UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)



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

For the quarterly period ended ~~June 30, 2019~~March 31, 2020



☐	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission file number 1-7584

TRANSCONTINENTAL GAS PIPE LINE COMPANY, LLC

(Exact name of registrant as specified in its charter)



DEDelaware			74-1079400
(State or other jurisdiction of incorporation or organization)			(I.R.S. Employer Identification No.)
~~2800 POST OAK BOULEVARD~~
~~HOUSTON~~	TX	~~77056~~

2800 Post Oak Boulevard
Houston	Texas		77056
(Address of principal executive offices)				(Zip Code)

Registrant’s telephone number, including area code: (713) 215-2000

NO CHANGE

(Former name, former address and former fiscal year, if changed since last report)

Securities registered pursuant to Section 12(b) of the Act: None

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes þ No ¨

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes þ No ¨

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

Large accelerated filer

Accelerated filer

Non-accelerated Filer

Smaller reporting company

☐

Emerging growth company

☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No þ

THE REGISTRANT MEETS THE CONDITIONS SET FORTH IN GENERAL INSTRUCTIONS H (1)(a) AND (b) OF FORM 10-Q AND IS THEREFORE FILING THIS FORM 10-Q WITH THE REDUCED DISCLOSURE FORMAT.

Table of Contents

TRANSCONTINTENTAL GAS PIPE LINE COMPANY, LLC

Index



	Page
Part I. Financial Information:
Item 1. Financial Statements
Condensed Consolidated Statement of Comprehensive Income —Three ~~and Six~~ Months Ended ~~June 30,~~March 31, 2020 and 2019 ~~and 2018~~	4
Condensed Consolidated Balance Sheet — ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018~~2019	5
Condensed Consolidated Statement of Member's Equity — Three ~~and Six~~ Months Ended ~~June 30,~~March 31, 2020 and 2019 ~~and 2018~~	7
Condensed Consolidated Statement of Cash Flows — ~~Six~~Three Months Ended ~~June 30,~~March 31, 2020 and 2019 ~~and 2018~~	8
Notes to Condensed Consolidated Financial Statements	9

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	1916

Item 4. Controls and Procedures	2219

Part II. Other Information	2219

Item 1. Legal Proceedings	2219

Item 1A. Risk Factors	2219

Item 6. Exhibits	2321

Forward Looking Statements

The reports, filings, and other public announcements of Transcontinental Gas Pipe Line Company, LLC may contain or incorporate by reference statements that do not directly or exclusively relate to historical facts. Such statements are “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (Securities Act), and Section 21E of the Securities Exchange Act of 1934, as amended (Exchange Act). These forward-looking statements relate to anticipated financial performance, management’s plans and objectives for future operations, business prospects, outcome of regulatory proceedings, market conditions and other matters.

All statements, other than statements of historical facts, included in this report that address activities, events, or developments that we expect, believe, or anticipate will exist or may occur in the future, are forward-looking statements. Forward-looking statements can be identified by various forms of words ~~or phrases~~ such as “anticipates,” “believes,” “seeks,” “could,” “may,” “should,” “continues,” “estimates,” “expects,~~” “assumes,~~” “forecasts,” “intends,” “might,” “goals,” “objectives,” “targets,” “planned,” “potential,” “projects,” “scheduled,” “will,” "assumes," “guidance,” “outlook,” “in- service ~~date”~~date,” or other similar expressions. These forward-looking statements are based on management’s beliefs and assumptions and on information currently available to management and include, among others, statements regarding:

Our and our affiliates’ future credit ratings;

Amounts and nature of future capital expenditures;

Expansion and growth of our business and operations;

Expected in-service dates for capital projects;

Financial condition and liquidity;

Business strategy;

Cash flow from operations or results of operations;

Rate case filings;

Natural gas prices, supply, and demand; ~~and~~

Demand for our ~~services.~~services; and

The impact of the novel coronavirus (COVID-19) pandemic.

Forward-looking statements are based on numerous assumptions, uncertainties, and risks that could cause future events or results to be materially different from those stated or implied in this report. Many of the factors that will determine these results are beyond our ability to control or predict. Specific factors that could cause actual results to differ from results contemplated by the forward-looking statements include, among others, the following:

The impact of operational and developmental hazards and unforeseen interruptions;

Development and rate of adoption of alternative energy sources;

The strength and financial resources of our competitors and the effects of competition;

Availability of supplies, including lower than anticipated volumes from third parties, and market demand;

Volatility of pricing including the effect of lower than anticipated energy commodity prices;

~~Inflation, interest rates,~~

Changes in maintenance and ~~general economic conditions (including future disruptions and volatility in the global credit markets and the impact of these events on~~construction costs, as well as our ~~customers and suppliers);~~

~~The strength and financial resources of our competitors and the effects of competition;~~

~~Whether we are able to successfully identify, evaluate and timely execute our capital projects and other investment opportunities;~~

~~Our~~ ability to ~~successfully expand our facilities and operations;~~obtain sufficient construction related inputs including skilled labor;

~~Development and rate of adoption of alternative energy sources;~~

~~Availability of adequate insurance coverage and the impact of operational and development hazards and unforeseen interruptions;~~

The impact of existing and future laws and regulations, the regulatory environment, environmental liabilities, and litigation, as well as our ability to obtain necessary permits and approvals, and achieve favorable rate proceeding outcomes;

Increasing scrutiny and changing expectations from stakeholders with respect to our environmental, social and governance practices;

The physical and financial risks associated with climate change;

Our exposure to the credit risk of our customers and counterparties;

Our ability to successfully expand our facilities and operations;

Whether we are able to successfully identify, evaluate, and timely execute our capital projects and investment opportunities in accordance with our capital expenditure budget;

Risks related to financing, including restrictions stemming from debt agreements, future changes in credit ratings as determined by nationally recognized credit rating agencies, and the availability and cost of capital;

Inflation, interest rates, and general economic conditions (including future disruptions and volatility in the global credit markets and the impact of these events on customers and suppliers);

Our costs for defined benefit pension plans and other postretirement benefit plans sponsored by our affiliates;

~~Changes in maintenance and construction costs, as well as our ability to obtain sufficient construction related inputs~~

The risks resulting from outbreaks or other public health crises, including ~~skilled labor;~~COVID-19;

Changes in the current geopolitical situation;

~~Our exposure to the credit risks of our customers and counterparties;~~

~~Risks related to financing, including restrictions stemming from our debt agreements, future changes in our credit ratings and the availability and cost of capital;~~

Risks associated with weather and natural phenomena, including climate conditions and physical damage to our facilities;

Acts of terrorism, cybersecurity incidents, and related disruptions; and

Additional risks described in our filings with the Securities and Exchange Commission (SEC).

Given the uncertainties and risk factors that could cause our actual results to differ materially from those contained in any forward-looking statement, we caution investors not to unduly rely on our forward-looking statements. We disclaim any obligations to and do not intend to update the above list or to announce publicly the result of any revisions to any of the forward-looking statements to reflect future events or developments.

In addition to causing our actual results to differ, the factors listed above and referred to below may cause our intentions to change from those statements of intention set forth in this report. Such changes in our intentions may also

cause our results to differ. We may change our intentions, at any time and without notice, based upon changes in such factors, our assumptions, or otherwise.

Because forward-looking statements involve risks and uncertainties, we caution that there are important factors, in addition to those listed above, that may cause actual results to differ materially from those contained in the forward-looking statements. For a detailed discussion of those factors, see Part I, Item 1A. Risk Factors in our Annual Report on Form 10-K filed with the SEC on February ~~21, 2019.~~24, 2020, as supplemented by the disclosure in Part II, Item 1A. Risk Factors in this Quarterly Report on Form 10-Q.

PART I — FINANCIAL INFORMATION



ITEM 1.	Financial Statements.

TRANSCONTINENTAL GAS PIPE LINE COMPANY, LLC

CONDENSED CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME

(Thousands of Dollars)

(Unaudited)


	Three months ended June 30,						Six months ended June 30,						Three months ended March 31,
	2019			2018			2019			2018			2020			2019
Operating Revenues:
Natural gas sales	$	22,429		$	29,873		$	46,515		$	55,124		$	19,654		$	24,086
Natural gas transportation	526,152			415,708			1,060,312			842,286			566,006			534,160
Natural gas storage	38,472			33,786			74,557			68,553			38,374			36,085
Other	2,759			2,308			5,521			4,948			3,334			2,762
Total operating revenues	589,812			481,675			1,186,905			970,911			627,368			597,093

Operating Costs and Expenses:
Cost of natural gas sales	22,429			29,873			46,515			55,124			19,654			24,086
Cost of natural gas transportation	8,939			8,461			23,574			21,535			13,396			14,635
Operation and maintenance	98,135			93,659			181,583			180,675			80,689			83,448
Administrative and general	57,358			46,981			105,509			93,362			42,171			48,151
Depreciation and amortization	103,184			89,282			207,807			172,506			113,635			104,623
Taxes — other than income taxes	18,661			17,164			38,938			35,602			22,437			20,277
Regulatory credit resulting from Tax Reform	(5,248		)	(20,867		)	(6,997		)	(20,867		)	(7,688		)	(1,749		)
Other expense, net	12,365			12,564			25,714			30,405			3,290			13,349
Total operating costs and expenses	315,823			277,117			622,643			568,342			287,584			306,820

Operating Income	273,989			204,558			564,262			402,569			339,784			290,273

Other (Income) and Other Expenses:
Interest expense	70,989			53,375			142,080			98,449			73,109			71,091
Allowance for equity and borrowed funds used during construction (AFUDC)	(7,504		)	(34,895		)	(16,218		)	(61,503		)	(10,953		)	(8,714		)
Equity in (earnings) losses of unconsolidated affiliates	(823		)	(1,325		)	(1,594		)	265
Equity in earnings of unconsolidated affiliates													—			(771		)
Miscellaneous other (income) expenses, net	(572		)	(4,819		)	(1,607		)	(6,780		)	(356		)	(1,035		)
Total other (income) and other expenses	62,090			12,336			122,661			30,431			61,800			60,571

Net Income	211,899			192,222			441,601			372,138			277,984			229,702

Other comprehensive income (loss):
Equity interest in unrealized gain (loss) on interest rate hedges (includes $(51) and $(33) for the three months ended and $(129) and $(27) for the six months ended June 30, 2019 and June 30, 2018, respectively, of accumulated other comprehensive income reclassification for equity interest in realized gains on interest rate hedges)	(369		)	119			(599		)	524
Other comprehensive loss:
Equity interest in unrealized gain (loss) on interest rate hedges (includes $(78) for the three months ended March 31, 2019 of accumulated other comprehensive income reclassification for equity interest in realized gains on interest rate hedges)													—			(230		)

Comprehensive Income	$	211,530		$	192,341		$	441,002		$	372,662		$	277,984		$	229,472

See accompanying notes.

TRANSCONTINENTAL GAS PIPE LINE COMPANY, LLC

CONDENSED CONSOLIDATED BALANCE SHEET

(Thousands of Dollars)

(Unaudited)


	June 30, 2019		December 31, 2018		March 31, 2020		December 31, 2019
ASSETS

Current Assets:
Cash	$	—	$	—	$	—	$	—
Receivables:
Affiliates	1,617		1,018		1,685		669
Advances to affiliate	—		33,034
Trade and other	223,761		201,198		233,039		253,266
Transportation and exchange gas receivables	10,361		4,515		5,663		6,360
Inventories	74,643		63,205		63,862		64,992
Regulatory assets	93,725		95,770		62,559		69,440
Other	11,868		12,574		10,753		11,240
Total current assets	415,975		411,314		377,561		405,967

Investments, at cost plus equity in undistributed earnings	37,268		26,520

Property, Plant and Equipment:
Natural gas transmission plant	16,329,890		15,908,878		16,888,643		16,764,904
Less-Accumulated depreciation and amortization	4,321,042		4,147,729		4,528,011		4,438,077
Total property, plant and equipment, net	12,008,848		11,761,149		12,360,632		12,326,827

Other Assets:
Regulatory assets	273,545		289,479		318,200		290,923
Right-of-use assets	91,516		—		83,342		84,979
Other	192,414		167,490		196,426		210,017
Total other assets	557,475		456,969		597,968		585,919

Total assets	$	13,019,566	$	12,655,952	$	13,336,161	$	13,318,713

(continued)

See accompanying notes.

TRANSCONTINENTAL GAS PIPE LINE COMPANY, LLC

CONDENSED CONSOLIDATED BALANCE SHEET

(Thousands of Dollars)

(Unaudited)


	June 30, 2019			December 31, 2018		March 31, 2020		December 31, 2019
LIABILITIES AND MEMBER’S EQUITY

Current Liabilities:
Payables:
Affiliates	$	56,330		$	50,727	$	40,767	$	47,740
Advances from affiliates	34,345			—
Advances from affiliate						316,907		252,549
Trade and other	253,413			226,911		118,607		183,968
Transportation and exchange gas payables	1,224			5,973		607		3,961
Reserve for rate refunds	85,853			—		248,291		188,842
Regulatory liabilities	39,652			5,097		57,092		57,359
Accrued liabilities	218,733			218,384		158,908		199,128
Long-term debt due within one year	16,904			15,419		20,644		20,180
Total current liabilities	706,454			522,511		961,823		953,727

Long-Term Debt	4,010,847			3,998,988		4,041,622		4,044,790

Other Long-Term Liabilities:
Asset retirement obligations	364,841			348,609		431,937		426,505
Regulatory liabilities	996,813			1,026,892		962,945		966,961
Deferred revenue	220,885			226,164		212,957		215,598
Lease liability	87,410			—		83,107		84,528
Other	8,714			4,188		28,003		20,821
Total other long-term liabilities	1,678,663			1,605,853		1,718,949		1,714,413

Contingent Liabilities and Commitments (Note 4)
Contingent Liabilities and Commitments (Note 3)

Member’s Equity:
Member’s capital	4,428,499			4,428,499		4,428,499		4,428,499
Retained earnings	2,195,168			2,099,567		2,185,268		2,177,284
Accumulated other comprehensive income	(65		)	534
Total member’s equity	6,623,602			6,528,600		6,613,767		6,605,783

Total liabilities and member’s equity	$	13,019,566		$	12,655,952	$	13,336,161	$	13,318,713

See accompanying notes.

TRANSCONTINENTAL GAS PIPE LINE COMPANY, LLC

CONDENSED CONSOLIDATED STATEMENT OF MEMBER’S EQUITY

(Thousands of Dollars)

(Unaudited)


	Three months ended June 30,						Three Months Ended March 31,
	2019			2018			2020			2019
Member's Capital:
Balance at beginning of period	$	4,428,499		$	4,428,499		$	4,428,499		$	4,428,499
Cash contributions from parent	—			—			—			—
Balance at end of period	4,428,499			4,428,499			4,428,499			4,428,499
Retained Earnings:
Balance at beginning of period	2,153,269			1,973,404			2,177,284			2,099,567
Net income	211,899			192,222			277,984			229,702
Cash distributions to parent	(170,000		)	(135,000		)	(270,000		)	(176,000		)
Balance at end of period	2,195,168			2,030,626			2,185,268			2,153,269
Accumulated Other Comprehensive Income:
Balance at beginning of period	304			742			—			534
Equity interest in unrealized gain (loss) on interest rate hedge	(369		)	119
Equity interest in unrealized loss in interest rate hedge							—			(230		)
Balance at end of period	(65		)	861			—			304

Total Member's Equity	$	6,623,602		$	6,459,986		$	6,613,767		$	6,582,072

Six months ended June 30,
2019 2018
Member's Capital:
Balance at beginning of period $ 4,428,499
$ 4,088,499
Cash contributions from parent —
340,000
Balance at end of period 4,428,499
4,428,499
Retained Earnings:
Balance at beginning of period 2,099,567
1,848,488
Net income 441,601
372,138
Cash distributions to parent (346,000 ) (190,000 )
Balance at end of period 2,195,168
2,030,626
Accumulated Other Comprehensive Income:
Balance at beginning of period 534
337
Equity interest in unrealized gain (loss) on interest rate hedge (599 ) 524
Balance at end of period (65 ) 861

Total Member's Equity $ 6,623,602
$ 6,459,986

See accompanying notes.

TRANSCONTINENTAL GAS PIPE LINE COMPANY, LLC

CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS

(Thousands of Dollars)

(Unaudited)


	Six months ended June 30,						Three months ended March 31,
	2019			2018			2020			2019
Cash flows from operating activities:
Net income	$	441,601		$	372,138		$	277,984		$	229,702
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	207,807			172,506			113,635			104,623
Allowance for equity funds used during construction (equity AFUDC)	(13,598		)	(45,910		)	(8,121		)	(6,510		)
Regulatory credit resulting from Tax Reform	(6,997		)	(20,867		)	(7,688		)	(1,749		)
Equity in (earnings) losses of unconsolidated affiliates	(1,594		)	265
Equity in earnings of unconsolidated affiliates							—			(771		)
Distributions from unconsolidated affiliates	2,496			931			—			1,248
Changes in operating assets and liabilities:
Receivables — affiliates	(599		)	300			(1,016		)	619
— trade and other	(22,563		)	5,053			20,227			(33,047		)
Transportation and exchange gas receivable	(5,846		)	(4,932		)	697			(1,824		)
Inventories	(3,671		)	(19,794		)	1,130			(4,531		)
Payables — affiliates	5,603			(10,686		)	(6,973		)	(4,242		)
— trade	(20,397		)	(30,052		)	(31,120		)	(45,546		)
Accrued liabilities	(8,346		)	20,741			(40,343		)	(35,238		)
Reserve for rate refunds	85,853			—			59,449			22,133
Asset retirement obligations - non-current	16,897			19,217
Asset retirement obligations							5,432			18,577
Deferred revenue	(5,279		)	(5,279		)	(2,641		)	(2,638		)
Other, net	37,518			(17,244		)	9,572			3,419
Net cash provided by operating activities	708,885			436,387			390,224			244,225

Cash flows from financing activities:
Proceeds from long-term debt	—			993,440
Proceeds from other financing obligations	20,429			24,298			1,685			7,914
Retirement of long-term debt	—			(250,000		)
Payments on other financing obligations	(7,944		)	(758		)	(4,837		)	(3,680		)
Payments for debt issuance costs	—			(9,208		)
Cash distributions to parent	(346,000		)	(190,000		)	(270,000		)	(176,000		)
Cash contributions from parent	—			340,000
Advances from affiliate, net	34,345			—			64,358			86,580
Net cash provided by (used in) financing activities	(299,170		)	907,772
Net cash used in financing activities							(208,794		)	(85,186		)

Cash flows from investing activities:
Capital expenditures*	(412,561		)	(1,463,600		)	(173,184		)	(184,556		)
Contributions and advances for construction costs	17,481			337,874			10,149			10,057
Disposal of property, plant and equipment, net	(17,077		)	(7,477		)	(4,782		)	(5,477		)
Advances to affiliate, net	33,034			(193,886		)	—			33,034
Contribution to unconsolidated affiliate	(12,250		)	—
Purchase of ARO Trust investments	(42,632		)	(36,807		)	(28,686		)	(19,518		)
Proceeds from sale of ARO Trust investments	26,636			19,737			15,073			9,767
Other, net	(2,346		)	—			—			(2,346		)
Net cash used in investing activities	(409,715		)	(1,344,159		)	(181,430		)	(159,039		)

Increase (decrease) in cash	—			—			—			—
Cash at beginning of period	—			—			—			—
Cash at end of period	$	—		$	—		$	—		$	—

* Increase to property, plant and equipment, exclusive of equity AFUDC	$	(446,594	)	$	(1,434,519	)	$	(132,575	)	$	(161,741	)
Changes in related accounts payable and accrued liabilities	34,033			(29,081		)	(40,609		)	(22,815		)
Capital expenditures	$	(412,561	)	$	(1,463,600	)	$	(173,184	)	$	(184,556	)

See accompanying notes.

TRANSCONTINENTAL GAS PIPE LINE COMPANY, LLC

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1. BASIS OF PRESENTATION

In this report, Transco (which includes Transcontinental Gas Pipe Line Company, LLC and, unless the context otherwise requires, all of our majority-owned subsidiaries) is at times referred to in the first person as “we,” “us” or “our.”

Transco is indirectly owned by The Williams Companies, Inc. (Williams).

General

The condensed consolidated unaudited financial statements include our accounts and the accounts of the subsidiaries we control. Companies in which we and our subsidiaries own 20 percent to 50 percent of the voting common stock or otherwise exercise significant influence over operating and financial policies of the company are accounted for under the equity method. Effective December 31, 2019, we distributed to our parent four wholly owned subsidiaries, two of which owned an interest in Pine Needle Operating Company, LLC and Cardinal Operating Company, LLC. The equity method investments ~~as of June 30, 2019 and~~prior to December 31, ~~2018 consist~~2019 consisted of Cardinal Pipeline Company, LLC (Cardinal) with an ownership interest of approximately 45 percent and Pine Needle LNG Company, LLC (Pine Needle) with an ownership interest of 35 percent. We received distributions associated with our equity method investments totaling ~~$2.5 million and $0.9~~$1.2 million in the ~~six~~three months ended ~~June 30, 2019 and June 30, 2018, respectively. We made a $12.3 million contribution to Pine Needle in the six months ended June 30,~~March 31, 2019.

The condensed consolidated unaudited financial statements have been prepared from our books and records. Certain information and footnote disclosures normally included in financial statements prepared in accordance with U.S. generally accepted accounting principles (GAAP) have been condensed or omitted in this Form 10-Q pursuant to Securities and Exchange Commission rules and regulations. The condensed consolidated unaudited financial statements include all normal recurring adjustments and others which, in the opinion of our management, are necessary to present fairly our interim financial statements. These condensed consolidated unaudited financial statements should be read in conjunction with the consolidated financial statements and the notes thereto included in our ~~2018~~2019 Annual Report on Form 10-K.

The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the amounts reported in the condensed consolidated unaudited financial statements and accompanying notes. Actual results could differ from those estimates.

~~A reclassification within operating activities in the Condensed Consolidated Statement of Cash Flows between~~ ~~Accrued liabilities~~ ~~and~~ ~~Other, net~~ ~~of $5.0 million for the six months ended June 30, 2018, has been made to conform to the 2019 presentation.~~

Income Taxes

We generally are not a taxable entity for federal or state and local income tax purposes. The tax on net income is generally borne by our parent, Williams. Net income for financial statement purposes may differ significantly from taxable income of Williams as a result of differences between the tax basis and financial reporting basis of assets and liabilities.

Revenue Subject to Refund

Federal Energy Regulatory Commission (FERC) regulations promulgate policies and procedures which govern a process to establish the rates that we are permitted to charge customers for natural gas sales and services, including the transportation and storage of natural gas. Key determinants in the ratemaking process are (1) costs of providing service, including depreciation expense, (2) allowed rate of return, including the equity component of the capital structure and related taxes, and (3) contract and volume throughput assumptions.

As a result of the ratemaking process, certain revenues collected by us may be subject to refund upon the issuance of final orders by the FERC in pending rate proceedings. We record estimates of rate refund liabilities considering our and other third-party regulatory proceedings, advice of counsel and estimated total exposure, as well as collection and other risks. Depending on the results of these proceedings, the actual amounts allowed to be collected from customers

could differ from management's estimate. In addition, as a result of rate orders, tariff provisions or regulations, we are required to refund or credit certain revenues to our customers. ~~At June 30, 2019, we have accrued approximately $85.9 million related to Docket No. RP18-1126, which we believe is adequate for any refunds that may be required.~~(See Note 3)

Accounting Standards Issued and Adopted

In ~~February~~June 2016, the Financial Accounting Standards Board ~~(FASB)~~ issued Accounting Standards Update (ASU) 2016-02 “Leases (Topic 842)” (ASU 2016-02). ASU 2016-02 establishes a comprehensive new lease accounting model. ASU 2016-02 modifies the definition of a lease, requires a dual approach to lease classification similar to prior lease accounting, and causes lessees to recognize operating leases on the balance sheet as a lease liability measured as the present value of the future lease payments with a corresponding right-of-use asset, with an exception for leases with a term of one year or less. Additional disclosures are required regarding the amount, timing, and uncertainty of cash flows arising from leases. In January 2018, the FASB issued ASU 2018-01 “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842” (ASU 2018-01). Per ASU 2018-01, land easements and rights-of-way are required to be assessed under ASU 2016-02 to determine whether the arrangements are or contain a lease. ASU 2018-01 permits an entity to elect a transition practical expedient to not apply ASU 2016-02 to land easements that exist or expired before the effective date of ASU 2016-02 and that were not previously assessed under the previous lease guidance in Accounting Standards Codification (ASC) Topic 840 “Leases.”

In July 2018, the FASB issued ASU 2018-11 “Leases (Topic 842): Targeted Improvements” (ASU 2018-11). Prior to ASU 2018-11, a modified retrospective transition was required for financing or operating leases existing at or entered into after the beginning of the earliest comparative period presented in the financial statements. ASU 2018-11 allows entities an additional transition method to the existing requirements whereby an entity could adopt the provisions of ASU 2016-02 by recognizing a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption without adjustment to the financial statements for periods prior to adoption. ASU 2018-11 also allows a practical expedient that permits lessors to not separate non-lease components from the associated lease component if certain conditions are present. ASU 2016-02 is effective for interim and annual periods beginning after December 15, 2018. We prospectively adopted ASU 2016-02 effective January 1, 2019, and did not adjust prior periods as permitted by ASU 2018-11 (See Note 3).

We completed our review of contracts to identify leases based on the modified definition of a lease and implemented changes to our internal controls to support management in the accounting for and disclosure of leasing activities upon adoption of ASU 2016-02. We implemented a financial lease accounting system to assist management in the accounting for leases upon adoption. The most significant changes to our financial statements as a result of adopting ASU 2016-02 relate to the recognition of a $91.3 million lease liability and offsetting right-of-use asset in our Condensed Consolidated Balance Sheetfor operating leases. We also evaluated ASU 2016-02’s available practical expedients on adoption. We generally elected to adopt the practical expedients, which includes the practical expedient to not separate lease and non-lease components by both lessees and lessors by class of underlying assets and the land easements practical expedient.

~~Accounting Standards Issued But Not Yet Adopted~~

~~In June 2016, the FASB issued ASU~~ 2016-13 “Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments” (ASU 2016-13). ASU 2016-13 ~~changes~~changed the impairment model for most financial assets and certain other instruments. For trade and other receivables, held-to-maturity debt securities, loans, and other instruments, entities ~~will be~~are required to use a ~~new~~ forward-looking “expected loss” model that generally will result in the earlier recognition of allowances for losses. ~~The guidance also requires increased disclosures.~~We adopted ASU 2016-13 is effective ~~for interim and annual periods beginning after December 15, 2019. We plan to adopt as of~~ January 1, ~~2020. We anticipate that ASU 2016-13 will~~2020, which primarily ~~apply~~applied to our short-term trade receivables. ~~While~~There was no cumulative effect adjustment to retained earnings upon adoption.

The majority of our trade receivable balances are due within 30 days. We monitor the credit quality of our counterparties through review of collection trends, credit ratings, and other analysis, such as bankruptcy monitoring. Financial assets are evaluated as one pool. Changes in counterparty risk factors could lead to reassessment of the composition of our financial assets as one pool. We calculate our allowance for credit losses incorporating an aging method. In estimating our expected credit losses, we utilized historical loss rates over many years. Our expected credit loss estimate considered both internal and external forward-looking commodity price expectations, as well as counterparty credit ratings, and factors impacting their near term liquidity.

Past due accounts are generally written off against the allowance for doubtful accounts only after all collection attempts have been exhausted. We do not ~~expect~~have a ~~significant financial impact, we are currently developing additional processes, procedures and internal controls in order to make the necessary credit loss assessments and required disclosures.~~material amount of significantly aged receivables at March 31, 2020.

2. REVENUE RECOGNITION

Revenue by Category

Our revenue disaggregation by major service line includes Natural gas sales, Natural gas transportation, Natural gas storage, and Other, which are separately presented on the Condensed Consolidated Statement of Comprehensive Income.

Contract Liabilities

The following table presents a reconciliation of our contract liabilities:


	Quarter to Date June 30, 2019			Year to Date June 30, 2019			Year to Date March 31, 2020
	(Thousands)						(Thousands)
Balance at beginning of period	$	234,092		$	236,730		$	226,164
Payments received and deferred	—			—			—
Recognized in revenue	(2,641		)	(5,279		)	(2,641		)
Balance at end of period	$	231,451		$	231,451		$	223,523

The following table presents the amount of the contract liabilities balance as of June 30, 2019, expected to be recognized as revenue in each of the next five years as performance obligations are expected to be satisfied:

(Thousands)
2019 (remainder) $ 5,287
2020 10,568
2021 10,566
2022 10,566
2023 10,566
Thereafter 183,898
Total $ 231,451

~~Remaining Performance Obligations~~

~~The following table presents the transaction price allocated to the~~Our remaining performance obligations ~~under certain contracts as of June 30, 2019. These~~ primarily include reservation charges on contracted capacity on our firm transportation and storage contracts with customers. Amounts from certain contracts included in the table below, which are subject to the periodic review and approval by the FERC, reflect the rates for such services in our current FERC tariffs, net of estimated reserve for refund, for the life of the related contracts; however, these rates may change based on future tariffs approved by the FERC and the amount and timing of these changes is not currently known. This table excludes the variable consideration component for commodity charges. ~~It also excludes consideration that will be recognized in future periods (see above for Contract Liabilities and the expected recognition of those amounts within revenue).~~ Certain of our contracts contain evergreen provisions for periods beyond the initial term of the contract. The remaining performance obligations as of ~~June 30, 2019,~~March 31, 2020, do not consider potential future performance obligations for which the renewal has not been exercised. The table below also does not include contracts with customers for which the underlying facilities have not received FERC authorization to be placed into service.

The following table presents the amount of the contract liabilities balance expected to be recognized as revenue when performance obligations are satisfied and the transaction price allocated to the remaining performance obligations under certain contracts as of March 31, 2020.


	(Thousands)		Contract Liabilities		Remaining Performance Obligations
2019 (remainder)	$	1,110,171
2020	2,115,390
			(Thousands)
2020 (remainder)			$	7,928	$	1,701,586
2021	1,994,257		10,566		2,142,316
2022	1,766,701		10,566		2,042,192
2023	1,447,332		10,566		1,607,989
2024			10,568		1,394,930
Thereafter	13,545,469		173,329		12,782,399
Total	$	21,979,320	$	223,523	$	21,671,412

Accounts Receivable

Receivables from contracts with customers are included within Receivables - Trade and other and Receivables - Affiliates ~~and receivables that are not related to contracts with customers are included with~~ ~~Receivables - Advances to affiliate~~ in our Condensed Consolidated Balance Sheet. At ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, Receivables - Trade and other includes ~~$12.6~~$9.2 million and ~~$10.4~~$13.8 million, respectively, of receivables not related to contracts with customers.

3. ~~LEASES~~

We are a lessee through noncancellable lease agreements for property and equipment consisting primarily of buildings, land, vehicles, and equipment used in both our operations and administrative functions. We recognize a lease liability with an offsetting right-of-use asset in our Condensed Consolidated Balance Sheet for operating leases based on the present value of the future lease payments. As an accounting policy, we have elected to combine lease and non-lease components for all classes of leased assets in our calculation of the lease liability and the offsetting right-of-use asset.

Our lease agreements require both fixed and variable periodic payments, with initial terms typically ranging from one year to 15 years, but a certain land lease has a term of 108 years. Payment provisions in certain of our lease agreements contain escalation factors which may be based on stated rates or a change in a published index at a future time. The amount by which a lease escalates based on the change in a published index, which is not known at lease commencement, is considered a variable payment and is not included in the present value of the future lease payments, which only includes those that are stated or can be calculated based on the lease agreement at lease commencement. In addition to the noncancellable periods, many of our lease agreements provide for one or more extensions of the lease agreement for periods ranging from one year in length to an indefinite number of times following the specified contract term. Other lease agreements provide for extension terms that allow us to utilize the identified leased asset for an indefinite period of time so long as the asset continues to be utilized in our operations. In consideration of these renewal features, we assess the term of the lease agreements, which includes using judgment in the determination of which renewal periods and termination provisions, when at our sole election, will be reasonably certain of being exercised. Periods after the initial term or extension terms that allow for either party to the lease to cancel the lease are not considered in the assessment of the lease term. Additionally, we have elected to exclude leases with an original term of one year or less, including renewal periods, from the calculation of the lease liability and the offsetting right-of-use asset.

We used judgment in determining the discount rate upon which the present value of the future lease payments is determined. This rate is based on a collateralized interest rate corresponding to the term of the lease agreement using company, industry, and market information available.

Three Months Ended
June 30, Six Months Ended
June 30,
2019
(Thousands)
Lease Cost:
Operating lease cost $ 2,664
$ 5,166
Short-term lease cost —
—
Variable lease cost 2,732
4,124
Total lease cost $ 5,396
$ 9,290

Cash paid for amounts included in the measurement of operating lease liabilities $ 2,896
$ 5,284

June 30, 2019
(Thousands)
Other Information:
Right-of-use assets $ 91,516
Operating lease liabilities:
Current (included in Accrued liabilities in our Condensed Consolidated Balance Sheet)
$ 3,051
Lease liability $ 87,410
Weighted-average remaining lease term - operating leases (years) 16
Weighted-average discount rate - operating leases 5 %

As of June 30, 2019, the following table represents our operating lease maturities, including renewal provisions that we have assessed as being reasonably certain of exercise, for each of the years ended December 31:

(Thousands)
2019 (remainder) $ 3,987
2020 7,615
2021 9,644
2022 9,625
2023 9,628
Thereafter 92,848
Total future lease payments 133,347
Less amount representing interest 42,886
Total obligations under operating leases $ 90,461

4. CONTINGENT LIABILITIES AND COMMITMENTS

Rate Matters

General rate case (Docket No. RP18-1126) On August 31, 2018, we filed a general rate case with the FERC for an overall increase in rates and to comply with the terms of the settlement in our prior rate case to file a rate case no later than August 31, 2018. On September 28, 2018, the FERC issued an order accepting and suspending our general rate filing to be effective March 1, 2019, subject to refund and the outcome of a hearing, except that rates for certain services that were proposed as overall rate decreases were accepted, without suspension, to be effective October 1, 2018. The decreased rates will not be subject to refund but may be subject to decrease prospectively under Section 5 of the Natural Gas Act of 1938, as amended. On March 18, 2019, the FERC accepted our motion to place the rates that were suspended by the September 28, 2018 order into effect on March 1, 2019, subject to refund. ~~As of~~On December 31, 2019, we filed a stipulation and agreement with the FERC to resolve all issues in this proceeding without the need for a hearing. On March 24, 2020, the FERC approved the settlement, which will become effective on June ~~30,~~

~~2019,~~1, 2020. At March 31, 2020, we have accrued ~~a reserve for rate refunds of~~ approximately ~~$85.9~~$248.3 million related to Docket No. RP18-1126, which we believe is adequate for any refunds that may be required.

~~Notice of Inquiry (Docket No. PL19-4-000)~~ On March 21, 2019, the FERC issued a Notice of Inquiry (NOI) in Docket No. PL19-4-000, seeking comments regarding whether and, if so, how FERC should revise its policies for determining the base return on equity (ROE) used in setting rates charged by jurisdictional public utilities. FERC also seeks comment on, among other things, whether FERC should change its ROE policies for interstate natural gas and oil pipelines to align with is policy for electric public utilities. FERC's action follows a decision from the United States Court of Appeals for the District of Columbia Circuit, which vacated and remanded a series of earlier FERC orders establishing a new base ROE for certain electric transmission owners. Following that decision, FERC proposed in the remanded proceedings that it rely on four financial models to establish ROEs for the affected utilities rather than rely primarily on its long-used, two-step Discounted Cash Flow model. In the NOI, FERC poses a series of questions and invited comments on this proposed new approach, including whether it should apply the new approach to future proceedings involving interstate natural gas and oil pipeline ROEs. We are currently monitoring this proceeding.

~~Station 62 Incident~~

On October 8, 2015, an explosion and fire occurred at our Compressor Station No. 62 in Gibson, Louisiana. At the time of the incident, planned facility maintenance was being performed at the station and the facility was not operational. The incident was related to maintenance work being performed on the slug catcher at the station. Four contractor employees were killed in the incident and others were injured.

In responding to the incident, we cooperated with local, state and federal authorities, including the Louisiana State Police, Terrebonne Parish, the Louisiana Department of Environmental Quality, the U.S. Environmental Protection Agency (Region 6), the Occupational Safety and Health Administration, and the U.S. Department of Transportation's Pipeline and Hazardous Materials Safety Administration (PHMSA). On July 29, 2016, PHMSA issued a Notice of Probable Violation (NOPV), which includes a $1.6 million proposed civil penalty to us in connection with the incident. This penalty was accrued in the second quarter of 2016 and would not be covered by our insurance policies. We filed a response to the NOPV on August 25, 2016, and on July 14, 2017, PHMSA held a hearing on the NOPV. On December 20, 2018, the PHMSA issued a Final Order, which made findings of violation, reduced the civil penalty to $1.4 million, and specified actions that need to be taken by us to comply with pipeline safety regulations.

The incident did not cause any rupture of the gas pipeline or any damage to the building containing the compressor engines. In anticipation of the planned maintenance, our Southeast Louisiana Lateral was taken out of service on October 4, 2015, which affected approximately 200 MMcf/d of natural gas production. The lateral was restored to service in early 2016 after repairs were made to the facilities damaged in the incident.

We, with the insurer of one of our contractors, have settled all claims against us for wrongful death and all but one of the claims for personal injury. In addition, we are a defendant in other lawsuits seeking damages for off-site property damages. We believe it is reasonably possible that losses will be incurred on some of these remaining lawsuits. However, in management's judgment, the ultimate resolution of these matters will not have a material effect on our financial condition, results of operations, or cash flows. While we also have claims for indemnification, we continue to believe that it is probable that any ultimate losses incurred will be covered by our contractors' insurance and our insurance.

Environmental Matters

We have had studies underway for many years to test some of our facilities for the presence of toxic and hazardous substances such as polychlorinated biphenyls (PCBs) and mercury to determine to what extent, if any, remediation may be necessary. We have also similarly evaluated past on-site disposal of hydrocarbons at a number of our facilities. We have worked closely with and responded to data requests from the U.S. Environmental Protection Agency (EPA) and state agencies regarding such potential contamination of certain of our sites. We are conducting environmental assessments and implementing a variety of remedial measures that may result in increases or decreases in the total estimated costs. At ~~June 30,~~March 31, 2020, and December 31, 2019, we had a balance of approximately ~~$3.1~~$2.5 million for the expense portion of these estimated costs, ~~$1.3~~$1.2 million recorded in Accrued liabilities and ~~$1.8 million recorded in~~ ~~Other Long-Term Liabilities - Other~~ ~~in the accompanying Condensed Consolidated Balance Sheet. At December 31, 2018, we had a balance of~~

~~approximately $3.5 million for the expense portion of these estimated costs, $1.5 million recorded in~~ ~~Accrued liabilities~~ ~~and $2.0~~$1.3 million recorded in Other Long-Term Liabilities - Other in the accompanying Condensed Consolidated Balance Sheet.

We have been identified as a potentially responsible party (PRP) at various Superfund and state waste disposal sites. Based on present volumetric estimates and other factors, our estimated aggregate exposure for remediation of these sites is less than $0.5 million. The estimated remediation costs for all of these sites are included in the environmental

liabilities discussed above. Liability under the Comprehensive Environmental Response, Compensation and Liability Act and applicable state law can be joint and several with other PRPs. Although volumetric allocation is a factor in assessing liability, it is not necessarily determinative; thus, the ultimate liability could be substantially greater than the amounts described above.

The EPA and various state regulatory agencies routinely promulgate and propose new rules, and issue updated guidance to existing rules. These rulemakings include, but are not limited to, rules for reciprocating internal combustion engine and combustion turbine maximum achievable control technology, air quality standards for one-hour nitrogen dioxide emissions, and volatile organic compound and methane new source performance standards impacting design and operation of storage vessels, pressure valves, and compressors. The EPA previously issued its rule regarding National Ambient Air Quality Standards for ground-level ozone. We are monitoring the rule’s implementation as it will trigger additional federal and state regulatory actions that may impact our operations. Implementation of the regulations is expected to result in impacts to our operations and increase the cost of additions to Total property, plant and equipment, net in the Condensed Consolidated Balance Sheet for both new and existing facilities in affected areas. We are unable to reasonably estimate the cost of additions that may be required to meet the regulations at this time due to uncertainty created by various legal challenges to these regulations and the need for further specific regulatory guidance.

We consider prudently incurred environmental assessment and remediation costs and the costs associated with compliance with environmental standards to be recoverable through rates. To date, we have been permitted recovery of environmental costs, and it is our intent to continue seeking recovery of such costs through future rate filings.

Other Matters

Various other proceedings are pending against us and are considered incidental to our operations.

Summary

We estimate that for all matters for which we are able to reasonably estimate a range of loss, including those noted above and others that are not individually significant, our aggregate reasonably possible losses beyond amounts accrued for all of our contingent liabilities are immaterial to our expected future annual results of operations, liquidity and financial position. These calculations have been made without consideration of any potential recovery from third parties. We have disclosed all significant matters for which we are unable to reasonably estimate a range of possible loss.

5.4. DEBT AND FINANCING ARRANGEMENTS

Credit Facility

We, along with Williams and Northwest Pipeline LLC (Northwest) (the “borrowers”), are party to a Credit Agreement with aggregate commitments available of $4.5 billion, with up to an additional $500 million increase in aggregate commitments available under certain circumstances. We and Northwest are each subject to a $500 million borrowing sublimit. Letter of credit commitments of ~~$1.0~~$1 billion are, subject to the $500 million borrowing sublimit applicable to us and Northwest, available to the borrowers. At ~~June 30, 2019, no~~March 31, 2020, 0 letters of credit have been issued and no loans to Williams of $1.7 billion were outstanding under the credit facility.

Williams participates in a commercial paper program and Williams management considers amounts outstanding under this program to be a reduction of available capacity under the credit facility. The program allows a maximum outstanding amount at any time of ~~$4.0~~$4 billion of unsecured commercial paper notes. At ~~June 30, 2019,~~March 31, 2020, Williams had no0 outstanding commercial paper.

Other Financing Obligations

Dalton Expansion Project

During the first six months of 2019, we received an additional $0.7 million of funding from a co-owner for its proportionate share of construction costs related to its undivided ownership interest in the Dalton lateral. This additional funding is reflected in ~~Long-Term Debt~~ ~~on our Condensed Consolidated Balance Sheet.~~ At ~~June 30, 2019,~~March 31, 2020, the amount included in Long-Term Debt on our Condensed Consolidated Balance Sheet for this financing obligation is ~~$257.8~~$256.2 million, and the amount included in Long-term debt due within one year on our Condensed Consolidated Balance Sheet for this financing obligation is ~~$2.0~~$2.1 million.

Atlantic Sunrise Project

During the first ~~six~~three months of ~~2019,~~2020, we received an additional ~~$19.7~~$1.7 million of funding from a co-owner for its proportionate share of construction costs related to its undivided ownership interest in certain parts of the project. This additional funding is reflected in Long-Term Debt on our Condensed Consolidated Balance Sheet. At ~~June 30, 2019,~~March 31, 2020, the amount included in Long-Term Debt on our Condensed Consolidated Balance Sheet for this financing obligation is ~~$805.0~~$835.9 million, and the amount included in Long-term debt due within one year on our Condensed Consolidated Balance Sheet for this financing obligation is ~~$14.9~~$18.5 million.

Long-Term Debt Due Within One Year

The long-term debt due within one year at ~~June 30, 2019~~March 31, 2020 is associated with the previously described other financing obligations.

6.5. ARO TRUST

We are entitled to collect in rates the amounts necessary to fund our asset retirement obligations (ARO). We deposit monthly, into an external trust account (ARO Trust), the revenues specifically designated for ARO. The ARO Trust carries a moderate risk portfolio. The Money Market Funds held in our ARO Trust are considered investments. We measure the financial instruments held in our ARO Trust at fair value. However, in accordance with the ASC Topic 980, Regulated Operations, both realized and unrealized gains and losses of the ARO Trust are recorded as regulatory assets or liabilities.

Effective March 1, 2019, the annual funding obligation based on the Docket No. RP18-1126 rate case filing was approximately $35.9 million. Pursuant to the approved stipulation and agreement in Docket No. RP18-1126, the new funding obligation 1) effective March 1, 2019 is approximately ~~$35.9~~$23.8 million, ~~with deposits made monthly.~~and 2) effective March 1, 2020 is approximately $16.0 million.

Investments within the ARO Trust at fair value were as follows (in millions):


	June 30, 2019				December 31, 2018				March 31, 2020				December 31, 2019
	Amortized Cost Basis		Fair Value		Amortized Cost Basis		Fair Value		Amortized Cost Basis		Fair Value		Amortized Cost Basis		Fair Value
Money Market Funds	$	19.0	$	19.0	$	21.7	$	21.7	$	22.4	$	22.4	$	15.8	$	15.8
U.S. Equity Funds	54.7		75.8		46.4		56.8		63.3		74.5		55.3		83.3
International Equity Funds	25.4		27.6		21.9		21.4		36.8		32.3		31.8		35.4
Municipal Bond Funds	59.3		60.4		50.1		49.6		58.2		59.0		64.7		66.1
Total	$	158.4	$	182.8	$	140.1	$	149.5	$	180.7	$	188.2	$	167.6	$	200.6

7.6. FAIR VALUE MEASUREMENTS

The following table presents, by level within the fair value hierarchy, certain of our financial assets and liabilities. The carrying values of short-term financial assets (advances to and from affiliate) that have variable interest rates, accounts receivable and accounts payable approximate fair value because of the short-term nature of these instruments. Therefore, these assets and liabilities are not presented in the following table.


							Fair Value Measurements Using													Fair Value Measurements Using
	Carrying Amount			Fair Value			Quoted Prices In Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)		Carrying Amount			Fair Value			Quoted Prices In Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)
	(Millions)													(Millions)
Assets (liabilities) at June 30, 2019:
Assets (liabilities) at March 31, 2020:
Measured on a recurring basis:
ARO Trust investments	$	182.8		$	182.8		$	182.8	$	—		$	—	$	188.2		$	188.2		$	188.2	$	—		$	—

Additional disclosures:
Long-term debt, including current portion	(4,027.8		)	(5,177.1		)	—		(5,177.1		)	—		(4,062.3		)	(4,634.9		)	—		(4,634.9		)	—

Assets (liabilities) at December 31, 2018:
Assets (liabilities) at December 31, 2019:
Measured on a recurring basis:
ARO Trust investments	$	149.5		$	149.5		$	149.5	$	—		$	—	$	200.6		$	200.6		$	200.6	$	—		$	—

Additional disclosures:
Long-term debt, including current portion	(4,014.4		)	(4,785.5		)	—		(4,785.5		)	—		(4,065.0		)	(5,251.4		)	—		(5,251.4		)	—

Fair Value Methods

The following methods and assumptions were used to estimate the fair value of each class of financial instruments for which it is practicable to estimate that value:

ARO Trust investments — We deposit a portion of our collected rates, pursuant to the terms of the Docket No. RP18-1126 rate case settlement, into the ARO Trust which is specifically designated to fund future asset retirement obligations. The ARO Trust invests in a portfolio of actively traded mutual funds that are measured at fair value on a recurring basis based on quoted prices in an active market and are reported in Other Assets-Other in the Condensed Consolidated Balance Sheet. However, both realized and unrealized gains and losses are ultimately recorded as regulatory assets or liabilities. See Note 65 for more information regarding the ARO Trust.

Long-term debt — The disclosed fair value of our long-term debt is determined primarily by a market approach using broker quoted indicative period-end bond prices. The quoted prices are based on observable transactions in less active markets for our debt or similar instruments. The fair value of the financing obligations associated with our Dalton and Atlantic Sunrise expansions, which are included within long-term debt, were determined using an income approach (See Note 5)4).

Reclassifications of fair value between Level 1, Level 2, and Level 3 of the fair value hierarchy, if applicable, are made at the end of each quarter. No transfers between Level 1 and Level 2 occurred during the six months ended June 30, 2019 or 2018.

8.7. TRANSACTIONS WITH AFFILIATES

We are a participant in Williams' cash management program, and we receive advances from and make advances to Williams. At ~~June 30,~~March 31, 2020 and December 31, 2019, our advances from Williams totaled approximately ~~$34.3~~$316.9 million and $252.5 million, respectively. These advances are classified as Payables - Advances from ~~affiliates~~ ~~in the accompanying Condensed Consolidated Balance Sheet. At December 31, 2018, our advances to Williams totaled approximately $33.0 million and are classified as~~ ~~Receivables - Advances to~~ affiliate in the accompanying Condensed Consolidated Balance Sheet. Advances are stated at the historical carrying amounts. ~~Interest income and expense are recognized when chargeable and collectability is reasonably assured.~~ The interest rate on these intercompany demand notes is based upon the daily overnight investment rate paid on Williams' excess cash at the end of each month. At ~~June 30, 2019,~~March 31, 2020, the interest rate was ~~2.27~~0.27 percent.

Included in Operating Revenues in the accompanying Condensed Consolidated Statement of Comprehensive Income are revenues received from affiliates of ~~$2.3 million and $5.6 million for the three and six months ended June 30,~~

~~2019, respectively, and $1.5~~$2.6 million and $3.3 million for the three ~~and six~~ months ended ~~June 30, 2018,~~March 31, 2020 and 2019, respectively. The rates charged to provide sales and services to affiliates are the same as those that are charged to similarly-situated nonaffiliated customers.

Included in Cost of natural gas sales in the accompanying Condensed Consolidated Statement of Comprehensive Income are cost of gas purchased from affiliates of ~~$0.6~~$2.5 million and ~~$2.2~~$1.6 million for the three ~~and six~~ months ended ~~June 30,~~March 31, 2020 and 2019, ~~respectively, and $1.8 million and $3.7 million for the three and six months ended June 30, 2018,~~ respectively. All gas purchases are made at market or contract prices.

We have no0 employees. Services necessary to operate our business are provided to us by Williams and certain affiliates of Williams. We reimburse Williams and its affiliates for all direct and indirect expenses incurred or payments made (including salary, bonus, incentive compensation and benefits) in connection with these services. Employees of Williams also provide general, administrative and management services to us, and we are charged for certain administrative expenses incurred by Williams. These charges are either directly identifiable or allocated to our assets. Direct charges are for goods and services provided by Williams at our request. Allocated charges are based on a three-factor formula, which considers revenues; property, plant and equipment; and payroll. In management’s estimation, the allocation methodologies used are reasonable and result in a reasonable allocation to us of our costs of doing business incurred by Williams. We were billed ~~$112.4~~$86.9 million and ~~$204.6~~$92.2 million in the three ~~and six~~ months ended ~~June 30,~~March 31, 2020, and 2019, ~~respectively, and $99.3 million and $190.8 million in the three and six months ended June 30, 2018,~~ respectively, for these services. Such expenses are primarily included in Operation and maintenance and Administrative and general expenses in the accompanying Condensed Consolidated Statement of Comprehensive Income. The amount billed to us for the six months ended June 30, 2019, includes $12.9 million recognized in the second quarter for estimated severance and related costs driven by a voluntary separation program associated with a review of Williams' enterprise cost structure.

We provide services to certain of our affiliates. We recorded reductions in operating expenses for services provided to and reimbursed by our affiliates of ~~$1.1~~$1.0 million and ~~$2.3~~$1.2 million for the three ~~and six~~ months ended ~~June 30,~~March 31, 2020, and 2019, ~~respectively, and $1.2 million and $2.2 million for the three and six months ended June 30, 2018,~~ respectively.

We made equity distributions totaling ~~$346.0~~$270.0 million and ~~$190.0~~$176.0 million during the ~~six~~three months ended ~~June 30,~~March 31, 2020 and 2019, ~~and 2018,~~ respectively. ~~During July 2019, we made an additional distribution of $213.0 million. Our parent made contributions to us totaling~~ ~~$340.0 million~~ ~~in the six months ended June 30, 2018, to fund a portion of our expenditures for additions to property, plant and equipment.~~



ITEM 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations

General

The following discussion should be read in conjunction with the Consolidated Financial Statements, Notes and Management’s Discussion and Analysis contained in Items 7 and 8 of our ~~2018~~2019 Annual Report on Form 10-K and with the Condensed Consolidated Financial Statements and Notes contained in this Form 10-Q.

Filing of Rate Case

On August 31, 2018, we filed a general rate case with the FERC for an overall increase in rates and to comply with the terms of the settlement in our prior rate case to file a rate case no later than August 31, 2018. On September 28, 2018, the FERC issued an order accepting and suspending our general rate filing to be effective March 1, 2019, subject to refund and the outcome of a hearing, except that rates for certain services that were proposed as overall rate decreases were accepted, without suspension, to be effective October 1, 2018. The decreased rates will not be subject to refund but may be subject to decrease prospectively under Section 5 of the Natural Gas Act of 1938, as amended. On March 18, 2019, the FERC accepted our motion to place the rates that were suspended by the September 28, 2018 order into effect on March 1, 2019, subject to refund. On December 31, 2019, we filed a stipulation and agreement with the FERC to resolve all issues in this proceeding without the need for a hearing. On March 24, 2020, the FERC approved the settlement, which will become effective on June 1, 2020. We have provided a reserve for rate refunds which we believe is adequate for any refunds that may be required.

~~Critical Accounting Estimates~~

In December 2017, Tax Reform was enacted, which, among other things, reduced the corporate income tax rate from 35 percent to 21 percent. Rates charged to our customers are subject to the rate-making policies of the FERC, which have historically permitted the recovery of an income tax allowance that includes a deferred income tax component. As a result of the reduced income tax rate from Tax Reform and the collection of historical rates that reflected historical federal income tax rates, we expect that we will be required to return amounts to certain customers through future rates and have accordingly established a regulatory liability totaling $422.2 million as of June 30, 2019 and $450.2 million as of December 31, 2018. Effective March 1, 2019, we began amortizing this regulatory liability. The timing and actual amount of such return will be subject to the outcome of the rate case proceeding filed in Docket No. RP18-1126.

RESULTS OF OPERATIONS

Operating Income and Net Income

Operating Income for the ~~six~~three months ended ~~June 30, 2019~~March 31, 2020 was ~~$564.3~~$339.8 million compared to $~~402.6~~290.3 million for the ~~six~~three months ended ~~June 30, 2018~~March 31, 2019. The increase in Operating Income of ~~$161.7~~$49.5 million ~~(40.2~~(17.1 percent) was primarily due to higher ~~Operating Revenues~~Natural gas transportation revenues in the first ~~six~~three months of ~~2019~~2020 compared to the same period in ~~2018, as discussed below, partly offset by an increase~~2019, and a favorable change in Operating Costs and Expenses, as discussed below. Net Income for the ~~six~~three months ended ~~June 30, 2019~~March 31, 2020 was ~~$441.6~~$278.0 million compared to ~~$372.1~~$229.7 million for the ~~six~~three months ended ~~June 30, 2018.~~March 31, 2019. The increase in Net Income of ~~$69.5~~$48.3 million ~~(18.7~~(21.0 percent) was mostly attributable to the increase in Operating Income ~~partially offset by an unfavorable change in net expenses in~~ ~~Other (Income) and Other Expenses~~, as discussed below.

Operating Revenues

Natural gas sales decreased ~~$8.6~~$4.4 million ~~(15.6~~(18.4 percent) for the ~~six~~three months ended ~~June 30, 2019~~March 31, 2020 compared to the same period in ~~2018.~~2019. The decrease was primarily due to ~~$4.3~~$4.4 million of lower cash out ~~sales and $4.3 million of lower system management gas~~ sales. Cash out ~~sales and system management gas~~ sales are offset in our cost of natural gas sold and therefore have no impact on our operating income or ~~results of operations.~~net income.

Natural gas transportation for the ~~six~~three months ended ~~June 30, 2019~~March 31, 2020 increased ~~$218.0~~$31.8 million ~~(25.9~~(6.0 percent) over the same period in ~~2018~~2019. The increase was primarily attributable to:

$~~218.9~~13.2 million ~~increase in transportation reservation revenues~~ related to implementation of new ~~incremental projects primarily attributable to:~~rates;

$~~194.6~~6.4 million from our ~~Atlantic Sunrise project placed in full service in October 2018;~~

~~$17.8 million from our Gulf Connector~~Rivervale South to Market project placed in service in ~~January~~September 2019; ~~and~~

$~~4.8~~5.6 million due to an additional billing day in 2020;

$4.1 million from our ~~Garden State~~Gateway project placed in ~~full~~ service in ~~March 2018.~~December 2019;

$~~6.1~~2.0 million ~~higher recoveries of~~and related to short-term firm transportation and commodity revenue; and

$1.7 million from our St. James project placed into service in April 2019.

Partially offset by $1.2 million lower electric power costs. Electric power costs are recovered from our customers through transportation rates resulting in no net impact on our operating income or results of operations.

~~$4.7 million higher commodity revenue.~~

~~Partially offset by $11.7 million lower revenues related to Docket No. RP18-1126 rate decreases effective October 1, 2018.~~

~~Natural gas storage~~ ~~increased $6.0 million (8.7 percent) for the six months ended June 30, 2019 compared to the same period in 2018. The increase was primarily due to the implementation of new rates in March 2019.~~

Operating Costs and Expenses

Excluding the Cost of natural gas sales, which is directly offset in revenues, ~~of $46.5 million for the~~ ~~six~~ ~~months ended~~ ~~June 30, 2019~~ ~~and $55.1 million for the comparable period in~~ ~~2018~~, our operating costs and expenses decreased approximately $14.8 million (5.2 percent) for the ~~six~~three months ended ~~June 30, 2019~~March 31, 2020 ~~increased $62.9 million (12.3 percent) from~~to the comparable period in ~~2018~~.2019. This ~~increase~~decrease was primarily attributable to:


•	$~~35.3~~10.1 million ~~(20.5~~(75.4 percent) favorable change in Other expenses, net primarily due to a $3.7 million decrease in pension regulatory charge, and $4.4 million decrease due to additional deferral of ARO related depreciation;


•	$6.0 million (12.4 percent) favorable change in Administrative and general costs primarily due to lower corporate allocated expenses; and


•	$5.9 million (339.6 percent) favorable change in Regulatory credit resulting from Tax Reform primarily related to general rate case Docket No. RP18-1126.


•	Partially offset by $9.0 million (8.6 percent) increase in Depreciation and amortization costs primarily resulting from ~~additional assets placed into service;~~


•	~~$13.9 million (66.5 percent) unfavorable change in~~ ~~Regulatory credit resulting from Tax Reform~~;

•

~~$12.1 million (13.0 percent) increase in~~ ~~Administrative and general~~ ~~costs primarily due to a $7.6~~$4.4 million increase in ~~employee labor~~ARO asset depreciation, and related benefits costs mainly due to estimated severance and related costs driven by a voluntary separation program (VSP) associated with a review of Williams' enterprise cost structure, and a $2.4 million higher allocated corporate expenses;


•	~~$3.3 million (9.3 percent) increase in~~ ~~Taxes - other than income taxes~~ ~~primarily due to higher ad valorem taxes as a result of additional assets placed into service;~~


•	~~$2.1 million (9.8 percent) increase in~~ ~~Cost of natural gas transportation~~ costs primarily resulting from $6.1 million higher electric power costs, partly offset by $4.1 million lower fuel costs. Electric power costs are recovered from customers through transportation rates resulting in no net impact on our operating income or results of operations; and

•

~~$0.9 million (0.5 percent) increase in~~ ~~Operation and maintenance~~ ~~costs primarily resulting from a $10.7~~$3.8 million increase in employee labor and related benefit costs ($5.1 million due to estimated severance and related costs driven by a VSP associated with a review of Williams' enterprise cost structure, and $4.8 million due to lower capitalized labor as a result of fewer capital projects ongoing in 2019) and a $9.4 million increase in contracted services related to costs transferred from capital, mostly offset by a $17.8 million decrease in contracted services mainly related to general maintenance and other testing on our pipeline.


•	~~Partially offset by $4.7 million (15.5 percent) decrease in~~ ~~Other expenses, net~~ primarily due to a $13.2 million favorable change in costs associated with pension and other postretirement benefits related to Docket No. RP18-1126, partly offset by a $6.6 million unfavorable change related to costs transferred from capital and certain other charges.asset depreciation.

~~Other (Income)~~Recent Developments

COVID-19

The outbreak of novel coronavirus (COVID-19) has severely impacted global economic activity and ~~Other Expenses~~caused significant volatility and negative pressure in financial markets. We are monitoring the COVID-19 pandemic and are taking steps intended to protect the safety of our customers, employees and communities, and to support the continued delivery of safe and reliable service to our customers and the communities we serve. We are continuing to monitor developments with respect to the outbreak and note the following:

~~Other (income)~~Our financial condition, results of operations, and ~~other expenses~~ ~~for~~liquidity have not been materially impacted by direct effects of COVID-19.

We believe we have the ~~six~~ ~~months ended~~ ~~June 30, 2019~~ ~~had an unfavorable change~~ability to access the debt market if necessary, and continue to have significant levels of ~~$92.3 million (303.6 percent)~~unused capacity on our revolving credit facility with no significant debt maturities in the near future.

We have implemented remote working arrangements where possible and restricted business-related travel. Implementation of these measures has not required material expenditures or significantly impacted our ability to operate our business.

Our remote working arrangements have not significantly impacted our internal controls over ~~the same period in~~ ~~2018. This is mostly due to an unfavorable change of $45.3 million in~~ ~~Allowance for equity~~financial reporting and ~~borrowed funds used during construction (AFUDC)~~ ~~primarily associated with reduced capital expenditures on projects~~disclosure controls and ~~a $43.7 million increase in~~ ~~Interest expense~~ ~~primarily due to other financing obligations.~~procedures.

Pipeline Expansion Projects

Hillabee

The Hillabee Expansion Project involves an expansion of our existing natural gas transmission system from our Station 85 Pooling Point in Choctaw County, Alabama to ~~a new~~an interconnection with the Sabal Trail pipeline in Tallapoosa County, Alabama. The project is being constructed in phases, and all of the project expansion capacity is dedicated to Sabal Trail pursuant to a capacity lease agreement. Phase I was completed in 2017 and it increased capacity by 818 Mdth/d. ~~The in-service date of~~We placed Phase II ~~is planned for the second quarter of~~into service on May 1, 2020. Together, the first two phases of the project ~~are expected to increase~~increased capacity by 1,025 Mdth/d.

~~Gulf Connector~~

The Gulf Connector Expansion Project involved an expansion of our existing natural gas transmission system to provide incremental firm transportation capacity from Station 65 in Louisiana to delivery points in Wharton and San Patricio Counties, Texas. We placed the project into service on January 4, 2019. The project increased capacity by 475 Mdth/d.

Northeast Supply Enhancement

The Northeast Supply Enhancement Project involves an expansion of our existing natural gas transmission system to provide incremental firm transportation capacity from Station 195 in Pennsylvania to the Rockaway Delivery Lateral transfer point in New York. In May 2019, we received approval from the FERC for the project. Approvals required for the project from the New York State Department of Environmental Conservation and the New Jersey Department of Environmental Protection remain pending, with each such agency having denied, without prejudice, Transco's applications for such approvals. We have refiled our applications for those approvals and ~~are addressing certain~~have addressed the technical issues identified by the agencies. We plan to place the project into service in the ~~fourth quarter~~fall of ~~2020,~~2021, assuming timely receipt of these remaining approvals. The project is expected to increase capacity by 400 ~~Mdth/d.~~

~~Rivervale South to Market~~

The Rivervale South to Market Project involves an expansion of our existing natural gas transmission system to provide incremental firm transportation capacity from the existing Rivervale interconnection with Tennessee Gas Pipeline on our North New Jersey Extension to our existing Central Manhattan meter station in New Jersey and our Station 210 Pooling Point in New Jersey. In August 2018, we received approval from the FERC for the project. The project was placed into partial service on July 1, 2019. We plan to place the remaining portion of the project into service by the fourth quarter of 2019, assuming timely receipt of all necessary regulatory approvals. The project is expected to increase capacity by 190 Mdth/d.

~~Gateway~~

The Gateway Project involves an expansion of our existing natural gas transmission system to provide incremental firm transportation capacity from PennEast Pipeline Company's proposed interconnection with our mainline south of Station 205 in New Jersey to our existing Ridgefield meter station in Bergen County, New Jersey and our existing Paterson meter station in Passaic County, New Jersey. In December 2018, we received approval from the FERC for the project. We plan to place the project into service in the first half of 2020, assuming timely receipt of all necessary regulatory approvals. The project is expected to increase capacity by 65 Mdth/d.

Southeastern Trail

The Southeastern Trail Project involves an expansion of our existing natural gas transmission system to provide incremental firm transportation capacity from the Pleasant Valley interconnect with Dominion's Cove Point Pipeline in Virginia to the Station 65 Pooling Point in Louisiana. ~~We filed an application with~~In October 2019, we received approval from the FERC ~~in April 2018~~ for ~~approval of~~ the project. We plan to place the project into service in late ~~2020, assuming timely receipt of all necessary regulatory approvals.~~2020. The project is expected to increase capacity by 296 Mdth/d.

Leidy South

The Leidy South Project involves an expansion of our existing natural gas transmission system and an extension of our system through a capacity lease with National Fuel Gas Supply Corporation that will enable us to provide incremental firm transportation from Clermont, Pennsylvania and from the Zick interconnection on Transco's Leidy Line to the River

Road regulating station in Lancaster County, Pennsylvania. We filed an application with the FERC in July 2019 for approval of the project. We plan to place the project into service inas early as the ~~second half~~fourth quarter of ~~2022,~~2021, assuming timely receipt of all necessary regulatory approvals. The project is expected to increase capacity by 582 Mdth/d.

~~South Louisiana Market~~

The South Louisiana Market Project involves an expansion of our existing natural gas transmission system to provide incremental firm transportation capacity from Station 65 in Louisiana to a new interconnection with a proposed chemical plant in St. James Parish, Louisiana. We expect to file an application with the FERC in August 2019 for approval of the project. We plan to place the project into service in the fourth quarter of 2022, assuming timely receipt of all necessary regulatory approvals. The project is expected to increase capacity by 202 Mdth/d.



ITEM 4.	Controls and Procedures

Our management, including our Senior Vice President and our Vice President and Chief Accounting Officer, does not expect that our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934 as amended) (Disclosure Controls) or our internal control over financial reporting (Internal Controls) will prevent all errors and all fraud. A control system, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Because of the inherent limitations in all control systems, no evaluation of controls can provide absolute assurance that all control issues and instances of fraud, if any, within the company have been detected. These inherent limitations include the realities that judgments in decision-making can be faulty, and that breakdowns can occur because of simple error or mistake. Additionally, controls can be circumvented by the individual acts of some persons, by collusion of two or more people, or by management override of the control. The design of any system of controls also is based in part upon certain assumptions about the likelihood of future events, and there can be no assurance that any design will succeed in achieving its stated goals under all potential future conditions. Because of the inherent limitations in a cost-effective control system, misstatements due to error or fraud may occur and not be detected. We monitor our Disclosure Controls and Internal Controls and make modifications as necessary; our intent in this regard is that the Disclosure Controls and Internal Controls will be modified as systems change and conditions warrant.

Evaluation of Disclosure Controls and Procedures

An evaluation of the effectiveness of the design and operation of our Disclosure Controls was performed as of the end of the period covered by this report. This evaluation was performed under the supervision and with the participation of our management, including our Senior Vice President and our Vice President and Chief Accounting Officer. Based upon that evaluation, our Senior Vice President and our Vice President and Chief Accounting Officer concluded that these Disclosure Controls are effective at a reasonable assurance level.

Changes in Internal Control Over Financial Reporting

There have been no changes during the ~~second~~first quarter of ~~2019~~2020 that have materially affected, or are reasonably likely to materially affect, our Internal Control over Financial Reporting.

PART II — OTHER INFORMATION.



ITEM 1.	Legal Proceedings

Environmental

On May 5, 2017, we entered into a Consent Order with the Georgia Department of Natural Resources, Environmental Protection Division (GADNR) pertaining to alleged violations of the Georgia Water Quality Control Act and associated rules arising from a permit issued by GADNR for construction of Transco’s Dalton expansion project. Pursuant to the Consent Order, we paid a fine of $168,750 and agreed to a Corrective Action Plan. On March 26, 2020, the GADNR issued a closure letter to Transco approving the final Corrective Action Plan implementation and acknowledging that all conditions of the Consent Order have been achieved.

Other

The information called for by this item is provided in Note 43 of the Notes to Condensed Consolidated Financial Statements included under Part I, Item 1. Financial Statements of this report, which information is incorporated by reference into this item.



ITEM 1A.	Risk Factors

Part I, Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, ~~2018,~~2019, includes certain risk factors that could materially affect our business, financial condition, or future results. Those ~~risk factors~~Risk Factors have not materially ~~changed.~~changed except that they are supplemented by the following risk factor:

We face risks related to the COVID-19 pandemic and other health epidemics.

The global outbreak of the novel coronavirus (COVID-19) is currently impacting countries, communities, supply chains and markets. We provide a critical service to our customers, which means that it is paramount that we keep our employees safe. To date, COVID-19 has not had a material impact on our business. However, we cannot predict whether, and the extent to which, COVID-19 will have a material impact on our business, including our liquidity, financial condition, and results of operations. COVID-19 could pose a risk to our employees, our customers, our suppliers and the communities in which we operate, which could negatively impact our business. To the extent that our access to the capital markets is adversely affected by COVID-19, we may need to consider alternative sources of funding for our operations and for working capital, any of which could increase our cost of capital. Measures to try to contain the virus, such as travel bans and restrictions, quarantines, shelter in place orders, and shutdowns, may cause us to experience operational delays or to delay plans for growth. The extent to which COVID-19 may impact our business will depend on future developments, which are highly uncertain and cannot be predicted, including new information concerning the severity of COVID-19 and the actions taken to contain it or treat its impact, among others.

To the extent the COVID-19 pandemic adversely affects our business and financial results, it may also have the effect of heightening many of the other factors described in the Risk Factors disclosed in Part I, Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2019.



ITEM 6.	Exhibits

The following instruments are included as exhibits to this report.



Exhibit Number		Description

2		Certificate of Conversion dated December 22, 2008 and effective December 31, 2008 (filed on February 24, 2011 as Exhibit 2.1 to our annual report on Form 10-K (File No. 001-07584) and incorporated herein by reference).

3.1		Certificate of Formation dated December 22, 2008 and effective December 31, 2008 (filed on February 24, 2011 as Exhibit 3.1 to our annual report on Form 10-K (File No. 001-07584) and incorporated herein by reference).

3.2		Amended and Restated Operating Agreement of Transcontinental Gas Pipe Line Company, LLC dated February 17, 2010 (filed on October 28, 2010 as Exhibit 3.2 to our quarterly report on Form 10-Q (File No. 001-07584) and incorporated herein by reference).

31.1*		Certification of Principal Executive Officer pursuant to Rules 13a-14(a) and 15d-14(a) promulgated under the Securities Exchange Act of 1934, as amended, and Item 601(b)(31) of Regulation S-K, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

31.2*		Certification of Principal Financial Officer pursuant to Rules 13a-14(a) and 15d-14(a) promulgated under the Securities Exchange Act of 1934, as amended, and Item 601(b)(31) of Regulation S-K, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

32**		Certification of Principal Executive Officer and Principal Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

101.INS*		XBRL Instance Document. The instance document does not appear in the interactive data file because its XBRL tags are embedded within the inline XBRL document.

101.SCH*		XBRL Taxonomy Extension Schema.

101.CAL*		XBRL Taxonomy Extension Calculation Linkbase.

101.DEF*		XBRL Taxonomy Extension Definition Linkbase.

101.LAB*		XBRL Taxonomy Extension Label Linkbase.

101.PRE*		XBRL Taxonomy Extension Presentation Linkbase.

104*		Cover Page Interactive Data File. The cover page interactive data file does not appear in the interactive data file because its XBRL tags are embedded within the inline XBRL document (contained in Exhibit 101).



*	Filed herewith.
**	Furnished herewith.

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.



		TRANSCONTINENTAL GAS PIPE LINE COMPANY, LLC (Registrant)

Dated:	~~August 1, 2019~~May 4, 2020	By:	/s/ ~~Kathleen R. Hambleton~~Billeigh Mark
			~~Kathleen R. Hambleton~~Billeigh Mark
			Controller
			(Principal Accounting Officer)



	(Thousands)
2019 (remainder)	$	5,287
2020	10,568
2021	10,566
2022	10,566
2023	10,566
Thereafter	183,898
Total	$	231,451



	(Thousands)
2019 (remainder)	$	3,987
2020	7,615
2021	9,644
2022	9,625
2023	9,628
Thereafter	92,848
Total future lease payments	133,347
Less amount representing interest	42,886
Total obligations under operating leases	$	90,461