggregated Revenue by Type of Service table in Note 2 - Revenue From Contracts with Customers. During the three and six months ended June 30, 2019 , Washington Gas did not record any impairments related to our leased assets.

Accounts Payable and Other Accr

Accounts Payable and Other Accrued Liabilities	6 Months Ended
	Jun. 30, 2019
Accounts Payable and Accrued Liabilities [Abstract]
Accounts Payable and Other Accrued Liabilities	ACCOUNTS PAYABLE AND OTHER ACCRUED LIABILITIES The table below provides details for the amounts included in “Accounts payable and other accrued liabilities” on the balance sheet. (In millions) June 30, 2019 December 31, 2018 Accounts payable—trade $ 153.3 $ 228.9 Employee benefits and payroll accruals 13.6 28.0 Other accrued liabilities 29.7 31.5 Total $ 196.6 $ 288.4

Short-Term Debt

Short-Term Debt	6 Months Ended
	Jun. 30, 2019
Short-term Debt [Abstract]
Short-Term Debt	SHORT-TERM DEBT Washington Gas satisfies short-term financing requirements through the sale of commercial paper, financing arrangements with third-party lenders, or bank borrowings. Due to the seasonal nature of our operations, 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. The policy of Washington Gas 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 June 30, 2019 and December 31, 2018 . Committed Credit Available ($ in millions) June 30, 2019 December 31, 2018 Committed credit agreements Unsecured revolving credit facility, expire December 19, 2019 (a) $ 350.0 $ 350.0 Less: Commercial paper outstanding (218.0 ) (296.0 ) Net committed credit available $ 132.0 $ 54.0 Weighted average interest rate 2.64 % 2.93 % (a) Washington Gas’s revolving credit facility includes the right to request extensions with the bank group’s approval. Washington Gas’ revolving credit facility permits it to increase its borrowing limit by an additional $100 million , with the bank group’s approval, for a total of $450 million . At June 30, 2019 and December 31, 2018 , there were no outstanding bank loans from Washington Gas’ revolving credit facilities. On July 19, 2019, Washington Gas terminated its existing unsecured revolving credit facility and entered into a new, amended senior unsecured revolving credit facility with a term of five years, plus two one-year extension options, with bank group’s approval (Credit Facility). The Credit Facility permits Washington Gas to borrow up to $ 450 million with an option to increase the facility by an additional $ 100 million , with the bank group’s approval, for a total potential maximum borrowing of $ 550 million . The interest rate of loans made under the credit facilities will be a fluctuating rate per annum that will be set using certain parameters at the time each loan is made. The existing $350.0 million credit facility as of June 30, 2019 with the original expiration date of December 19, 2019 was terminated by virtue of entry into the Credit Facility as of July 19, 2019. Project Financing Washington Gas previously obtained third-party project financing on behalf of the federal government to provide funds for the construction of certain energy management services projects entered under Washington Gas’ area-wide contract. Washington Gas recorded a project financing obligation in “Notes payable and project financing” on the balance sheet. As the construction work was performed by WGL Energy Systems, Washington Gas established a contract asset in “Unbilled revenue” representing the government’s obligation to remit principal and interest, and recorded a “Payable to associated company” to WGL Energy Systems for the construction work performed for the same amount. WGL Energy Systems now directly obtains third-party project financing for its energy management services projects. As work is performed, Washington Gas establishes a contract asset in “Unbilled revenue” representing the government’s obligation to remit principal and interest and records a “Payable to associated company” to WGL Energy Systems for the construction work performed for the same amount. As of June 30, 2019 , Washington Gas recorded $ 38.0 million of contract assets in “Unbilled revenues” and a $ 38.0 million payable to WGL Energy Systems in “Payables to associated companies,” respectively, for energy management services projects financed by WGL Energy Systems that were not complete. There was no project financing obligation on Washington Gas’ balance sheet as of June 30, 2019. As of December 31, 2018 , Washington Gas recorded $ 85.3 million of contract assets in “Unbilled revenues,” $ 15.5 million in a corresponding short-term financing to third-party lenders in “Notes payable and project financing,” and $69.7 million accounts payable to WGL Energy Systems in “Payables to associated companies” for energy management services projects that were not complete. In October 2018, WGL Energy Systems repaid $53.0 million drawn by Washington Gas from a third-party lender for a specific project for which the lender demanded repayment due to delays in achieving final acceptance from the federal government agency customer. The $ 53.0 million was included in “Payables to associated companies” on Washington Gas’ balance sheet as of December 31, 2018. On January 16, 2019, the federal government agency customer provided notification of final acceptance as of December 14, 2018. In February 2019, WGL sold the receivables, and accordingly, Washington Gas reversed the associated amount in “Payables to associated companies” and “Unbilled revenue” on its balance sheet. Washington Gas did not record a corresponding reserve for bad debts related to these contract assets at June 30, 2019 and December 31, 2018 , based on our previous collection experience with receivables that have been financed for government agencies with minimal credit risk.

Long-Term Debt

Long-Term Debt	6 Months Ended
	Jun. 30, 2019
Debt Disclosure [Abstract]
Long-Term Debt	LONG-TERM DEBT Unsecured Notes Washington Gas issues long-term debt in the form of medium-term notes (MTNs), unsecured long-term notes and private placement notes, all of which contain individual terms regarding interest rates, maturities and call or put options. Each of these note types can have maturity dates of one or more years from the date of issuance. The following table shows the outstanding notes as of June 30, 2019 and December 31, 2018 . Long-Term Debt Outstanding ($ in millions) June 30, 2019 December 31, 2018 Total Long-Term Debt (a) $ 1,096.0 $ 1,096.0 Unamortized discount (2.9 ) (2.9 ) Unamortized debt expense (8.0 ) (8.1 ) Less—current maturities 50.0 50.0 Total Long-Term Debt $ 1,035.1 $ 1,035.0 Weighted average interest rate (b) 4.77 % 4.77 % (a) Includes MTNs and private placement notes. The amount represents face value of long-term debt including current maturities. (b) Weighted average interest rate is for the long-term debt including current maturities. There were no issuances or retirements of long-term debt for the six months ended June 30, 2019 and 2018 .

Components of Total Equity

Components of Total Equity	6 Months Ended
	Jun. 30, 2019
Components of Total Equity [Abstract]
Components of Total Equity	COMPONENTS OF TOTAL EQUITY The tables below reflect the components of “Total equity” for the three and six months ended June 30, 2019 and 2018 . Components of Total Equity (In thousands, except shares) Common Stock Paid-In Capital Retained Earnings Accumulated Other Comprehensive Income (Loss), Net of Taxes Total Shares Amount Three Months Ended June 30, 2019 Balance at March 31, 2019 46,479,536 46,479 979,273 631,114 (2,362 ) $ 1,654,504 Net loss — — — (20,591 ) — $ (20,591 ) Other comprehensive income (loss) — — — — (3,779 ) $ (3,779 ) Dividends declared: Common stock — — — (25,000 ) — $ (25,000 ) Preferred stock — — — (330 ) — $ (330 ) Balance at June 30, 2019 46,479,536 46,479 979,273 585,193 (6,141 ) 1,604,804 Three Months Ended June 30, 2018 Balance at March 31, 2018 46,479,536 46,479 584,596 756,374 (4,147 ) 1,383,302 Net loss — — — (11,499 ) — $ (11,499 ) Other comprehensive income (loss) — — — — 188 $ 188 Stock-based compensation (a) — — 966 — — $ 966 Dividends declared: Common stock — — — (20,796 ) — $ (20,796 ) Preferred stock — — — (330 ) — $ (330 ) Balance at June 30, 2018 46,479,536 46,479 585,562 723,749 (3,959 ) 1,351,831 Six Months Ended June 30, 2019 Balance at December 31, 2018 46,479,536 46,479 979,273 543,448 (6,627 ) 1,562,573 Net income — — — 92,405 — 92,405 Other comprehensive income (loss) — — — — 486 486 Dividends declared: Common stock — — — (50,000 ) — (50,000 ) Preferred stock — — — (660 ) — (660 ) Balance at June 30, 2019 46,479,536 46,479 979,273 585,193 (6,141 ) 1,604,804 Six Months Ended June 30, 2018 Balance at December 31, 2017 46,479,536 46,479 583,185 670,580 (4,330 ) $ 1,295,914 Net income — — — 96,585 — $ 96,585 Other comprehensive income (loss) — — — — 371 $ 371 Stock-based compensation (a) — — 2,377 — — $ 2,377 Dividends declared: Common stock — — — (42,756 ) — $ (42,756 ) Preferred stock — — — (660 ) — $ (660 ) Balance at June 30, 2018 46,479,536 46,479 585,562 723,749 (3,959 ) 1,351,831 (a) Stock-based compensation is based on the stock awards of WGL that are allocated to Washington Gas Light Company for its pro-rata share and includes implementation of ASU 2016-09.

Income Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2019
Income Tax Disclosure [Abstract]
Income Taxes	INCOME TAXES Washington Gas will be included in the ASUS consolidated income tax returns beginning with the period from July 7, 2018 to December 31, 2018. We have established a new tax sharing policy with ASUS. During the three and six months ended June 30, 2019, Washington Gas did not make or receive any payments to or from its associated companies related to the legacy WGL tax sharing agreement or the new tax sharing agreement. Amounts of Interest and Penalties Recognized Washington Gas recognizes 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 operations. During the three and six months ended June 30, 2019 and 2018, there were no accrued interest expenses or penalties associated with uncertain tax positions.

Pension and Other Post-Retireme

Pension and Other Post-Retirement Benefit Plans	6 Months Ended
	Jun. 30, 2019
Retirement Benefits [Abstract]
Pension and Other Post-Retirement Benefit Plans	PENSION AND OTHER POST-RETIREMENT BENEFIT PLANS The following table shows the components of net periodic benefit costs (income) recognized in our financial statements during the three and six months ended June 30, 2019 and 2018 : Components of Net Periodic Benefit Costs (Income) Three Months Ended June 30, 2019 2018 (In millions) Pension Benefits Health and Life Benefits Pension Benefits Health and Life Benefits Service cost $ 3.1 $ 1.2 $ 3.7 $ 1.3 Interest cost 10.3 3.0 9.9 2.9 Expected return on plan assets (10.7 ) (6.1 ) (10.6 ) (5.9 ) Recognized prior service cost (credit) 0.1 (3.9 ) 0.1 (4.4 ) Recognized actuarial loss 1.4 — 3.9 — Net periodic benefit cost (income) 4.2 (5.8 ) 7.0 (6.1 ) Allocation to affiliates (0.5 ) 0.6 (0.9 ) 0.7 Adjusted net periodic benefit cost (income) 3.7 (5.2 ) 6.1 (5.4 ) Amount allocated to construction projects (b) (0.4 ) (0.2 ) (1.5 ) 1.2 Amount deferred as regulatory asset (liability)-net allocations (c) — — 1.5 — Amount charged (credited) to expense $ 3.3 $ (5.4 ) $ 6.1 $ (4.2 ) Six Months Ended June 30, 2019 2018 Service cost $ 6.1 $ 2.5 $ 7.4 $ 2.6 Interest cost 20.5 6.0 19.8 5.8 Expected return on plan assets (21.4 ) (12.2 ) (21.1 ) (11.8 ) Recognized prior service cost (credit) 0.2 (7.8 ) 0.2 (8.8 ) Recognized actuarial loss 2.7 — 7.8 — Settlement charge (a) 4.3 — — — Net periodic benefit cost (income) 12.4 (11.5 ) 14.1 (12.2 ) Allocation to affiliates (0.9 ) 1.3 (1.7 ) 1.4 Adjusted net periodic benefit cost (income) 11.5 (10.2 ) 12.4 (10.8 ) Amount allocated to construction projects (b) (0.8 ) (0.4 ) (2.6 ) 2.1 Amount deferred as regulatory asset (liability)-net allocations (c) 0.7 — 3.0 — Amount charged (credited) to expense $ 11.4 $ (10.6 ) $ 12.8 $ (8.7 ) (a)Amount relates to a one time partial settlement charge associated with a lump sum payment to Washington Gas’ defined benefit supplemental executive retirement plan (DB SERP) that was paid in the first quarter of 2019. (b)On October 1, 2018, Washington Gas adopted ASU 2017-07. As a result, only the service cost component of net periodic benefit costs (income) is eligible for capitalization. (c)Amount represents the amortization of previously unrecovered costs of the applicable pension benefits or the health and life benefits as approved in the District of Columbia through 2019. At June 30, 2019 and December 31, 2018 , the rabbi trust balance associated with the DB SERP and non-funded defined benefit restoration plan (DB restoration) plans was $ 44.1 million and $ 60.8 million , respectively. $ 4.2 million and $ 20.2 million was recorded in “Current Assets-Other” and $ 39.9 million and $ 40.6 million was recorded in “Deferred Charges and Other Assets - Other” respectively, along with other rabbi trust balances. On October 1, 2018, Washington Gas adopted ASU 2017-07. This standard requires entities to report the service cost component in the same financial statement line item as other compensation costs arising from services rendered by the pertinent employees during the period. The other components of net benefit cost are to be presented separately from service cost and outside of operating income. In addition, only the service cost component of net benefit cost is eligible for capitalization. Changes to the presentation of service costs and other components of net benefit cost were applied retrospectively. As a result of the retrospective adoption, we reclassified $ 2.8 million and $ 5.6 million of net periodic benefit income from “Operation and maintenance” expense to “Other income (expense)-net” on the statement of operations for the three and six months ended June 30, 2018 . Changes in capitalization practices were implemented prospectively.

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2019
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	COMMITMENTS AND CONTINGENCIES Contractual Obligations Washington Gas has 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, and our commitments related to the business process outsourcing program. Reference is made to the “Contractual Obligations, Off-Balance Sheet Arrangements and Other Commercial Commitments” section of Management’s Discussion and Analysis in Washington Gas’ Form 10-K/T. Note 6 to the Financial Statements in Form 10-K/T includes a discussion of long-term debt, including debt maturities. Note 12 to the Financial Statements in Form 10-K/T reflects information about the various contracts of Washington Gas. There were no significant changes to contractual obligations during the six months ended June 30, 2019 . Silver Spring, Maryland Incident On April 23, 2019, the National Transportation and Safety Board (NTSB) held a hearing during which it found, among other things, that the probable cause of the August 10, 2016, explosion and fire at an apartment complex on Arliss Street in Silver Spring, Maryland “was the failure of an indoor mercury service regulator with an unconnected vent line that allowed natural gas into the meter room where it accumulated and ignited from an unknown ignition source. Contributing to the accident was the location of the mercury service regulators where leak detection by odor was not readily available.” Washington Gas disagrees with the NTSB’s probable cause findings. Following this hearing, on June 10, 2019, the NTSB issued an accident report. In connection with the incident, a total of 37 civil actions related to the incident have been filed and are pending against WGL and Washington Gas in the Circuit Court for Montgomery County, Maryland. All cases have been consolidated for discovery purposes. All of these suits seek unspecified damages for personal injury and/or property damage. The trial date for the civil actions has been scheduled for December 2, 2019. Washington Gas maintains excess liability insurance coverage from highly-rated insurers, subject to a nominal self-insured retention. Washington Gas believes that this coverage will be sufficient to cover any significant liability that may result from this incident. Given the early stage of the litigation, the outcome is not yet determinable and management is unable to make an estimate of any potential loss or range of potential losses that are reasonably possible of occurring. As a result, management has not recorded a reserve associated with this incident. Regulatory Contingencies Certain legal and administrative proceedings incidental to our business, including regulatory contingencies, involve Washington Gas. In our opinion, we have recorded an adequate provision for probable losses or refunds to customers for regulatory contingencies related to these proceedings. Merger Commitments In connection with the Merger, AltaGas and WGL made commitments related to the terms of the Public Service Commission of the District of Columbia (PSC of DC) settlement agreement and the conditions of approval from the Public Service Commission of Maryland (PSC of MD) and the State Corporation Commission of Virginia ( SCC of VA). Among other things, these commitments include rate credits distributable to both residential and non-residential customers, gas expansion and other programs, various public interest commitments, and safety programs. The cumulative amount expensed as of June 30, 2019 was $ 136.1 million , of which $ 117.6 million has been paid, including $ 4.2 million and $6.5 million paid in the three and six months ended June 30, 2019 , respectively. In March 2019, the PSC of MD directed that the $ 3.9 million Most Favored Nation adjustment, originally recorded as a commitment expense, should be used to offset future rates under Washington Gas’ natural gas expansion program in Maryland. As a result, Washington Gas reversed the commitment expense in the first quarter of 2019. Further, there are additional regulatory commitments that will be recorded when the costs are incurred in the future, including the hiring of damage prevention trainers in each jurisdiction for a total of $ 2.4 million over 5 years; investing up to $ 70.0 million over a 10 year period to further extend natural gas service; spending $ 8.0 million for leak mitigation within three years of the Merger close; and developing 15 megawatts of either electric grid energy storage or Tier 1 renewable resources within five years. Application for Approval of Reduction of Distribution Rates On January 12, 2018, Washington Gas filed applications to reduce customer rates in Maryland, Virginia, and the District of Columbia to reflect the impact of the Tax Act, including both the impact of the re-measurement of deferred tax assets and liabilities and reduction of the federal tax rate to 21%. Washington Gas began tracking the impact of the Tax Act on revenue requirements beginning January 1, 2018, recording all impacts to regulatory assets and liabilities. In Maryland and the District of Columbia, rates have been adjusted for the impact of the Tax Act. In Virginia, the SCC of VA dismissed the application on March 15, 2018. Washington Gas filed a new general rate case on July 31, 2018 incorporating the effects of the Tax Act, which is still pending (see discussion below). Washington Gas recorded a regulatory liability, representing the amounts owed to Virginia customers for reduced rates between January 1, 2018 and December 30, 2018 of $19.2 million . This liability is amortized over a 5 year period as it is refunded to Virginia customers. At June 30, 2019 , this liability had a balance of $16.8 million . Virginia Jurisdiction Virginia Rate Case. On July 31, 2018, Washington Gas filed an application with the SCC of VA to increase its base rates for natural gas service by $37.6 million , which includes $14.7 million of revenue associated with natural gas pipeline replacement initiatives previously approved by the Commission and paid by customers through a monthly ride r. Additionally, the requested revenue increase incorporates the effects of the Tax Act. On August 23, 2018, the SCC of VA issued an order setting a procedural schedule and appointing a Hearing Examiner. Interim rates became effective, subject to refund, for usage in the January 2019 billing cycle. On February 4, 2019, the Hearing Examiner granted an extension of time for Intervenor and Staff testimonies and Washington Gas rebuttal. On March 13, 2019, the Staff filed its Direct testimony. On April 12, 2019, Washington Gas filed rebuttal testimony and revised its original return on equity down from 10.6% to 10.3% and its overall rate of return down from 7.94% to 7.81% . Evidentiary hearings were held on April 30 and May 1, 2019. Post hearing briefs were filed on July 3, 2019. The case is pending SCC of VA review. Financial Guarantees At June 30, 2019 and December 31, 2018, there were no guarantees to external parties. Antero Contract Washington Gas and WGL Midstream (together, the Companies) contracted in June 2014 with Antero Resources Corporation (Antero) to buy gas from Antero at invoiced prices based on an index, and at a delivery point, specified in the contracts (the “Antero Contract”). Once deliveries began, however, the index price paid was more than the fair market value at the same physical delivery point, resulting in losses to the Companies. Accordingly, the Companies notified Antero that they sought to apply a contract provision that would permit the establishment of a new index. Antero objected. The dispute was arbitrated in January 2017, and the arbitral tribunal ruled in favor of Antero on the applicability of the re-pricing mechanism but found that it lacked authority to determine whether Antero was in breach of its obligation to deliver gas to the Companies at a point where a higher price could be obtained. The Companies filed suit in state court in Colorado for a determination of that issue. Separately, Antero initiated suit against the Companies, claiming that those entities failed to purchase specified daily quantities of gas. These two cases were consolidated and a jury trial was held in June 2019 in the County Court for Denver, Colorado. Following the trial, the jury returned a verdict in favor of Antero for $95.9 million , of which $11.2 million was against Washington Gas, and $84.7 million against WGL Midstream. Once the judgment is officially entered, the Companies would have 49 days to file a Notice of Appeal under Colorado rules, provided the Companies file a supersedeas bond within 14 days of the judgment entry. The Companies are considering their option to appeal. As a result of this verdict, it was determined that a loss contingency is probable and Washington Gas has recorded an estimated liability of $ 11.2 million in “Accounts payable and accrued liabilities” on the balance sheet as of June 30, 2019, of which $ 2.6 million had already been recorded in a prior period. Washington Gas has also recorded a receivable from our trading partner of $ 1.3 million net in “Accounts payable and accrued liabilities” and sharing with customers as the contract relates to asset optimization of $ 4.5 million in “Deferred charges and other assets - Gas costs”. In addition, Washington Gas has recorded an accrual for estimated court fees of $ 0.2 million . For the three months ending June 30, 2019, the net pre-tax loss recorded as a result of the verdict was $ 3.0 million , of which $ 2.8 million was recorded in “Utility cost of gas” and $ 0.2 million was recorded in “Operations and maintenance” on Washington Gas’ statements of operations. 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 manufactured gas plants (MGPs). 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. At June 30, 2019 and December 31, 2018 , Washington Gas reported a liability of $ 11.6 million and $ 11.3 million on an undiscounted basis related to future environmental response costs. These estimates principally include the minimum liabilities associated with a range of environmental response costs expected to be incurred. At June 30, 2019 and December 31, 2018 , Washington Gas estimated the maximum liability associated with all of its sites to be approximately $35.6 million and $ 29.4 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 and the extent of remediation that may be required. Washington Gas is currently remediating its East Station property, which is adjacent to the Anacostia River, including ground water pump and treat, tar recovery, soil encapsulation and other treatment. Washington Gas is conducting a remedial investigation and feasibility study under a 2012 consent decree with the District of Columbia and the federal government and additional remediation may be required. In addition, manufactured gas waste was discovered at an adjoining property adjacent to East Station. Washington Gas has agreed to work with the owners of the adjoining property to perform a site investigation, ground water sampling, and report on the contamination at the site pursuant to oversight by the District of Columbia Department of Energy and Environment (DOEE). On July 12, 2019, Washington Gas received an Administrative Order from the DOEE requesting certain steps towards preparing and submitting a remedial investigation report and a feasibility study regarding potential actions associated with the adjoining property. Washington Gas is reviewing the Administrative Order and preparing potential workplans to address the items contained within. Washington Gas received a letter in February 2016 from the DOEE and National Park Service regarding the Anacostia River Sediment Project, indicating that the District of Columbia is conducting a separate remedial investigation and feasibility study of the river to determine if and what cleanup measures may be required and to prepare a natural resource damage assessment. The sediment project draft remedial investigation report issued on March 30, 2018 identifies East Station as one of seventeen potential environmental cleanup sites. We are not able to estimate the total amount of potential damages or timing associated with the District of Columbia’s environmental investigation on the Anacostia River at this time. While an allocation method has not been established, Washington Gas has accrued an amount for study costs based on a potential range of estimates. 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 June 30, 2019 and December 31, 2018 , Washington Gas reported a regulatory asset of $ 6.4 million and $ 5.8 million for the portion of environmental response costs that are expected to be recoverable in future rates. For further information on our Environmental activities refer to Note 11 - Environmental Matters in Washington Gas’ 10-K/T for the three months ended December 31, 2018.

Derivative and Weather Related

Derivative and Weather Related Instruments	6 Months Ended
	Jun. 30, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative and Weather-Related Instruments	DERIVATIVES Derivative Instruments Washington Gas enters into contracts 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 currently 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 utilizes 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 securing operating margins that Washington Gas will ultimately realize. The derivative transactions entered into under this program are subject to mark-to-market accounting treatment under ASC Topic 820. Regulatory sharing mechanisms provide for the annual realized profit from these transactions to be shared between Washington Gas’ shareholders and customers; therefore, changes in fair value are recorded through earnings, or as regulatory assets or liabilities to the extent that it is probable that realized gains and losses associated with these derivative transactions will be included in the rates charged to customers when they are realized. Unrealized gains and losses recorded to earnings may cause significant period-to-period volatility; this volatility does not change the 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 operations 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 three months ended June 30, 2019 was a net gain of $1.3 million including an unrealized loss of $0.5 million and a loss related to the Antero Contract of $2.8 million . During the three months ended June 30, 2018 , we recorded a net gain of $1.9 million including an unrealized loss of $3.8 million . Total net margins recorded to “Utility cost of gas” after sharing and management fees associated with all asset optimization transactions for the six months ended June 30, 2019 was a net gain of $9.5 million including an unrealized gain of $6.6 million and a $2.8 million loss related to the Antero Contract. During the six months ended June 30, 2018 , we recorded a net gain of $20.7 million including an unrealized gain of $8.5 million . Refer to Note 10- Commitments and Contingencies for further discussion of the Antero Contract. Managing Price Risk. To manage price risk associated with acquiring natural gas supply for utility customers, Washington Gas enters into physical and financial derivative transactions in the form of forward, option and other contracts, as authorized by its regulators. 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 may utilize 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 related debt. As of June 30, 2019 and December 31, 2018 , Washington Gas does not have any interest rate swaps in derivatives. Operations The following table presents the balance sheet classification for all derivative instruments as of June 30, 2019 and December 31, 2018 . Absolute Notional Amounts of Open Positions on Derivative Instruments Notional Amounts June 30, 2019 December 31, 2018 Natural Gas (In millions of therms) Asset optimization & trading 12,233.0 13,051.0 Other risk-management activities 974.0 1,072.0 The following table presents the balance sheet classification for all derivative instruments as of June 30, 2019 and December 31, 2018 . Balance Sheet Classification of Derivative Instruments (b) (in millions) Gross Gross Total (a) As of June 30, 2019 Current Assets—Derivatives $ 5.5 $ (1.4 ) $ 4.1 Deferred Charges and Other Assets—Derivatives 10.3 — 10.3 Current Liabilities—Derivatives — (8.2 ) (8.2 ) Deferred Credits—Derivatives 1.1 (94.5 ) (93.4 ) Total $ 16.9 $ (104.1 ) $ (87.2 ) As of December 31, 2018 Current Assets—Derivatives $ 25.7 $ (6.2 ) $ 19.5 Deferred Charges and Other Assets—Derivatives 11.3 — 11.3 Current Liabilities—Derivatives 1.1 (21.4 ) (20.3 ) Deferred Credits—Derivatives — (116.8 ) (116.8 ) Total $ 38.1 $ (144.4 ) $ (106.3 ) (a) Washington Gas 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 Topic 815. All recognized derivative contracts and associated financial collateral subject to a master netting arrangement or similar that is eligible for offset under ASC Topic 815 have been presented net in the balance sheet. (b) Washington Gas did not have derivative instruments outstanding that were designated as hedging instruments at June 30, 2019 or December 31, 2018 . The following table presents all gains and losses associated with derivative instruments for the three and six months ended June 30, 2019 and 2018 . Washington Gas Light Company Gains and (Losses) on Derivative Instruments (In millions) Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Recorded to income Utility cost of gas 1.7 (4.5 ) 5.7 (1.5 ) Recorded to regulatory assets Gas costs 2.5 (9.0 ) 14.4 (5.5 ) Total $ 4.2 $ (13.5 ) $ 20.1 $ (7.0 ) Collateral Washington Gas 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 parent company 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 Washington Gas’ 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. Any collateral posted that is not offset against derivative assets and liabilities is included in “Other prepayments” in the condensed balance sheet. Collateral received and not offset against derivative assets and liabilities is included in “Customer deposits and advance payments” in the accompanying balance sheet. At June 30, 2019 and December 31, 2018 , Washington Gas had $4.8 million and $7.4 million , respectively, in collateral deposits posted with counterparties that are not offset against derivative asset and liabilities. At June 30, 2019 and December 31, 2018 , Washington Gas had $0.1 million and $0.2 million , respectively, cash collateral held representing an obligation, and are not offset against derivative asset and liabilities. Certain derivative instruments of Washington Gas contain contract provisions that require collateral to be posted if the credit rating of Washington Gas falls below certain levels or if counterparty exposure to Washington Gas exceeds a certain level (credit-related contingent features) . At June 30, 2019 and December 31, 2018 , Washington Gas was not required to post collateral related to a derivative liability that contained a credit-related contingent feature. 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 June 30, 2019 and December 31, 2018 , respectively. Potential Collateral Requirements for Derivative Liabilities with Credit-Risk-Contingent Features (In millions) June 30, 2019 December 31, 2018 Derivative liabilities with credit-risk-contingent features $ — $ 1.1 Maximum potential collateral requirements — 1.0 We 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 June 30, 2019 , three counterparties each represented over 10% of Washington Gas’ credit exposure to wholesale derivative counterparties for a total credit risk of $21.8 million .

Fair Value Measurements

Fair Value Measurements	6 Months Ended
	Jun. 30, 2019
Fair Value Disclosures [Abstract]
Fair Value Measurements	FAIR VALUE MEASUREMENTS We measure the fair value of our financial assets and liabilities using a combination of the income and market approaches in accordance with ASC Topic 820. These financial assets and liabilities primarily consist of derivatives recorded on our balance sheet under ASC Topic 815 and 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 Washington Gas. 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. Washington Gas did not have any Level 1 derivatives at June 30, 2019 or December 31, 2018 . 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 June 30, 2019 and December 31, 2018 , Level 2 financial assets and liabilities included energy-related physical and financial derivative transactions such as forward, option and other 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 and annualized volatilities of natural gas 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 Washington Gas’ Chief Financial Officer. In accordance with Washington Gas valuation policy, we may utilize a variety of valuation methodologies to determine the fair value of 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 June 30, 2019 and December 31, 2018 , 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 majority of the life of the contract; (iii) contracts valued using historical spot price volatility assumptions and (iv) valuations using indicative broker quotes for inactive market locations. The following table sets forth financial instruments recorded at fair value as of June 30, 2019 and December 31, 2018 , 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. Fair Value Measurements Under the Fair Value Hierarchy (In millions) Level 1 Level 2 Level 3 Total At June 30, 2019 Assets Natural gas related derivatives $ — $ 1.4 $ 15.5 $ 16.9 Total Assets $ — $ 1.4 $ 15.5 $ 16.9 Liabilities Natural gas related derivatives $ — $ (1.7 ) $ (102.4 ) $ (104.1 ) Total Liabilities $ — $ (1.7 ) $ (102.4 ) $ (104.1 ) At December 31, 2018 Assets Natural gas related derivatives $ — $ 9.8 $ 28.3 $ 38.1 Total Assets $ — $ 9.8 $ 28.3 $ 38.1 Liabilities Natural gas related derivatives $ — $ (9.5 ) $ (134.9 ) $ (144.4 ) Total Liabilities $ — $ (9.5 ) $ (134.9 ) $ (144.4 ) 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 June 30, 2019 and December 31, 2018 . Quantitative Information about Level 3 Fair Value Measurements (In millions) Net Fair Value Valuation Techniques Unobservable Inputs Range Natural gas related derivatives ($86.9) Discounted Cash Flow Natural Gas Basis Price (per dekatherm) ($0.878) - $2.665 Net Fair Value Natural gas related derivatives ($106.6) Discounted Cash Flow Natural Gas Basis Price ($1.028)-$5.34 The following table presents 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 three and six months ended June 30, 2019 and 2018, respectively. Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs (In millions) Total - Natural Gas Three Months Ended June 30, 2019 Balance at April 1, 2019 $ (86.1 ) Realized and unrealized gains (losses) Recorded to income 1.2 Recorded to regulatory assets—gas costs 1.9 Settlements (3.9 ) Balance at June 30, 2019 $ (86.9 ) Three Months Ended June 30, 2018 Balance at April 1, 2018 $ (89.0 ) Realized and unrealized gains (losses) Recorded to income (3.5 ) Recorded to regulatory assets—gas costs (7.6 ) Transfers into Level 3 (7.0 ) Settlements 3.5 Balance at June 30, 2018 $ (103.6 ) Six Months Ended June 30, 2019 Balance at January 1, 2019 $ (106.6 ) Realized and unrealized gains (losses) Recorded to income 4.8 Recorded to regulatory assets—gas costs 14.4 Transfers into Level 3 (3.8 ) Transfers out of Level 3 5.0 Settlements (0.7 ) Balance at June 30, 2019 $ (86.9 ) Six Months Ended June 30, 2018 Balance at January 1, 2018 $ (125.4 ) Realized and unrealized gains (losses) Recorded to income (4.2 ) Recorded to regulatory assets—gas costs (8.7 ) Transfers into Level 3 (7.0 ) Transfers out of Level 3 9.0 Settlements 32.7 Balance at June 30, 2018 $ (103.6 ) Transfers between different levels of the fair value hierarchy may occur based on fluctuations in the valuation inputs and 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 period. Transfers out of Level 3 during the three and six months ended June 30, 2019 and 2018 were due to valuations that experienced an increase in observable market inputs. Transfers into Level 3 during the three and six months ended June 30, 2019 and 2018 were due to an increase in unobservable market inputs, primarily pricing points. The table below sets forth the line items on the statements of operations to which amounts are recorded for the three and six months ended June 30, 2019 and 2018, respectively, related to fair value measurements using significant Level 3 inputs. Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements (In millions) Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Utility cost of gas $1.2 $(3.5) $4.8 $(4.2) Unrealized gains (losses) attributable to derivative assets and liabilities measured using significant Level 3 inputs were recorded as follows for the three and six months ended June 30, 2019 and 2018, respectively. Unrealized Gains (Losses) Recorded for Level 3 Measurements (In millions) Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Recorded to income Utility cost of gas $ 4.4 $ (5.9 ) $ 8.1 $ 3.3 Recorded to regulatory assets—gas costs 6.5 (9.9 ) 19.1 2.1 Total $ 10.9 $ (15.8 ) $ 27.2 $ 5.4 The following table presents the carrying amounts recorded at amortized cost and estimated fair values of our financial instruments at June 30, 2019 and December 31, 2018 . Fair Value of Financial Instruments June 30, 2019 December 31, 2018 (In millions) Carrying Amount Fair Value Carrying Amount Fair Value Money market funds (a) $ 49.6 $ 49.6 $ 69.7 $ 69.7 Commercial paper (b) $ 218.0 $ 218.0 $ 296.0 $ 296.0 Project financing (b) $ — $ — $ 15.5 $ 15.5 Current maturities of long-term debt $ 50.0 $ 50.0 $ 50.0 $ 50.0 Long-term debt (c) $ 1,035.1 $ 1,184.7 $ 1,035.0 $ 1,096.3 (a) The balance as of June 30, 2019 includes $0.9 million money market funds located in “Cash and cash equivalents,” $4.2 million rabbi trust investment located in “Current Assets-Other,” and $44.5 million rabbi trust investments located in “Deferred Charges and Other Assets-Other” of the accompanying balance sheet; The balance as of December 31, 2018 includes $4.4 million money market funds located in “Cash and cash equivalents,” $ 20.2 million rabbi trust investment located in “Current Assets-Other” and $45.1 million rabbi trust investments located in “Deferred Charges and Other Assets-Other.” The amounts in cash and cash equivalent may be offset by outstanding checks. (b) Balance is located in “Notes payable and project financing” in the accompanying balance sheet. (c) Includes adjustments for current maturities and unamortized discounts, as applicable. Our money market funds are Level 1 valuations and their carrying amount approximates fair value. The maturity of our commercial paper outstanding at both June 30, 2019 and December 31, 2018 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. Due to the nature of our project financing arrangements, the carrying cost approximates fair value using Level 2 inputs. Due to the short term nature of current maturities of long-term debt, the carrying cost 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 valuation techniques when observable market data is not available. Our long-term debt fair value measurement is classified as Level 3.

Related Party Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2019
Related Party Transactions [Abstract]
Related Party Transactions	RELATED PARTY TRANSACTIONS Corporate Service Allocation As a subsidiary of AltaGas and effective with the close of the Merger on July 6, 2018, Washington Gas is charged a proportionate share of corporate governance and other shared services costs from AltaGas, primarily related to human resources, employee benefits, finance, legal, accounting, tax, information technology services, and office services. AltaGas charges Washington Gas for the total shared service costs attributable to WGL and its affiliates and Washington Gas in turn allocates a portion of the costs to WGL’s other subsidiaries based on methodologies further described below. Washington Gas records a payable of the total shared service costs allocated to all WGL’s subsidiaries in “Payable to associated companies” and a receivable of the shared service costs allocated to WGL’s other subsidiaries in “Receivables from associated companies” on the balance sheet. As of June 30, 2019 , WGL recorded a $ 10.3 million liability to “Payables to associated companies,” reflecting Washington Gas’ unpaid shared service cost payable to AltaGas, and a receivable of $ 2.9 million to “Receivables from associated companies” on the balance sheet related to the shared service costs allocated to WGL’s subsidiaries. The net expenses of $ 3.0 million and $ 7.4 million were included in “Operation and maintenance” on the statements of operations for the three and six months ended June 30, 2019 , respectively, reflecting the shared service cost allocated to Washington Gas. As of December 31, 2018 , Washington Gas recorded a receivable of $ 0.6 million to “Receivables from associated companies” on the balance sheet related to the shared service costs allocated to WGL’s subsidiaries. There was no payable balance related to the shared service cost payable to AltaGas as of December 31, 2018 . In addition, Washington Gas provides accounting, treasury, legal and other administrative and general support to WGL’s subsidiaries, and files consolidated tax returns that include affiliated taxable transactions. Effective upon the approvals by the SCC of Virginia and beginning in January 2019 and June 2019, Washington Gas also provides accounting, legal, tax and other administrative and general support to various AltaGas U.S. entities and AltaGas. Washington Gas bills affiliates to which it provides services in accordance with regulatory requirements for the actual cost of providing these services, which approximates their market value. To the extent such billings are outstanding, they are reflected in “Receivables from associated companies” on Washington Gas’ balance sheet. Washington Gas assigns or allocates these costs directly to its affiliates and, therefore, does not recognize revenues or expenses associated with providing these services. Washington Gas believes that allocations based on broad measures of business activity are appropriate for allocating expenses resulting from common services. Affiliate entities are allocated a portion of common services based on a formula driven by appropriate indicators of activity, as approved by management. Project Financing Washington Gas previously obtained third-party project financing on behalf of the federal government to provide funds during the construction of certain energy management services projects entered into under Washington Gas’ area-wide contract. Washington Gas recorded a contract asset in “Unbilled revenues” representing the government’s obligation and an account payable to WGL Energy Systems in “Payable to associated companies” for the construction work performed for the same amount. Refer to Note 5- Short Term Debt of the Notes to Condensed Financial Statements for further discussions of the project financing. Related Party Transactions with Hampshire 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 and records the cost of the services in “Operation and maintenance” in its statements of operations. Hampshire operates under a “pass-through” cost of service-based tariff approved by the Federal Energy Regulatory Commission ( 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. The arrangement between Hampshire and Washington Gas is classified as an operating lease. An ROU asset and lease liability was not recognized upon the adoption of ASC 842 because all the costs associated with the arrangement are variable. Washington Gas recorded expenses related to the cost of services provided by Hampshire in Washington Gas’ statements of operations of $ 1.9 million and $ 4.0 million for the three and six months ended in June 30, 2019, and $ 1.8 million and $ 3.4 million for the three and six months ended in June 30, 2018, respectively. The outstanding balance not cleared between Washington Gas and Hampshire at the end of the reporting period was recorded in “Receivables from associated companies” on Washington Gas’ balance sheet. Refer to Note 3- Leases for further discussion of ASC 842. Other Related Party Transactions In connection with billing for unregulated third-party marketers, including WGL Energy Services 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 sheet. 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 WGL Energy Services. Washington Gas records revenues for these balancing services pursuant to tariffs approved by the appropriate regulatory bodies. The following table shows the amounts Washington Gas charged WGL Energy Services for balancing services. Gas Balancing Service Charges Three Months Ended Six Months Ended (In millions) 2019 2018 2019 2018 Gas balancing service charge $ 3.1 $ 4.3 $ 12.0 $ 12.8 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. Washington Gas recorded a $0.1 million payable, and $0.7 million receivable, from WGL Energy Services, at June 30, 2019 and December 31, 2018 , respectively, related to an imbalance in gas volumes. The receivable and payable are recorded in “Account receivable” and “Account payable and other accrued liabilities” on Washington Gas’ balance sheet. Refer to Note 1— Accounting Policies of the Notes to Financial Statements on Form 10-K/T for the three months ended December 31, 2018 for further discussion of these imbalance transactions. Washington Gas participates in a purchase of receivables (POR) program as approved by the PSC of MD and the PSC of DC, whereby it purchases receivables from participating energy marketers, including WGL Energy Services, at approved discount rates. Washington Gas implemented the POR program in the District of Columbia beginning in January 2019. The receivables purchased by Washington Gas are included in “Accounts receivable” in the accompanying balance sheet. At June 30, 2019 and December 31, 2018 , Washington Gas had balances of $4.6 million and $ 6.4 million , respectively, of purchased receivables from WGL Energy Services. Refer to Note 8- Income Taxes of the Notes to Condensed Financial Statements for discussions of related party income taxes.

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income (Loss)	6 Months Ended
	Jun. 30, 2019
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Accumulated Other Comprehensive Income (Loss)	ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) The following table shows the changes in accumulated other comprehensive income (loss) by component for three and six months ended June 30, 2019 and 2018 . Changes in Accumulated Other Comprehensive Income (Loss) by Component Three Months Ended June 30, Six Months Ended June 30, (In thousands) 2019 2018 2019 2018 Beginning Balance $ (2,362 ) $ (4,147 ) $ (6,627 ) $ (4,330 ) Change in prior service cost (a) (161 ) (273 ) (323 ) (546 ) Change in actuarial gain (loss) (a) (2,848 ) 530 2,056 1,060 Current-period other comprehensive income (loss) (3,009 ) 257 1,733 514 Income tax expense related to other comprehensive income 770 69 1,247 143 Ending Balance $ (6,141 ) $ (3,959 ) $ (6,141 ) $ (3,959 ) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic benefit cost. Refer to Note 9—Pension and other post-retirement benefit plans for additional details.

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	6 Months Ended
	Jun. 30, 2019
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information	SUPPLEMENTAL CASH FLOW INFORMATION The following table details the changes in operating assets and liabilities from operating activities, cash payments that have been included in the determination of earnings and non-cash investing and financing activities. Six Months Ended June 30, Six Months Ended June 30, (In thousands) 2019 2018 CHANGES IN OPERATING ASSETS AND LIABILITIES Accounts receivable and unbilled revenues $ 141,473 $ 128,596 Receivables from associated companies (1,078 ) (6,559 ) Gas costs and other regulatory assets/liabilities—net (32,789 ) (7,403 ) Storage gas 37,700 30,283 Prepaid taxes 2,972 8,895 Accounts payable and other accrued liabilities (86,061 ) (8,974 ) Payables to associated companies (1,384 ) 1,744 Customer deposits and advance payments (17,868 ) 9,358 Accrued taxes (400 ) (23,796 ) Other current assets 4,796 2,575 Other current liabilities (243 ) (244 ) Deferred gas costs—net 68,477 52,235 Deferred assets—other 9,989 (1,435 ) Deferred liabilities—other (6,900 ) (10,772 ) Pension and other post-retirement benefits (13,246 ) (984 ) Other—net — 1,564 Changes in operating assets and liabilities $ 105,438 $ 175,083 SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION Income taxes paid (refunded)—net $ (1,682 ) $ — Interest paid $ 28,890 $ 28,084 SUPPLEMENTAL DISCLOSURES OF NON-CASH INVESTING AND FINANCING ACTIVITIES: Extinguishment of project debt financing $ (15,460 ) $ (28,312 ) Capital expenditure accruals included in accounts payable and other accrued liabilities $ 42,161 $ 26,472 The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within Washington Gas’ balance sheet that sums to the total of such amounts shown on the statements of cash flows. (in thousands) June 30, 2019 June 30, 2018 Cash and cash equivalents $ — $ 27,185 Restricted cash included in Current Assets-Other $ 4,225 $ — Restricted cash included in Deferred Charges and Other Assets-Other $ 44,508 $ — Total cash, cash equivalents and restricted cash shown in the statement of cash flows $ 48,733 $ 27,185 Restricted cash included in “Current assets—Other” and “Deferred charges and other assets—Other” on the balance sheet represents amount of investment in rabbi trusts to fund deferred compensation, pension and other post-retirement benefits for certain management personnel and directors. The funds in the rabbi trusts can only be used to pay for plan participant benefits and other plan expenses such as investment fees or trustee fees. The funds are invested in money market funds as of June 30, 2019 . We did not have any restricted cash as of June 30, 2018 . Refer to Note 9-Pension and Other Post-Retirement Benefit Plans for further discussion of rabbi trusts.

Accounting Policies (Policies)

Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2019
Accounting Policies [Abstract]
Consolidation	Washington Gas is an indirect, majority owned subsidiary of, among other entities, AltaGas and WGL. On July 6, 2018, a merger of WGL into AltaGas was consummated (the Merger). In connection with the Merger, WGL, the former parent entity of Washington Gas, formed a wholly owned subsidiary, Wrangler SPE LLC (Wrangler), a bankruptcy remote, special purpose entity to own the common stock of Washington Gas, which survived the Merger as an indirect, wholly owned subsidiary of AltaGas. In addition, WGL owns all of the shares of common stock of Washington Gas Resources Corporation (Washington Gas Resources) and Hampshire Gas Company (Hampshire). Washington Gas Resources owns all of the shares of common stock of four non-utility subsidiaries that include WGL Energy Services, Inc. (WGL Energy Services), WGL Energy Systems, Inc. (WGL Energy Systems), WGL Midstream, Inc. (WGL Midstream) and WGSW, Inc. (WGSW). Additionally, several subsidiaries of WGL own interests in other entities.
Basis of Accounting, Policy	The condensed financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (SEC). Therefore, certain financial information and note disclosures accompanying annual financial statements prepared in accordance with generally accepted accounting principles in the United States of America (GAAP) are omitted in this interim report.
Operating Leases	For our multiple office location leases classified as operating leases, the lease term begins on the date when construction of the leasehold improvements can start and has allowed us to occupy the respective locations. Leasehold improvement costs are classified as “Property, Plant, and Equipment” on the balance sheet, and are being amortized to “Depreciation and amortization” expense on a straight-line basis over the non-cancelable period of the leases. We determine if an arrangement is a lease and the lease classification at inception. Lease payments under operating leases are recognized on a straight-line basis over the lease term. For our building leases, we do not separate the lease and non-lease components.
Accounting Standards Adopted Current Fiscal Year [Policy Text Block]	ACCOUNTING STANDARDS ADOPTED IN CALENDAR YEAR ASU 2016-02, Leases (Topic 842), ASU 2018-01, Land Easement Practical Expedient for Transition to Topic 842, ASU 2018-11, Targeted Improvements, and ASU 2018-20, Narrow-Scope Improvements for Lessors ASU 2016-02 requires recognition of a right-to-use asset and lease liability by lessees on the statement of financial position and disclosure of key information about leasing arrangements. Lessor accounting remains substantially unchanged but the standard modifies what qualifies as a sales-type and direct financing lease and eliminated real-estate specific provisions. The standard requires application using a modified retrospective approach. January 1, 2019 Leases, with terms longer than 12 months, for which Washington Gas is the lessee have been reflected on the balance sheet by recording an increase to non- current assets and an increase to deferred credits net of the current portion that is recorded in current liabilities. Upon adoption, Washington Gas recorded lease liabilities of $58.9 million and a right-of-use asset of $43.2 million, net of lease incentives and prepaid or deferred rent balances of $15.7 million. Washington Gas utilized the transition practical expedients which allow entities to not have to reassess whether an arrangement contains a lease and the lease classification under the provisions of ASC Topic 842, land easements, and not separating out the lease and non-lease components for certain classes of assets. As a result of the transition practical expedients, Washington Gas’ operating leases on transition are consistent with its conclusions under ASC 840. Washington Gas has also elected to present prior comparative information under ASC 840. See Note 3 - Leases for further information and the new required lease disclosures. ______________________________________________________________________________________________________ ASU 2017-12, Derivatives and Hedging (Topic 815): Targeted improvements to Accounting for Hedging Activities and ASU 2018-16, Inclusion of the Secured Overnight Financing Rate (SOFR) Overnight Index Swap (OIS) Rate as a Benchmark Interest Rate for Hedge Accounting Purposes ASU 2017-12 amends the hedge accounting and recognition requirements by expanding an entity’s ability to hedge non-financial and financial risk components and reduce the complexity in fair value hedges of interest rate risk. Additionally, this standard eliminates the requirement to separately measure and disclose the ineffective portion of the hedge with the entire change in the fair value of a hedging instrument to be presented in the same statement of operations line as the hedged item. Early adoption is permitted. January 1, 2019 The guidance will only have an impact on new transactions that are entered into and where hedge accounting is elected. ____________________________________________________________________________________________________ ASU 2018-15, Intangibles-Goodwill and Other-Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract (a consensus of the FASB Emerging Issues Task Force) The update aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements to capitalize implementation costs incurred to develop or obtain internal-use software (and hosting arrangements that include an internal-use software license). Capitalized implementation costs should be presented in the statement of financial position as a prepaid expense and amortized over the term of the hosting arrangement, presented in the statements of operations in the same line items as prepayment of fees associated with the hosting arrangement. The updates in this standard may be applied on a prospective or retrospective basis. Early adoption is permitted. January 1, 2019 We early adopted this standard on a prospective basis. The adoption of this ASU did not have a material effect on our financial statements. ______________________________________________________________________________________________________
New Accounting Pronouncements, Policy [Policy Text Block]	OTHER NEWLY ISSUED ACCOUNTING STANDARDS ASU 2016-13, Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments, including other subsequent ASUs clarifying the guidance. For credit losses on financial instruments, this standard changes the current incurred loss impairment methodology to an expected loss methodology and requires consideration of a broader range of reasonable and supportable information to determine credit loss estimates. Early adoption is permitted. January 1, 2020 We are in the process of evaluating the impact the adoption of this standard will have on our financial statements. _____________________________________________________________________________________________________ ASU 2018-13, Fair Value Measurement (Topic 820): Disclosure Framework—Changes to the Disclosure Requirements for Fair Value Measurement This update modifies the disclosure requirements on fair value measurements. Early adoption is permitted. January 1, 2020 It is not expected that the adoption of this standard will have a material effect on our financial statements. _____________________________________________________________________________________________________ ASU 2018-17, Consolidation (Topic 810): Targeted Improvements to Related Party Guidance for Variable Interest Entities This standard provides a private-company scope exception to the VIE guidance for certain entities under common control and clarify that indirect interest held through related parties under common control will be considered on a proportional basis when determining whether fees paid to decision makers and service providers are variable interests. Early adoption is permitted. January 1, 2020 We are in the process of evaluating this new accounting standard but it is expected that the adoption of this standard will not have a material effect on our financial statements. ______________________________________________________________________________________________________ ASU 2019-01, Leases (Topic 842) Codification Improvements This update addresses the determination of the fair value of the underlying asset by lessors that are not manufacturers or dealers, provides guidance for the presentation of the statement of cash flows for sales-type and direct financing leases, and clarifies transition disclosures related to Topic 250. January 1, 2020 We do not anticipate that adoption of this standard will have a material effect on our financial statements. ______________________________________________________________________________________________________ ASU 2018-14, Compensation—Retirement Benefits—Defined Benefit Plans—General (Subtopic 715-20): Disclosure Framework—Changes to the Disclosure Requirements for Defined Benefit Plans This standard modifies the disclosure requirements related to defined benefit pension and other postretirement plans. Early adoption is permitted. December 31, 2020 We do not anticipate that adoption of this standard will have a material effect on our financial statements. ______________________________________________________________________________________________________

Revenue from Contracts With C_2

Revenue from Contracts With Customers (Policies)	6 Months Ended
	Jun. 30, 2019
Revenue from Contract with Customer [Abstract]
Revenue from Contracts with Customers	Customer billings are based on two main components: (i) a fixed service fee and (ii) a variable fee based on usage. For customers who choose to purchase their natural gas from Washington Gas, the bill will include a usage based charge for the cost of the commodity. Revenue is recognized over time as the natural gas is delivered or as the service is performed. As meter readings are performed on a cycle basis, Washington Gas recognizes accrued revenue for any services rendered to its customers but not billed at month-end. The tariff sales are generally considered daily or “at-will” contracts as customers may cancel their service at any time (subject to notification requirements in the tariff), and revenue generally represents the amount Washington Gas is entitled to invoice. There are certain contracts that have terms of one year or longer. For these contracts, revenue is recognized based on the amount Washington Gas is entitled to bill the customer. Customers have the choice to purchase natural gas from competitive service providers. Washington Gas charges the competitive service providers balancing fees to manage the natural gas transportation imbalances. Where regulations require, Washington Gas issues customers a consolidated bill to include the natural gas supplied by the competitive service providers and distribution of natural gas. Washington Gas recognizes revenue only for distribution services that it has provided to the customer, and the balancing fees for the services provided to the competitive service provider.
Unbilled revenue	Washington Gas accrues unbilled revenues for gas delivered, but not yet billed at the end of each accounting period due to our customer billing cycles. “Unbilled revenues” represent performance obligations that have been satisfied and to which Washington Gas has an unconditional right to payment, except for contract assets related to Washington Gas’ area-wide contract, which requires project acceptance by federal government for the right to payment to occur.

Short-Term Debt (Policies)

Short-Term Debt (Policies)	6 Months Ended
	Jun. 30, 2019
Short-term Debt [Abstract]
Short Term Debt Policy	Washington Gas satisfies short-term financing requirements through the sale of commercial paper, financing arrangements with third-party lenders, or bank borrowings. Due to the seasonal nature of our operations, 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. The policy of Washington Gas is to maintain bank credit facilities in amounts equal to or greater than the expected maximum commercial paper position. Washington Gas issues long-term debt in the form of medium-term notes (MTNs), unsecured long-term notes and private placement notes, all of which contain individual terms regarding interest rates, maturities and call or put options. Each of these note types can have maturity dates of one or more years from the date of issuance.

Long-Term Debt Long-Term Debt (

Long-Term Debt Long-Term Debt (Policies)	6 Months Ended
	Jun. 30, 2019
Debt Disclosure [Abstract]
Long Term Debt Policy	Washington Gas satisfies short-term financing requirements through the sale of commercial paper, financing arrangements with third-party lenders, or bank borrowings. Due to the seasonal nature of our operations, 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. The policy of Washington Gas is to maintain bank credit facilities in amounts equal to or greater than the expected maximum commercial paper position. Washington Gas issues long-term debt in the form of medium-term notes (MTNs), unsecured long-term notes and private placement notes, all of which contain individual terms regarding interest rates, maturities and call or put options. Each of these note types can have maturity dates of one or more years from the date of issuance.

Income Taxes Income Taxes (Poli

Income Taxes Income Taxes (Policies)	6 Months Ended
	Jun. 30, 2019
Accounting Policies [Abstract]
Income Taxes Policy	Washington Gas will be included in the ASUS consolidated income tax returns beginning with the period from July 7, 2018 to December 31, 2018. We have established a new tax sharing policy with ASUS.

Derivative and Weather Relate_2

Derivative and Weather Related Instruments (Policies)	6 Months Ended
	Jun. 30, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives, Policy	Washington Gas enters into contracts 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 currently 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 utilizes 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 securing operating margins that Washington Gas will ultimately realize. The derivative transactions entered into under this program are subject to mark-to-market accounting treatment under ASC Topic 820. Regulatory sharing mechanisms provide for the annual realized profit from these transactions to be shared between Washington Gas’ shareholders and customers; therefore, changes in fair value are recorded through earnings, or as regulatory assets or liabilities to the extent that it is probable that realized gains and losses associated with these derivative transactions will be included in the rates charged to customers when they are realized. Unrealized gains and losses recorded to earnings may cause significant period-to-period volatility; this volatility does not change the operating margins that Washington Gas expects to ultimately realize from these transactions through the use of its storage and transportation capacity resources.
Risk, Policy	Managing Price Risk. To manage price risk associated with acquiring natural gas supply for utility customers, Washington Gas enters into physical and financial derivative transactions in the form of forward, option and other contracts, as authorized by its regulators. 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 may utilize 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 related debt.
Collateral, Policy	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. Washington Gas 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 parent company 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 Washington Gas’ 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. 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. Washington Gas 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 parent company 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 Washington Gas’ 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. Any collateral posted that is not offset against derivative assets and liabilities is included in “Other prepayments” in the condensed balance sheet. Collateral received and not offset against derivative assets and liabilities is included in “Customer deposits and advance payments” in the accompanying balance sheet.

Fair Value Measurements Fair Va

Fair Value Measurements Fair Value (Policies)	6 Months Ended
	Jun. 30, 2019
Accounting Policies [Abstract]
Fair Value Measurement Policy	We measure the fair value of our financial assets and liabilities using a combination of the income and market approaches in accordance with ASC Topic 820. These financial assets and liabilities primarily consist of derivatives recorded on our balance sheet under ASC Topic 815 and 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 Washington Gas. 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. 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. Our Risk Analysis and Mitigation (RA&M) Group determines the valuation policies and procedures. The RA&M Group reports to Washington Gas’ Chief Financial Officer. In accordance with Washington Gas valuation policy, we may utilize a variety of valuation methodologies to determine the fair value of 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.
Fair Value Transfer, Policy	Transfers between different levels of the fair value hierarchy may occur based on fluctuations in the valuation inputs and 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 period. Transfers out of Level 3 during the three and six months ended June 30, 2019 and 2018 were due to valuations that experienced an increase in observable market inputs. Transfers into Level 3 during the three and six months ended June 30, 2019 and 2018 were due to an increase in unobservable market inputs, primarily pricing points.
Fair Value of Financial Instruments, Policy	Our money market funds are Level 1 valuations and their carrying amount approximates fair value. The maturity of our commercial paper outstanding at both June 30, 2019 and December 31, 2018 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. Due to the nature of our project financing arrangements, the carrying cost approximates fair value using Level 2 inputs. Due to the short term nature of current maturities of long-term debt, the carrying cost 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 valuation techniques when observable market data is not available. Our long-term debt fair value measurement is classified as Level 3.

Accounting Policies (Tables)

Accounting Policies (Tables)	6 Months Ended
	Jun. 30, 2019
Accounting Policies [Abstract]
Accounting standards adopted in the current fiscal year	The following tables represent Accounting Standards Updates (ASUs) adopted by Washington Gas during the six months ended June 30, and other newly issued accounting standards that will be adopted by Washington Gas in the future. ACCOUNTING STANDARDS ADOPTED IN CALENDAR YEAR 2019 Standard Description Date of adoption Effect on the financial statements or other significant matters ASU 2016-02, Leases (Topic 842), ASU 2018-01, Land Easement Practical Expedient for Transition to Topic 842, ASU 2018-11, Targeted Improvements, and ASU 2018-20, Narrow-Scope Improvements for Lessors ASU 2016-02 requires recognition of a right-to-use asset and lease liability by lessees on the statement of financial position and disclosure of key information about leasing arrangements. Lessor accounting remains substantially unchanged but the standard modifies what qualifies as a sales-type and direct financing lease and eliminated real-estate specific provisions. The standard requires application using a modified retrospective approach. January 1, 2019 Leases, with terms longer than 12 months, for which Washington Gas is the lessee have been reflected on the balance sheet by recording an increase to non- current assets and an increase to deferred credits net of the current portion that is recorded in current liabilities. Upon adoption, Washington Gas recorded lease liabilities of $58.9 million and a right-of-use asset of $43.2 million, net of lease incentives and prepaid or deferred rent balances of $15.7 million. Washington Gas utilized the transition practical expedients which allow entities to not have to reassess whether an arrangement contains a lease and the lease classification under the provisions of ASC Topic 842, land easements, and not separating out the lease and non-lease components for certain classes of assets. As a result of the transition practical expedients, Washington Gas’ operating leases on transition are consistent with its conclusions under ASC 840. Washington Gas has also elected to present prior comparative information under ASC 840. See Note 3 - Leases for further information and the new required lease disclosures. ASU 2017-12, Derivatives and Hedging (Topic 815): Targeted improvements to Accounting for Hedging Activities and ASU 2018-16, Inclusion of the Secured Overnight Financing Rate (SOFR) Overnight Index Swap (OIS) Rate as a Benchmark Interest Rate for Hedge Accounting Purposes ASU 2017-12 amends the hedge accounting and recognition requirements by expanding an entity’s ability to hedge non-financial and financial risk components and reduce the complexity in fair value hedges of interest rate risk. Additionally, this standard eliminates the requirement to separately measure and disclose the ineffective portion of the hedge with the entire change in the fair value of a hedging instrument to be presented in the same statement of operations line as the hedged item. Early adoption is permitted. ASU 2018-16 adds the OIS rate based on SOFR as a fifth U.S. benchmark interest rate for hedge accounting purposes. This standard should be adopted in conjunction with ASU 2017-12 if not early adopted. January 1, 2019 The guidance will only have an impact on new transactions that are entered into and where hedge accounting is elected. ASU 2018-15, Intangibles-Goodwill and Other-Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract (a consensus of the FASB Emerging Issues Task Force) The update aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements to capitalize implementation costs incurred to develop or obtain internal-use software (and hosting arrangements that include an internal-use software license). Capitalized implementation costs should be presented in the statement of financial position as a prepaid expense and amortized over the term of the hosting arrangement, presented in the statements of operations in the same line items as prepayment of fees associated with the hosting arrangement. The updates in this standard may be applied on a prospective or retrospective basis. Early adoption is permitted. January 1, 2019 We early adopted this standard on a prospective basis. The adoption of this ASU did not have a material effect on our financial statements.
Other newly issued accounting standards	OTHER NEWLY ISSUED ACCOUNTING STANDARDS Standard Description Required date of adoption Effect on the financial statements or other significant matters ASU 2016-13, Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments, including other subsequent ASUs clarifying the guidance. For credit losses on financial instruments, this standard changes the current incurred loss impairment methodology to an expected loss methodology and requires consideration of a broader range of reasonable and supportable information to determine credit loss estimates. Early adoption is permitted. January 1, 2020 We are in the process of evaluating the impact the adoption of this standard will have on our financial statements. ASU 2018-13, Fair Value Measurement (Topic 820): Disclosure Framework—Changes to the Disclosure Requirements for Fair Value Measurement This update modifies the disclosure requirements on fair value measurements. Early adoption is permitted. January 1, 2020 It is not expected that the adoption of this standard will have a material effect on our financial statements. ASU 2018-17, Consolidation (Topic 810): Targeted Improvements to Related Party Guidance for Variable Interest Entities This standard provides a private-company scope exception to the VIE guidance for certain entities under common control and clarify that indirect interest held through related parties under common control will be considered on a proportional basis when determining whether fees paid to decision makers and service providers are variable interests. Early adoption is permitted. January 1, 2020 We are in the process of evaluating this new accounting standard but it is expected that the adoption of this standard will not have a material effect on our financial statements. ASU 2019-01, Leases (Topic 842) Codification Improvements This update addresses the determination of the fair value of the underlying asset by lessors that are not manufacturers or dealers, provides guidance for the presentation of the statement of cash flows for sales-type and direct financing leases, and clarifies transition disclosures related to Topic 250. January 1, 2020 We do not anticipate that adoption of this standard will have a material effect on our financial statements. ASU 2018-14, Compensation—Retirement Benefits—Defined Benefit Plans—General (Subtopic 715-20): Disclosure Framework—Changes to the Disclosure Requirements for Defined Benefit Plans This standard modifies the disclosure requirements related to defined benefit pension and other postretirement plans. Early adoption is permitted. December 31, 2020 We do not anticipate that adoption of this standard will have a material effect on our financial statements.

Revenue from Contracts With C_3

Revenue from Contracts With Customers (Tables)	6 Months Ended
	Jun. 30, 2019
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following table disaggregates revenue for the three and six months ended June 30, 2019 . Disaggregated Revenue by Type of Service (In millions) Three Months Ended June 30, 2019 Six Months Ended June 30, 2019 Revenue from contracts with customers Gas and transportation sales Gas sold and delivered $ 132.4 $ 594.4 Gas delivered for others 43.9 153.3 Other 9.9 23.6 Other revenues 1.7 2.8 Total revenue from contracts with customers $ 187.9 $ 774.1 Other sources of revenue Revenue from alternative revenue programs (a) $ 7.2 $ 11.3 Leasing revenue (b) 0.2 0.3 Other 3.2 6.4 Total revenue from other sources 10.6 18.0 Total Operating Revenue $ 198.5 $ 792.1 (a) Washington Gas has determined that its Revenue Normalization Adjustment (RNA), Weather Normalization Adjustment (WNA), and Conservation and Ratemaking Efficiency (CARE) Ratemaking Adjustment (CRA) billing adjustment mechanisms and accelerated pipe replacement programs are alternative revenue programs and accounted for under ASC Topic 980. (b) Revenue generated from Washington Gas lessor operating leases accounted for under ASC Topic 842, Leases.

Leases (Tables)

Leases (Tables)	6 Months Ended
	Jun. 30, 2019
Leases [Abstract]
Lessee, Operating Lease, Liability, Maturity [Table Text Block]	The following table provides our expected operating lease payments as of June 30, 2019 . Maturity of Operating Lease Liabilities (In millions) June 30, 2019 2019 $ 1.9 2020 5.9 2021 5.5 2022 5.4 2023 5.4 Thereafter 51.9 Total lease payments $ 76.0 Less: Interest (16.0 ) Present Value of Lease Liabilities $ 60.0
Lessee, Operating Lease, Supplemental Information [Table Text Block]	The following table provides supplemental cash flow information related to operating leases for the three and six months ended June 30, 2019 . Supplemental Cash Flow Information Related to Operating Leases ($ in millions) Three Months Ended June 30, Six Months Ended June 30, 2019 Cash paid for amounts included in the lease liabilities in the operating cash flows $ 0.5 $ 1.0 Operating lease cost (including variable lease costs of $0.4 million and $1.0 million, respectively) $ 1.7 $ 3.6 Right-of-use assets obtained in exchange for new operating lease liabilities $ 1.1 $ 1.1
Lessor, Operating Lease, Payments to be Received, Maturity [Table Text Block]	The following table summarizes the future operating lease payments to be received associated with these leases. Maturity of Operating Lease Payments (a) (In millions) June 30, 2019 2019 $ 0.4 2020 0.7 2021 0.6 2022 0.6 2023 0.6 Thereafter 58.4 Total lease payments $ 61.3 (a) The payments are presented on an undiscounted basis

Accounts Payable and Other Ac_2

Accounts Payable and Other Accrued Liabilities (Tables)	6 Months Ended
	Jun. 30, 2019
Accounts Payable and Accrued Liabilities [Abstract]
Accounts Payable and Other Accrued Liabilities	The table below provides details for the amounts included in “Accounts payable and other accrued liabilities” on the balance sheet. (In millions) June 30, 2019 December 31, 2018 Accounts payable—trade $ 153.3 $ 228.9 Employee benefits and payroll accruals 13.6 28.0 Other accrued liabilities 29.7 31.5 Total $ 196.6 $ 288.4

Short-Term Debt (Tables)

Short-Term Debt (Tables)	6 Months Ended
	Jun. 30, 2019
Short-term Debt [Abstract]
Commited Credit Available	The following is a summary of committed credit available at June 30, 2019 and December 31, 2018 . Committed Credit Available ($ in millions) June 30, 2019 December 31, 2018 Committed credit agreements Unsecured revolving credit facility, expire December 19, 2019 (a) $ 350.0 $ 350.0 Less: Commercial paper outstanding (218.0 ) (296.0 ) Net committed credit available $ 132.0 $ 54.0 Weighted average interest rate 2.64 % 2.93 % (a) Washington Gas’s revolving credit facility includes the right to request extensions with the bank group’s approval. Washington Gas’ revolving credit facility permits it to increase its borrowing limit by an additional $100 million , with the bank group’s approval, for a total of $450 million .

Long Term Debt (Tables)

Long Term Debt (Tables)	6 Months Ended
	Jun. 30, 2019
Debt Disclosure [Abstract]
Schedule of Long-term Debt Instruments [Table Text Block]	The following table shows the outstanding notes as of June 30, 2019 and December 31, 2018 . Long-Term Debt Outstanding ($ in millions) June 30, 2019 December 31, 2018 Total Long-Term Debt (a) $ 1,096.0 $ 1,096.0 Unamortized discount (2.9 ) (2.9 ) Unamortized debt expense (8.0 ) (8.1 ) Less—current maturities 50.0 50.0 Total Long-Term Debt $ 1,035.1 $ 1,035.0 Weighted average interest rate (b) 4.77 % 4.77 % (a) Includes MTNs and private placement notes. The amount represents face value of long-term debt including current maturities. (b) Weighted average interest rate is for the long-term debt including current maturities.

Components of Total Equity (Tab

Components of Total Equity (Tables)	6 Months Ended
	Jun. 30, 2019
Components of Total Equity [Abstract]
Components of Total Equity Table	The tables below reflect the components of “Total equity” for the three and six months ended June 30, 2019 and 2018 . Components of Total Equity (In thousands, except shares) Common Stock Paid-In Capital Retained Earnings Accumulated Other Comprehensive Income (Loss), Net of Taxes Total Shares Amount Three Months Ended June 30, 2019 Balance at March 31, 2019 46,479,536 46,479 979,273 631,114 (2,362 ) $ 1,654,504 Net loss — — — (20,591 ) — $ (20,591 ) Other comprehensive income (loss) — — — — (3,779 ) $ (3,779 ) Dividends declared: Common stock — — — (25,000 ) — $ (25,000 ) Preferred stock — — — (330 ) — $ (330 ) Balance at June 30, 2019 46,479,536 46,479 979,273 585,193 (6,141 ) 1,604,804 Three Months Ended June 30, 2018 Balance at March 31, 2018 46,479,536 46,479 584,596 756,374 (4,147 ) 1,383,302 Net loss — — — (11,499 ) — $ (11,499 ) Other comprehensive income (loss) — — — — 188 $ 188 Stock-based compensation (a) — — 966 — — $ 966 Dividends declared: Common stock — — — (20,796 ) — $ (20,796 ) Preferred stock — — — (330 ) — $ (330 ) Balance at June 30, 2018 46,479,536 46,479 585,562 723,749 (3,959 ) 1,351,831 Six Months Ended June 30, 2019 Balance at December 31, 2018 46,479,536 46,479 979,273 543,448 (6,627 ) 1,562,573 Net income — — — 92,405 — 92,405 Other comprehensive income (loss) — — — — 486 486 Dividends declared: Common stock — — — (50,000 ) — (50,000 ) Preferred stock — — — (660 ) — (660 ) Balance at June 30, 2019 46,479,536 46,479 979,273 585,193 (6,141 ) 1,604,804 Six Months Ended June 30, 2018 Balance at December 31, 2017 46,479,536 46,479 583,185 670,580 (4,330 ) $ 1,295,914 Net income — — — 96,585 — $ 96,585 Other comprehensive income (loss) — — — — 371 $ 371 Stock-based compensation (a) — — 2,377 — — $ 2,377 Dividends declared: Common stock — — — (42,756 ) — $ (42,756 ) Preferred stock — — — (660 ) — $ (660 ) Balance at June 30, 2018 46,479,536 46,479 585,562 723,749 (3,959 ) 1,351,831 (a) Stock-based compensation is based on the stock awards of WGL that are allocated to Washington Gas Light Company for its pro-rata share and includes implementation of ASU 2016-09.

Pension and Other Post-Retire_2

Pension and Other Post-Retirement Benefit Plans (Tables)	6 Months Ended
	Jun. 30, 2019
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Components of Net Periodic Benefit Costs (Income)	The following table shows the components of net periodic benefit costs (income) recognized in our financial statements during the three and six months ended June 30, 2019 and 2018 : Components of Net Periodic Benefit Costs (Income) Three Months Ended June 30, 2019 2018 (In millions) Pension Benefits Health and Life Benefits Pension Benefits Health and Life Benefits Service cost $ 3.1 $ 1.2 $ 3.7 $ 1.3 Interest cost 10.3 3.0 9.9 2.9 Expected return on plan assets (10.7 ) (6.1 ) (10.6 ) (5.9 ) Recognized prior service cost (credit) 0.1 (3.9 ) 0.1 (4.4 ) Recognized actuarial loss 1.4 — 3.9 — Net periodic benefit cost (income) 4.2 (5.8 ) 7.0 (6.1 ) Allocation to affiliates (0.5 ) 0.6 (0.9 ) 0.7 Adjusted net periodic benefit cost (income) 3.7 (5.2 ) 6.1 (5.4 ) Amount allocated to construction projects (b) (0.4 ) (0.2 ) (1.5 ) 1.2 Amount deferred as regulatory asset (liability)-net allocations (c) — — 1.5 — Amount charged (credited) to expense $ 3.3 $ (5.4 ) $ 6.1 $ (4.2 ) Six Months Ended June 30, 2019 2018 Service cost $ 6.1 $ 2.5 $ 7.4 $ 2.6 Interest cost 20.5 6.0 19.8 5.8 Expected return on plan assets (21.4 ) (12.2 ) (21.1 ) (11.8 ) Recognized prior service cost (credit) 0.2 (7.8 ) 0.2 (8.8 ) Recognized actuarial loss 2.7 — 7.8 — Settlement charge (a) 4.3 — — — Net periodic benefit cost (income) 12.4 (11.5 ) 14.1 (12.2 ) Allocation to affiliates (0.9 ) 1.3 (1.7 ) 1.4 Adjusted net periodic benefit cost (income) 11.5 (10.2 ) 12.4 (10.8 ) Amount allocated to construction projects (b) (0.8 ) (0.4 ) (2.6 ) 2.1 Amount deferred as regulatory asset (liability)-net allocations (c) 0.7 — 3.0 — Amount charged (credited) to expense $ 11.4 $ (10.6 ) $ 12.8 $ (8.7 ) (a)Amount relates to a one time partial settlement charge associated with a lump sum payment to Washington Gas’ defined benefit supplemental executive retirement plan (DB SERP) that was paid in the first quarter of 2019. (b)On October 1, 2018, Washington Gas adopted ASU 2017-07. As a result, only the service cost component of net periodic benefit costs (income) is eligible for capitalization. (c)Amount represents the amortization of previously unrecovered costs of the applicable pension benefits or the health and life benefits as approved in the District of Columbia through 2019.

Derivative and Weather Relate_3

Derivative and Weather Related Instruments (Tables)	6 Months Ended
	Jun. 30, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Absolute Notional Amounts of Open Positions on Derivative Instruments	The following table presents the balance sheet classification for all derivative instruments as of June 30, 2019 and December 31, 2018 . Absolute Notional Amounts of Open Positions on Derivative Instruments Notional Amounts June 30, 2019 December 31, 2018 Natural Gas (In millions of therms) Asset optimization & trading 12,233.0 13,051.0 Other risk-management activities 974.0 1,072.0
Balance Sheet Classification of Derivative Instruments	The following table presents the balance sheet classification for all derivative instruments as of June 30, 2019 and December 31, 2018 . Balance Sheet Classification of Derivative Instruments (b) (in millions) Gross Gross Total (a) As of June 30, 2019 Current Assets—Derivatives $ 5.5 $ (1.4 ) $ 4.1 Deferred Charges and Other Assets—Derivatives 10.3 — 10.3 Current Liabilities—Derivatives — (8.2 ) (8.2 ) Deferred Credits—Derivatives 1.1 (94.5 ) (93.4 ) Total $ 16.9 $ (104.1 ) $ (87.2 ) As of December 31, 2018 Current Assets—Derivatives $ 25.7 $ (6.2 ) $ 19.5 Deferred Charges and Other Assets—Derivatives 11.3 — 11.3 Current Liabilities—Derivatives 1.1 (21.4 ) (20.3 ) Deferred Credits—Derivatives — (116.8 ) (116.8 ) Total $ 38.1 $ (144.4 ) $ (106.3 ) (a) Washington Gas 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 Topic 815. All recognized derivative contracts and associated financial collateral subject to a master netting arrangement or similar that is eligible for offset under ASC Topic 815 have been presented net in the balance sheet. (b) Washington Gas did not have derivative instruments outstanding that were designated as hedging instruments at June 30, 2019 or December 31, 2018 .
Gains and (Losses) on Derivative Instruments	The following table presents all gains and losses associated with derivative instruments for the three and six months ended June 30, 2019 and 2018 . Washington Gas Light Company Gains and (Losses) on Derivative Instruments (In millions) Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Recorded to income Utility cost of gas 1.7 (4.5 ) 5.7 (1.5 ) Recorded to regulatory assets Gas costs 2.5 (9.0 ) 14.4 (5.5 ) Total $ 4.2 $ (13.5 ) $ 20.1 $ (7.0 )
Potential Collateral Requirements for Derivative Liabilities with Credit-Risk-Contingent Features	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 June 30, 2019 and December 31, 2018 , respectively. Potential Collateral Requirements for Derivative Liabilities with Credit-Risk-Contingent Features (In millions) June 30, 2019 December 31, 2018 Derivative liabilities with credit-risk-contingent features $ — $ 1.1 Maximum potential collateral requirements — 1.0

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2019
Fair Value Disclosures [Abstract]
Fair Value Measurements Under the Fair Value Hierarchy	The following table sets forth financial instruments recorded at fair value as of June 30, 2019 and December 31, 2018 , 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. Fair Value Measurements Under the Fair Value Hierarchy (In millions) Level 1 Level 2 Level 3 Total At June 30, 2019 Assets Natural gas related derivatives $ — $ 1.4 $ 15.5 $ 16.9 Total Assets $ — $ 1.4 $ 15.5 $ 16.9 Liabilities Natural gas related derivatives $ — $ (1.7 ) $ (102.4 ) $ (104.1 ) Total Liabilities $ — $ (1.7 ) $ (102.4 ) $ (104.1 ) At December 31, 2018 Assets Natural gas related derivatives $ — $ 9.8 $ 28.3 $ 38.1 Total Assets $ — $ 9.8 $ 28.3 $ 38.1 Liabilities Natural gas related derivatives $ — $ (9.5 ) $ (134.9 ) $ (144.4 ) Total Liabilities $ — $ (9.5 ) $ (134.9 ) $ (144.4 )
Quantitative Information about Level 3 Fair Value Measurements	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 June 30, 2019 and December 31, 2018 . Quantitative Information about Level 3 Fair Value Measurements (In millions) Net Fair Value Valuation Techniques Unobservable Inputs Range Natural gas related derivatives ($86.9) Discounted Cash Flow Natural Gas Basis Price (per dekatherm) ($0.878) - $2.665 Net Fair Value Natural gas related derivatives ($106.6) Discounted Cash Flow Natural Gas Basis Price ($1.028)-$5.34
Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs	The following table presents 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 three and six months ended June 30, 2019 and 2018, respectively. Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs (In millions) Total - Natural Gas Three Months Ended June 30, 2019 Balance at April 1, 2019 $ (86.1 ) Realized and unrealized gains (losses) Recorded to income 1.2 Recorded to regulatory assets—gas costs 1.9 Settlements (3.9 ) Balance at June 30, 2019 $ (86.9 ) Three Months Ended June 30, 2018 Balance at April 1, 2018 $ (89.0 ) Realized and unrealized gains (losses) Recorded to income (3.5 ) Recorded to regulatory assets—gas costs (7.6 ) Transfers into Level 3 (7.0 ) Settlements 3.5 Balance at June 30, 2018 $ (103.6 ) Six Months Ended June 30, 2019 Balance at January 1, 2019 $ (106.6 ) Realized and unrealized gains (losses) Recorded to income 4.8 Recorded to regulatory assets—gas costs 14.4 Transfers into Level 3 (3.8 ) Transfers out of Level 3 5.0 Settlements (0.7 ) Balance at June 30, 2019 $ (86.9 ) Six Months Ended June 30, 2018 Balance at January 1, 2018 $ (125.4 ) Realized and unrealized gains (losses) Recorded to income (4.2 ) Recorded to regulatory assets—gas costs (8.7 ) Transfers into Level 3 (7.0 ) Transfers out of Level 3 9.0 Settlements 32.7 Balance at June 30, 2018 $ (103.6 )
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements	The table below sets forth the line items on the statements of operations to which amounts are recorded for the three and six months ended June 30, 2019 and 2018, respectively, related to fair value measurements using significant Level 3 inputs. Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements (In millions) Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Utility cost of gas $1.2 $(3.5) $4.8 $(4.2)
Unrealized Gains (Losses) Recorded for Level 3 Measurements	Unrealized gains (losses) attributable to derivative assets and liabilities measured using significant Level 3 inputs were recorded as follows for the three and six months ended June 30, 2019 and 2018, respectively. Unrealized Gains (Losses) Recorded for Level 3 Measurements (In millions) Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Recorded to income Utility cost of gas $ 4.4 $ (5.9 ) $ 8.1 $ 3.3 Recorded to regulatory assets—gas costs 6.5 (9.9 ) 19.1 2.1 Total $ 10.9 $ (15.8 ) $ 27.2 $ 5.4
Fair Value of Financial Instruments	The following table presents the carrying amounts recorded at amortized cost and estimated fair values of our financial instruments at June 30, 2019 and December 31, 2018 . Fair Value of Financial Instruments June 30, 2019 December 31, 2018 (In millions) Carrying Amount Fair Value Carrying Amount Fair Value Money market funds (a) $ 49.6 $ 49.6 $ 69.7 $ 69.7 Commercial paper (b) $ 218.0 $ 218.0 $ 296.0 $ 296.0 Project financing (b) $ — $ — $ 15.5 $ 15.5 Current maturities of long-term debt $ 50.0 $ 50.0 $ 50.0 $ 50.0 Long-term debt (c) $ 1,035.1 $ 1,184.7 $ 1,035.0 $ 1,096.3 (a) The balance as of June 30, 2019 includes $0.9 million money market funds located in “Cash and cash equivalents,” $4.2 million rabbi trust investment located in “Current Assets-Other,” and $44.5 million rabbi trust investments located in “Deferred Charges and Other Assets-Other” of the accompanying balance sheet; The balance as of December 31, 2018 includes $4.4 million money market funds located in “Cash and cash equivalents,” $ 20.2 million rabbi trust investment located in “Current Assets-Other” and $45.1 million rabbi trust investments located in “Deferred Charges and Other Assets-Other.” The amounts in cash and cash equivalent may be offset by outstanding checks. (b) Balance is located in “Notes payable and project financing” in the accompanying balance sheet. (c) Includes adjustments for current maturities and unamortized discounts, as applicable.

Related Party Transactions (Tab

Related Party Transactions (Tables)	6 Months Ended
	Jun. 30, 2019
Related Party Transactions [Abstract]
Gas Balancing Service Charges	The following table shows the amounts Washington Gas charged WGL Energy Services for balancing services. Gas Balancing Service Charges Three Months Ended Six Months Ended (In millions) 2019 2018 2019 2018 Gas balancing service charge $ 3.1 $ 4.3 $ 12.0 $ 12.8

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Income (Loss) (Tables)	6 Months Ended
	Jun. 30, 2019
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Schedule of Accumulated Other Comprehensive Income (Loss)	The following table shows the changes in accumulated other comprehensive income (loss) by component for three and six months ended June 30, 2019 and 2018 . Changes in Accumulated Other Comprehensive Income (Loss) by Component Three Months Ended June 30, Six Months Ended June 30, (In thousands) 2019 2018 2019 2018 Beginning Balance $ (2,362 ) $ (4,147 ) $ (6,627 ) $ (4,330 ) Change in prior service cost (a) (161 ) (273 ) (323 ) (546 ) Change in actuarial gain (loss) (a) (2,848 ) 530 2,056 1,060 Current-period other comprehensive income (loss) (3,009 ) 257 1,733 514 Income tax expense related to other comprehensive income 770 69 1,247 143 Ending Balance $ (6,141 ) $ (3,959 ) $ (6,141 ) $ (3,959 ) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic benefit cost. Refer to Note 9—Pension and other post-retirement benefit plans for additional details.

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	6 Months Ended
	Jun. 30, 2019
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information Table	The following table details the changes in operating assets and liabilities from operating activities, cash payments that have been included in the determination of earnings and non-cash investing and financing activities. Six Months Ended June 30, Six Months Ended June 30, (In thousands) 2019 2018 CHANGES IN OPERATING ASSETS AND LIABILITIES Accounts receivable and unbilled revenues $ 141,473 $ 128,596 Receivables from associated companies (1,078 ) (6,559 ) Gas costs and other regulatory assets/liabilities—net (32,789 ) (7,403 ) Storage gas 37,700 30,283 Prepaid taxes 2,972 8,895 Accounts payable and other accrued liabilities (86,061 ) (8,974 ) Payables to associated companies (1,384 ) 1,744 Customer deposits and advance payments (17,868 ) 9,358 Accrued taxes (400 ) (23,796 ) Other current assets 4,796 2,575 Other current liabilities (243 ) (244 ) Deferred gas costs—net 68,477 52,235 Deferred assets—other 9,989 (1,435 ) Deferred liabilities—other (6,900 ) (10,772 ) Pension and other post-retirement benefits (13,246 ) (984 ) Other—net — 1,564 Changes in operating assets and liabilities $ 105,438 $ 175,083 SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION Income taxes paid (refunded)—net $ (1,682 ) $ — Interest paid $ 28,890 $ 28,084 SUPPLEMENTAL DISCLOSURES OF NON-CASH INVESTING AND FINANCING ACTIVITIES: Extinguishment of project debt financing $ (15,460 ) $ (28,312 ) Capital expenditure accruals included in accounts payable and other accrued liabilities $ 42,161 $ 26,472
Reconciliation of cash, cash equivalents and restricted cash	The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within Washington Gas’ balance sheet that sums to the total of such amounts shown on the statements of cash flows. (in thousands) June 30, 2019 June 30, 2018 Cash and cash equivalents $ — $ 27,185 Restricted cash included in Current Assets-Other $ 4,225 $ — Restricted cash included in Deferred Charges and Other Assets-Other $ 44,508 $ — Total cash, cash equivalents and restricted cash shown in the statement of cash flows $ 48,733 $ 27,185

Accounting Policies (Narrative)

Accounting Policies (Narrative) (Details) $ in Millions	Jun. 30, 2019USD ($)subsidiary	Jan. 01, 2019USD ($)
Lease liabilities	$ 60	$ 58.9
Right-of-use asset		43.2
Lease incentives and prepaid or deferred rent		$ 15.7
Washington Gas Resources
Number of Subsidiaries | subsidiary	4

Revenue from Contracts With C_4

Revenue from Contracts With Customers (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 187,900		$ 774,100
Other sources of revenue	10,600		18,000
Total Operating Revenue	198,484	$ 199,512	792,137	$ 731,552
Gas and transportation sales | Gas sold and delivered
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	132,400		594,400
Gas and transportation sales | Gas delivered for others
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	43,900		153,300
Gas and transportation sales | Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	9,900		23,600
Other revenues
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,700		2,800
Revenue from alternative revenue programs
Disaggregation of Revenue [Line Items]
Other sources of revenue	7,200		11,300
Leasing revenue
Disaggregation of Revenue [Line Items]
Other sources of revenue	200		300
Other
Disaggregation of Revenue [Line Items]
Other sources of revenue	3,200		6,400
Energy management services projects not complete
Disaggregation of Revenue [Line Items]
Receivables, Long-term Contracts or Programs	$ 38,000		$ 38,000		$ 85,300

Leases Narrative (Details)

Leases Narrative (Details) - USD ($) $ in Thousands	3 Months Ended	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2019	Jan. 01, 2019	Dec. 31, 2018
Right-of-use asset			$ 43,200
Lease incentives and prepaid or deferred rent			15,700
Current lease liability	$ 4,647	$ 4,647	2,800	$ 0
Non current lease liability	55,341	$ 55,341	$ 56,100	$ 0
Lessee, Operating Lease, Description		<div style="line-height:120%;padding-top:6px;text-indent:12px;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">Washington Gas has operating leases for our corporate headquarters and other corporate offices, communication tower space, and certain office equipment.</font></div></div>" id="sjs-C7">&lt;div style="font-family:Times New Roman;font-size:10pt;">&lt;div style="line-height:120%;padding-top:6px;text-indent:12px;font-size:10pt;">&lt;font style="font-family:inherit;font-size:10pt;">Washington Gas has operating leases for our corporate headquarters and other corporate offices, communication tower space, and certain office equipment.&lt;/font>&lt;/div>&lt;/div>
Lessee, Operating Lease, Option to Terminate		<div style="line-height:120%;padding-top:6px;text-indent:12px;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">The leases generally have options to terminate with notice prior to the end of the lease term based on the contract terms.</font></div></div>" id="sjs-C8">&lt;div style="font-family:Times New Roman;font-size:10pt;">&lt;div style="line-height:120%;padding-top:6px;text-indent:12px;font-size:10pt;">&lt;font style="font-family:inherit;font-size:10pt;">The leases generally have options to terminate with notice prior to the end of the lease term based on the contract terms.&lt;/font>&lt;/div>&lt;/div>
Lessee, Operating Lease, Option to Extend		<div style="line-height:120%;padding-top:6px;text-indent:12px;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">Some of the leases include options to extend the lease terms for 1 to 5 years with prior written notice or automatically renew if either party does not provide intent to terminate.</font></div></div><div style="font-family:Times New Roman;font-size:10pt;"><div style="line-height:120%;padding-top:6px;text-indent:12px;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">Some of the leases include options to extend the lease terms for 1 to 5 years with prior written notice or automatically renew if either party does not provide intent to terminate.</font></div></div>" id="sjs-C9">&lt;div style="font-family:Times New Roman;font-size:10pt;">&lt;div style="line-height:120%;padding-top:6px;text-indent:12px;font-size:10pt;">&lt;font style="font-family:inherit;font-size:10pt;">Some of the leases include options to extend the lease terms for 1 to 5 years with prior written notice or automatically renew if either party does not provide intent to terminate.&lt;/font>&lt;/div>&lt;/div>&lt;div style="font-family:Times New Roman;font-size:10pt;">&lt;div style="line-height:120%;padding-top:6px;text-indent:12px;font-size:10pt;">&lt;font style="font-family:inherit;font-size:10pt;">Some of the leases include options to extend the lease terms for 1 to 5 years with prior written notice or automatically renew if either party does not provide intent to terminate.&lt;/font>&lt;/div>&lt;/div>
Lessor, Operating Lease, Option to Extend		<div style="line-height:120%;padding-top:6px;text-indent:12px;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">Some of the leases include options to extend the lease terms for 1 to 5 years with prior written notice or automatically renew if the lessee does not provide intent not to renew.</font></div></div>" id="sjs-C10">&lt;div style="font-family:Times New Roman;font-size:10pt;">&lt;div style="line-height:120%;padding-top:6px;text-indent:12px;font-size:10pt;">&lt;font style="font-family:inherit;font-size:10pt;">Some of the leases include options to extend the lease terms for 1 to 5 years with prior written notice or automatically renew if the lessee does not provide intent not to renew.&lt;/font>&lt;/div>&lt;/div>
Lessor, Operating Lease, Option to Terminate		<div style="line-height:120%;padding-top:6px;text-indent:12px;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">The leases generally have options to terminate the leases with notice prior to the end of the lease term based on the contract terms.</font></div></div>" id="sjs-C11">&lt;div style="font-family:Times New Roman;font-size:10pt;">&lt;div style="line-height:120%;padding-top:6px;text-indent:12px;font-size:10pt;">&lt;font style="font-family:inherit;font-size:10pt;">The leases generally have options to terminate the leases with notice prior to the end of the lease term based on the contract terms.&lt;/font>&lt;/div>&lt;/div>
Operating Lease, Impairment Loss	$ 0	$ 0
Lease, Cost [Abstract]
Weighted average remaining lease term	13 years 8 months	13 years 8 months
Weighted average discount rate	3.32%	3.32%
Minimum
Lessee, Operating Lease, Remaining Lease Term	1 year	1 year
Lessor, Operating Lease, Remaining Lease Term	5 months	5 months
Maximum
Lessee, Operating Lease, Remaining Lease Term	22 years	22 years
Lessor, Operating Lease, Remaining Lease Term	82 years	82 years

Maturity of Operating Lease Lia

Maturity of Operating Lease Liabilities (Lessee) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Jan. 01, 2019
Operating Lease Liabilities, Payment Due [Abstract]
2019	$ 1.9
2020	5.9
2021	5.5
2022	5.4
2023	5.4
Thereafter	51.9
Total lease payments	76
Less: Interest	(16)
Present Value of Lease Liabilities	$ 60	$ 58.9

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information Related to Operating Leases (Lessee) (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2019
Leases [Abstract]
Cash paid for amounts included in the lease liabilities in the operating cash flows	$ 0.5	$ 1
Operating lease cost (including variable lease costs of $0.4 million and $1.0 million, respectively)	1.7	3.6
Variable lease cost	0.4	1
Right-of-Use Asset Obtained in Exchange for Operating Lease Liability	$ 1.1	$ 1.1

Maturity of Operating Lease Pay

Maturity of Operating Lease Payments (Lessor) (Details) $ in Millions	Jun. 30, 2019USD ($)
Maturity of Operating Lease Payments [Abstract]
2019	$ 0.4
2020	0.7
2021	0.6
2022	0.6
2023	0.6
Thereafter	58.4
Total lease payments	$ 61.3

Accounts Payable and Other Ac_3

Accounts Payable and Other Accrued Liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Accounts Payable and Accrued Liabilities [Abstract]
Accounts payable—trade	$ 153.3	$ 228.9
Employee benefits and payroll accruals	13.6	28
Other accrued liabilities	29.7	31.5
Total	$ 196.6	$ 288.4

Short-Term Debt (Details)

Short-Term Debt (Details) - USD ($) $ in Thousands	Jul. 19, 2019	Jun. 30, 2019	Dec. 31, 2018
Short Term Debt [Line Items]
Less: Commercial Paper		$ (218,000)	$ (311,460)
Payables to associated companies		56,299	95,228
WGL Energy Services
Short Term Debt [Line Items]
Payables to associated companies		100	53,000
New credit facility
Short Term Debt [Line Items]
Unsecured revolving credit facility	$ 450,000
Revolving credit facility additional borrowings	100,000
Revolving credit facility maximum borrowing capacity	$ 550,000
Energy management services projects not complete
Short Term Debt [Line Items]
Payables to associated companies		38,000	69,700
Notes payable and project financing			15,500
Unbilled revenues		38,000	85,300
Government agency with minimal credit risk [Member]
Short Term Debt [Line Items]
Reserve for bad debt		0	0
Committed credit
Short Term Debt [Line Items]
Unsecured revolving credit facility		350,000	350,000
Less: Commercial Paper		(218,000)	(296,000)
Net committed credit available		$ 132,000	$ 54,000
Weighted average interest rate		2.64%	2.93%
Revolving credit facility additional borrowings		$ 100,000
Revolving credit facility maximum borrowing capacity		450,000
Outstanding bank loans		$ 0	$ 0

Long Term Debt (Details)

Long Term Debt (Details) - USD ($)	Jun. 30, 2019	Dec. 31, 2018	Jun. 30, 2018
Long Term Debt [LIne Items]
Long-Term Debt	$ 1,096,000,000	$ 1,096,000,000
Unamortized discount	(2,900,000)	(2,900,000)
Unamortized debt expense	(8,000,000)	(8,100,000)
Less-current maturities	50,000,000	50,000,000
Total Long term debt	$ 1,035,100,000	$ 1,035,000,000
Weighted Average Interest Rate	4.77%	4.77%
Issuances
Long Term Debt [LIne Items]
Long-Term Debt	$ 0		$ 0
Retirements
Long Term Debt [LIne Items]
Long-Term Debt	$ 0		$ 0

Components of Total Equity (Det

Components of Total Equity (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common shareholders' equity, beginning balance	$ 1,654,504	$ 1,383,302	$ 1,562,573	$ 1,295,914
NET INCOME (LOSS)	(20,591)	(11,499)	92,405	96,585
OTHER COMPREHENSIVE INCOME (LOSS)	(3,779)	188	486	371
Stock-based compensation		966		2,377
Dividends declared - Common Stock	(25,000)	(20,796)	(50,000)	(42,756)
Dividends declared - Preferred Stock	(330)	(330)	(660)	(660)
Common shareholders' equity, ending balance	$ 1,604,804	$ 1,351,831	$ 1,604,804	$ 1,351,831
Common Stock
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning Balance, shares	46,479,536	46,479,536	46,479,536	46,479,536
Common shareholders' equity, beginning balance	$ 46,479	$ 46,479	$ 46,479	$ 46,479
Ending Balance, shares	46,479,536	46,479,536	46,479,536	46,479,536
Common shareholders' equity, ending balance	$ 46,479	$ 46,479	$ 46,479	$ 46,479
Paid-In Capital
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common shareholders' equity, beginning balance	979,273	584,596	979,273	583,185
Stock-based compensation		966		2,377
Common shareholders' equity, ending balance	979,273	585,562	979,273	585,562
Retained Earnings
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common shareholders' equity, beginning balance	631,114	756,374	543,448	670,580
NET INCOME (LOSS)	(20,591)	(11,499)	92,405	96,585
Dividends declared - Common Stock	(25,000)	(20,796)	(50,000)	(42,756)
Dividends declared - Preferred Stock	(330)	(330)	(660)	(660)
Common shareholders' equity, ending balance	585,193	723,749	585,193	723,749
Accumulated Other Comprehensive Loss, Net of Taxes
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common shareholders' equity, beginning balance	(2,362)	(4,147)	(6,627)	(4,330)
OTHER COMPREHENSIVE INCOME (LOSS)	(3,779)	188	486	371
Common shareholders' equity, ending balance	$ (6,141)	$ (3,959)	$ (6,141)	$ (3,959)

Income Taxes (Narrative) (Detai

Income Taxes (Narrative) (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Income Tax Disclosure [Abstract]
Tax sharing - amount paid to other associated companies	$ 0	$ 0	$ 0	$ 0
Tax sharing - amount received from associated companies	0	0	0	0
Interest or penalties associated with uncertain tax position	$ 0	$ 0	$ 0	$ 0

Pension and Other Post-retire_3

Pension and Other Post-retirement Benefit Plans (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Restricted cash included in Current Assets-Other	$ 4,378		$ 4,378		$ 20,347
Restricted cash included in Deferred Charges and Other Assets-Other	51,327		51,327		50,490
Reclass to Other income	(757)	$ 193	3,765	$ 1,787
ASU 2017-07
Defined Benefit Plan Disclosure [Line Items]
Reclass to Other income		$ 2,800		$ 5,600
Rabbi Trusts
Defined Benefit Plan Disclosure [Line Items]
Restricted Cash - Rabbi Trust Balance	44,100		44,100		60,800
Restricted cash included in Current Assets-Other	4,200		4,200		20,200
Restricted cash included in Deferred Charges and Other Assets-Other	$ 39,900		$ 39,900		$ 40,600

Pension and Other Post-retire_4

Pension and Other Post-retirement Benefit Plans (Components of Net Periodic Benefit Cost Income) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Defined Benefit Plan Disclosure [Line Items]
Recognized prior service cost (credit)	$ 161	$ 273	$ 323	$ 546
Recognized actuarial loss	2,848	(530)	(2,056)	(1,060)
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	3,100	3,700	6,100	7,400
Interest cost	10,300	9,900	20,500	19,800
Expected return on plan assets	(10,700)	(10,600)	(21,400)	(21,100)
Recognized prior service cost (credit)	100	100	200	200
Recognized actuarial loss	1,400	3,900	2,700	7,800
Settlement charge			4,300
Net periodic benefit cost (income)	4,200	7,000	12,400	14,100
Allocation to affiliates	(500)	(900)	(900)	(1,700)
Adjusted net periodic benefit cost (income)	3,700	6,100	11,500	12,400
Amount allocated to construction projects	(400)	(1,500)	(800)	(2,600)
Amount deferred as regulatory asset (liability)-net allocations	0	1,500	700	3,000
Amount charged (credited) to expense	3,300	6,100	11,400	12,800
Health and Life Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	1,200	1,300	2,500	2,600
Interest cost	3,000	2,900	6,000	5,800
Expected return on plan assets	(6,100)	(5,900)	(12,200)	(11,800)
Recognized prior service cost (credit)	(3,900)	(4,400)	(7,800)	(8,800)
Net periodic benefit cost (income)	(5,800)	(6,100)	(11,500)	(12,200)
Allocation to affiliates	600	700	1,300	1,400
Adjusted net periodic benefit cost (income)	(5,200)	(5,400)	(10,200)	(10,800)
Amount allocated to construction projects	(200)	1,200	(400)	2,100
Amount deferred as regulatory asset (liability)-net allocations			0	0
Amount charged (credited) to expense	$ (5,400)	$ (4,200)	$ (10,600)	$ (8,700)

Commitments and Contingencies (

Commitments and Contingencies (Narrative) (Details) - USD ($)	Jun. 21, 2019	Apr. 12, 2019	Jul. 31, 2018	Jun. 30, 2019	Dec. 31, 2018	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Mar. 31, 2019
Commitments and Contingencies [Line Items]
Operation and Maintenance Expenses				$ 88,236,000		$ 85,210,000	$ 199,238,000	$ 179,015,000
Regulatory Assets, Noncurrent				93,964,000	$ 99,105,000		93,964,000
Deferred Gas Cost				60,630,000	141,636,000		60,630,000
Utility cost of gas				55,589,000		$ 56,063,000	297,852,000	$ 261,359,000
Virginia rate case
Commitments and Contingencies [Line Items]
Requested base rate increase			$ 37,600,000
Virginia rate case | Minimum
Commitments and Contingencies [Line Items]
Requested Return on Equity, Percentage		10.30%
Requested Overall Rate of Return, Percentage		7.81%
Virginia rate case | Maximum
Commitments and Contingencies [Line Items]
Requested Return on Equity, Percentage		10.60%
Requested Overall Rate of Return, Percentage		7.94%
Accelerated pipeline replacement program
Commitments and Contingencies [Line Items]
Requested base rate increase			$ 14,700,000
Tax cuts and jobs act | Virginia
Commitments and Contingencies [Line Items]
Reduction in distribution rates				16,800,000	19,200,000		16,800,000
Environmental matters
Commitments and Contingencies [Line Items]
Liability for future environmental response costs				11,600,000	11,300,000		11,600,000
Estimated maximum liability for all environmental sites				35,600,000	29,400,000
Regulatory Assets, Noncurrent				6,400,000	5,800,000		6,400,000
Antero contract
Commitments and Contingencies [Line Items]
Loss Contingency, Damages Awarded, Value	$ 95,900,000
Antero contract | Washington Gas
Commitments and Contingencies [Line Items]
Operation and Maintenance Expenses				200,000
Loss Contingency, Damages Awarded, Value	11,200,000
Loss Contingency Accrual				11,200,000			11,200,000		$ 2,600,000
Loss Contingency, Receivable				1,300,000			1,300,000
Loss Contingency, Loss in Period				3,000,000
Deferred Gas Cost				4,500,000			4,500,000
Utility cost of gas				2,800,000
Antero contract | WGL Midstream
Commitments and Contingencies [Line Items]
Loss Contingency, Damages Awarded, Value	$ 84,700,000
Antero contract - court costs
Commitments and Contingencies [Line Items]
Loss Contingency Accrual				200,000			200,000
Merger commitments
Commitments and Contingencies [Line Items]
Operation and Maintenance Expenses				136,100,000
Other commitments amounts paid in prior fiscal year				117,600,000
Other commitments amounts paid in current fiscal year				4,200,000			6,500,000
Merger commitments | Natural gas extension
Commitments and Contingencies [Line Items]
Operation and Maintenance Expenses				70,000,000
Merger commitments | Natural gas extension | Maryland
Commitments and Contingencies [Line Items]
Operation and Maintenance Expenses				3,900,000
Merger commitments | Future hiring
Commitments and Contingencies [Line Items]
Operation and Maintenance Expenses				2,400,000
Merger commitments | Future leak mitigation
Commitments and Contingencies [Line Items]
Operation and Maintenance Expenses				8,000,000
Other External Partners | Performance Guarantee [Member]
Commitments and Contingencies [Line Items]
Unrecorded Unconditional Purchase Obligation				$ 0	$ 0		$ 0

Derivative and Weather Relate_4

Derivative and Weather Related Instruments Narrative (Details) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019USD ($)Counterparties	Jun. 30, 2018USD ($)	Jun. 30, 2019USD ($)Counterparties	Jun. 30, 2018USD ($)	Dec. 31, 2018USD ($)
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Liability, Fair Value, Gross Liability	$ (104.1)		$ (104.1)		$ (144.4)
Asset Optimization [Abstract]
Gain (Loss) on Asset Optimization Transactions Net Pretax	1.3	$ 1.9	9.5	$ 20.7
Unrealized Gains (Loss) On Asset Optimization Derivative Instruments Net Pretax	(0.5)	$ (3.8)	6.6	$ 8.5
Asset optimization loss contingency related	2.8
Derivative, Collateral [Abstract]
Right to Reclaim Cash	4.8		4.8		7.4
Derivative, Collateral, Obligation to Return Cash	$ 0.1		$ 0.1		$ 0.2
Concentration of Credit Risk [Abstract]
Number of Counterparties | Counterparties	3		3
Percentage Of Credit Exposure	10.00%		10.00%
Obligation to counterparties	$ 21.8		$ 21.8

Derivative and Weather Relate_5

Derivative and Weather Related Instruments (Gains and Losses) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Gains and (Losses) on Derivative Instruments
Total	$ 4,200	$ (13,500)	$ 20,100	$ (7,000)
Interest Expense	14,641	14,455	29,517	29,127
Utility cost of gas
Gains and (Losses) on Derivative Instruments
Recorded to income	1,700	(4,500)	5,700	(1,500)
Gas costs
Gains and (Losses) on Derivative Instruments
Recorded to regulatory assets	$ 2,500	$ (9,000)	$ 14,400	$ (5,500)

Potential Collateral Requiremen

Potential Collateral Requirements for Derivative Liabilities with Credit-Risk-Contingent Features (Details) - Credit Risk Contract - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Derivative [Line Items]
Derivative liabilities with credit-risk-contingent features	$ 0	$ 1.1
Maximum potential collateral requirements	$ 0	$ 1

Absolute Notional Amounts of Op

Absolute Notional Amounts of Open Positions on Derivative Instruments (Details) - MMBTU MMBTU in Millions	Jun. 30, 2019	Dec. 31, 2018
Asset Optimization [Member]
Derivative [Line Items]
Natural Gas Derivative Transaction, Volume	1,223,300,000	1,305,100,000
Other risk-management activities
Derivative [Line Items]
Natural Gas Derivative Transaction, Volume	97,400,000	107,200,000

Balance Sheet Classification of

Balance Sheet Classification of Derivative Instruments (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Derivative [Line Items]
Gross Derivative Assets	$ 16.9	$ 38.1
Gross Derivative Liabilities	(104.1)	(144.4)
Total	(87.2)	(106.3)
Current Assets—Derivatives
Derivative [Line Items]
Gross Derivative Assets	5.5	25.7
Gross Derivative Liabilities	(1.4)	(6.2)
Total	4.1	19.5
Deferred Charges and Other Assets—Derivatives
Derivative [Line Items]
Gross Derivative Assets	10.3	11.3
Total	10.3	11.3
Current Liabilities—Derivatives
Derivative [Line Items]
Gross Derivative Assets	0	1.1
Gross Derivative Liabilities	(8.2)	(21.4)
Total	(8.2)	(20.3)
Deferred Credits—Derivatives
Derivative [Line Items]
Gross Derivative Assets	1.1
Gross Derivative Liabilities	(94.5)	(116.8)
Total	$ (93.4)	$ (116.8)

Fair Value Measurements Under t

Fair Value Measurements Under the Fair Value Hierarchy (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Fair Value Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]
Assets	$ 16.9	$ 38.1
Liabilities	(104.1)	(144.4)
Natural Gas Related Derivatives
Fair Value Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]
Assets	16.9	38.1
Liabilities	(104.1)	(144.4)
Level 2
Fair Value Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]
Assets	1.4	9.8
Liabilities	(1.7)	(9.5)
Level 2 | Natural Gas Related Derivatives
Fair Value Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]
Assets	1.4	9.8
Liabilities	(1.7)	(9.5)
Level 3
Fair Value Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]
Assets	15.5	28.3
Liabilities	(102.4)	(134.9)
Level 3 | Natural Gas Related Derivatives
Fair Value Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]
Assets	15.5	28.3
Liabilities	$ (102.4)	$ (134.9)

Fair Value Measurements (Quanti

Fair Value Measurements (Quantitative information) (Details) - Natural Gas Related Derivatives $ in Millions	3 Months Ended
	Dec. 31, 2018USD ($)$ / dekatherm	Jun. 30, 2018USD ($)$ / dekatherm	Jun. 30, 2019USD ($)	Mar. 31, 2019USD ($)	Mar. 31, 2018USD ($)	Dec. 31, 2017USD ($)
Fair Value Measurements Details [Line Items]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs | $	$ (106.6)	$ (103.6)	$ (86.9)	$ (86.1)	$ (89)	$ (125.4)
Discounted Cash Flow
Fair Value Measurements Details [Line Items]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs | $	$ (106.6)		$ (86.9)
Discounted Cash Flow | Maximum | Natural Gas Basis Price
Fair Value Measurements Details [Line Items]
Input price | $ / dekatherm	5.34	2.665
Discounted Cash Flow | Minimum | Natural Gas Basis Price
Fair Value Measurements Details [Line Items]
Input price | $ / dekatherm	1.028	0.878

Fair Value Measurements (Reconc

Fair Value Measurements (Reconciliation with Level 3 Inputs) (Details) - Natural Gas Related Derivatives - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Reconciliation of Fair Value Measurements Using Significant Level 3 Inputs
Beginning Balance	$ (86.1)	$ (89)	$ (106.6)	$ (125.4)
Recorded to Income	1.2	(3.5)	4.8	(4.2)
Recorded to regulatory assets - gas costs	1.9	(7.6)	14.4	(8.7)
Transfers into Level 3		(7)	(3.8)	(7)
Transfers out of Level 3			5	9
Settlements	(3.9)	3.5	(0.7)	32.7
Ending Balance	$ (86.9)	$ (103.6)	$ (86.9)	$ (103.6)

Fair Value Measurements (Fair V

Fair Value Measurements (Fair Value of Financial Instruments) (Details) - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018	Jun. 30, 2018
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Commercial Paper	$ 218,000	$ 311,460
Current maturities of long-term debt	50,000	50,000
Long term debt	1,035,100	1,035,000
Restricted cash included in Current Assets-Other	4,378	20,347
Restricted cash included in Deferred Charges and Other Assets-Other	51,327	50,490
Cash and Cash Equivalents
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Money Market Funds	900	4,400
Rabbi Trusts
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Restricted cash included in Current Assets-Other	4,225	20,207	$ 0
Restricted cash included in Deferred Charges and Other Assets-Other	44,508	45,100	$ 0
Carrying Amount
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Money Market Funds	49,600	69,700
Commercial Paper	218,000	296,000
Project financing	0	15,500
Current maturities of long-term debt	50,000	50,000
Long term debt	1,035,100	1,035,000
Fair Value
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Money Market Funds	49,600	69,700
Commercial Paper	218,000	296,000
Project financing	0	15,500
Current maturities of long-term debt	50,000	50,000
Long-term debt	$ 1,184,700	$ 1,096,300

Fair Value Measurements (Realiz

Fair Value Measurements (Realized and Unrealized Gains and Losses with Level 3 Measurements) (Details) - Natural Gas Related Derivatives - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to regulatory assets - gas costs	$ 1.9	$ (7.6)	$ 14.4	$ (8.7)
Total Unrealized Gains (Losses)	10.9	(15.8)	27.2	5.4
Utility cost of gas
Realized and Unrealized Gains (Losses) Recorded to Income for Level 3 Measurements
Recorded to income	1.2	(3.5)	4.8	(4.2)
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to income	4.4	(5.9)	8.1	3.3
Regulatory asset-gas costs member
Unrealized Gains (Losses) Recorded for Level 3 Measurements
Recorded to regulatory assets - gas costs	$ 6.5	$ (9.9)	$ 19.1	$ 2.1

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Related Party Transaction [Line Items]
Payables to associated companies	$ 56,299		$ 56,299		$ 95,228
Receivables from Associated Companies	5,897		5,897		4,819
Operation and maintenance	88,236	$ 85,210	199,238	$ 179,015
Current liabilities-other	7,263		7,263		7,507
AltaGas | Shared service costs
Related Party Transaction [Line Items]
Payables to associated companies	10,300		10,300		0
Operation and maintenance	3,000		7,400
WGL Energy Services
Related Party Transaction [Line Items]
Payables to associated companies	100		100		53,000
Receivables from Associated Companies					700
Gas balancing service charge	3,100	4,300	12,000	12,800
Related Party Purchased Receivables	4,600		4,600		6,400
Other associated companies | Shared service costs
Related Party Transaction [Line Items]
Receivables from Associated Companies	2,900		2,900		$ 600
Hampshire Gas Company
Related Party Transaction [Line Items]
Operation and maintenance	$ 1,900	$ 1,800	$ 4,000	$ 3,400

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
AOCI, Net of Tax [Roll Forward]
Beginning Balance	$ (2,362)	$ (4,147)	$ (6,627)	$ (4,330)
Change in prior service cost	(161)	(273)	(323)	(546)
Change in actuarial gain (loss)	(2,848)	530	2,056	1,060
Current-period other comprehensive income (loss)	(3,009)	257	1,733	514
Income tax expense related to other comprehensive income	770	69	1,247	143
Ending Balance	$ (6,141)	$ (3,959)	$ (6,141)	$ (3,959)

Supplemental Cash Flow Inform_4

Supplemental Cash Flow Information (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018	Dec. 31, 2017
Increase (Decrease) in Operating Capital [Abstract]
Accounts receivable and unbilled revenues	$ 141,473	$ 128,596
Receivables from associated companies	(1,078)	(6,559)
Gas costs and other regulatory assets/liabilities—net	(32,789)	(7,403)
Storage gas	37,700	30,283
Prepaid taxes	2,972	8,895
Accounts payable and other accrued liabilities	(86,061)	(8,974)
Payables to associated companies	(1,384)	1,744
Customer deposits and advance payments	(17,868)	9,358
Accrued taxes	(400)	(23,796)
Other current assets	4,796	2,575
Other current liabilities	(243)	(244)
Deferred gas costs—net	68,477	52,235
Deferred assets—other	9,989	(1,435)
Deferred liabilities—other	(6,900)	(10,772)
Pension and other post-retirement benefits	(13,246)	(984)
Other—net	0	1,564
Changes in operating assets and liabilities	105,438	175,083
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Income taxes paid (refunded)—net	(1,682)	0
Interest paid	28,890	28,084
SUPPLEMENTAL DISCLOSURES OF NON-CASH INVESTING AND FINANCING ACTIVITIES:
Extinguisment of project debt financing	(15,460)	(28,312)
Capital expenditure accruals included in accounts payable and other accrued liabilities	42,161	26,472
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract]
Cash and cash equivalents	0	27,185	$ 6,082
Restricted cash included in Current Assets-Other	4,378		20,347
Restricted cash included in Deferred Charges and Other Assets-Other	51,327		50,490
Total cash, cash equivalents and restricted cash shown in the statement of cash flows	48,733	27,185	71,423	$ 6,652
Restricted Cash		0
Rabbi Trusts
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract]
Restricted cash included in Current Assets-Other	4,225	0	20,207
Restricted cash included in Deferred Charges and Other Assets-Other	$ 44,508	$ 0	$ 45,100