10-Q

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 March 31, 2020

OR

☐ 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)

Delaware		74-1079400
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)
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 þ 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.

TRANSCONTINTENTAL GAS PIPE LINE COMPANY, LLC

Index

	Page
Part I. Financial Information:
Item 1. Financial Statements
Condensed Consolidated Statement of Comprehensive Income —Three Months Ended March 31, 2020 and 2019	4
Condensed Consolidated Balance Sheet — March 31, 2020 and December 31, 2019	5
Condensed Consolidated Statement of Member's Equity — Three Months Ended March 31, 2020 and 2019	7
Condensed Consolidated Statement of Cash Flows — Three Months Ended March 31, 2020 and 2019	8
Notes to Condensed Consolidated Financial Statements	9
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	16
Item 4. Controls and Procedures	19
Part II. Other Information	19
Item 1. Legal Proceedings	19
Item 1A. Risk Factors	19
Item 6. Exhibits	21

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 such as “anticipates,” “believes,” “seeks,” “could,” “may,” “should,” “continues,” “estimates,” “expects,” “forecasts,” “intends,” “might,” “goals,” “objectives,” “targets,” “planned,” “potential,” “projects,” “scheduled,” “will,” "assumes," “guidance,” “outlook,” “in- service 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;

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• Cash flow from operations or results of operations;

• Rate case filings;

• Natural gas prices, supply, and demand;

• Demand for our 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;

• Changes in maintenance and construction costs, as well as our ability to obtain sufficient construction related inputs including skilled labor;

• 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);

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

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

• Changes in the current geopolitical situation;

• 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 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 24, 2020, as supplemented by the disclosure in Part II, Item 1A. Risk Factors in this Quarterly Report on Form 10-Q.

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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   March 31,
	2020			2019
Operating Revenues:
Natural gas sales	$	19,654		$	24,086
Natural gas transportation	566,006			534,160
Natural gas storage	38,374			36,085
Other	3,334			2,762
Total operating revenues	627,368			597,093
Operating Costs and Expenses:
Cost of natural gas sales	19,654			24,086
Cost of natural gas transportation	13,396			14,635
Operation and maintenance	80,689			83,448
Administrative and general	42,171			48,151
Depreciation and amortization	113,635			104,623
Taxes — other than income taxes	22,437			20,277
Regulatory credit resulting from Tax Reform	(7,688		)	(1,749		)
Other expense, net	3,290			13,349
Total operating costs and expenses	287,584			306,820
Operating Income	339,784			290,273
Other (Income) and Other Expenses:
Interest expense	73,109			71,091
Allowance for equity and borrowed funds used during construction (AFUDC)	(10,953		)	(8,714		)
Equity in earnings of unconsolidated affiliates	—			(771		)
Miscellaneous other (income) expenses, net	(356		)	(1,035		)
Total other (income) and other expenses	61,800			60,571
Net Income	277,984			229,702
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	$	277,984		$	229,472

See accompanying notes.

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TRANSCONTINENTAL GAS PIPE LINE COMPANY, LLC

CONDENSED CONSOLIDATED BALANCE SHEET

(Thousands of Dollars)

(Unaudited)

	March 31, 2020		December 31, 2019
ASSETS
Current Assets:
Cash	$	—	$	—
Receivables:
Affiliates	1,685		669
Trade and other	233,039		253,266
Transportation and exchange gas receivables	5,663		6,360
Inventories	63,862		64,992
Regulatory assets	62,559		69,440
Other	10,753		11,240
Total current assets	377,561		405,967
Property, Plant and Equipment:
Natural gas transmission plant	16,888,643		16,764,904
Less-Accumulated depreciation and amortization	4,528,011		4,438,077
Total property, plant and equipment, net	12,360,632		12,326,827
Other Assets:
Regulatory assets	318,200		290,923
Right-of-use assets	83,342		84,979
Other	196,426		210,017
Total other assets	597,968		585,919
Total assets	$	13,336,161	$	13,318,713

(continued)

See accompanying notes.

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TRANSCONTINENTAL GAS PIPE LINE COMPANY, LLC

CONDENSED CONSOLIDATED BALANCE SHEET

(Thousands of Dollars)

(Unaudited)

	March 31, 2020		December 31, 2019
LIABILITIES AND MEMBER’S EQUITY
Current Liabilities:
Payables:
Affiliates	$	40,767	$	47,740
Advances from affiliate	316,907		252,549
Trade and other	118,607		183,968
Transportation and exchange gas payables	607		3,961
Reserve for rate refunds	248,291		188,842
Regulatory liabilities	57,092		57,359
Accrued liabilities	158,908		199,128
Long-term debt due within one year	20,644		20,180
Total current liabilities	961,823		953,727
Long-Term Debt	4,041,622		4,044,790
Other Long-Term Liabilities:
Asset retirement obligations	431,937		426,505
Regulatory liabilities	962,945		966,961
Deferred revenue	212,957		215,598
Lease liability	83,107		84,528
Other	28,003		20,821
Total other long-term liabilities	1,718,949		1,714,413
Contingent Liabilities and Commitments (Note 3)
Member’s Equity:
Member’s capital	4,428,499		4,428,499
Retained earnings	2,185,268		2,177,284
Total member’s equity	6,613,767		6,605,783
Total liabilities and member’s equity	$	13,336,161	$	13,318,713

See accompanying notes.

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TRANSCONTINENTAL GAS PIPE LINE COMPANY, LLC

CONDENSED CONSOLIDATED STATEMENT OF MEMBER’S EQUITY

(Thousands of Dollars)

(Unaudited)

	Three Months Ended March 31,
	2020			2019
Member's Capital:
Balance at beginning of period	$	4,428,499		$	4,428,499
Cash contributions from parent	—			—
Balance at end of period	4,428,499			4,428,499
Retained Earnings:
Balance at beginning of period	2,177,284			2,099,567
Net income	277,984			229,702
Cash distributions to parent	(270,000		)	(176,000		)
Balance at end of period	2,185,268			2,153,269
Accumulated Other Comprehensive Income:
Balance at beginning of period	—			534
Equity interest in unrealized loss in interest rate hedge	—			(230		)
Balance at end of period	—			304
Total Member's Equity	$	6,613,767		$	6,582,072

See accompanying notes.

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TRANSCONTINENTAL GAS PIPE LINE COMPANY, LLC

CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS

(Thousands of Dollars)

(Unaudited)

	Three months ended March 31,
	2020			2019
Cash flows from operating activities:
Net income	$	277,984		$	229,702
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	113,635			104,623
Allowance for equity funds used during construction (equity AFUDC)	(8,121		)	(6,510		)
Regulatory credit resulting from Tax Reform	(7,688		)	(1,749		)
Equity in earnings of unconsolidated affiliates	—			(771		)
Distributions from unconsolidated affiliates	—			1,248
Changes in operating assets and liabilities:
Receivables — affiliates	(1,016		)	619
— trade and other	20,227			(33,047		)
Transportation and exchange gas receivable	697			(1,824		)
Inventories	1,130			(4,531		)
Payables — affiliates	(6,973		)	(4,242		)
— trade	(31,120		)	(45,546		)
Accrued liabilities	(40,343		)	(35,238		)
Reserve for rate refunds	59,449			22,133
Asset retirement obligations	5,432			18,577
Deferred revenue	(2,641		)	(2,638		)
Other, net	9,572			3,419
Net cash provided by operating activities	390,224			244,225
Cash flows from financing activities:
Proceeds from other financing obligations	1,685			7,914
Payments on other financing obligations	(4,837		)	(3,680		)
Cash distributions to parent	(270,000		)	(176,000		)
Advances from affiliate, net	64,358			86,580
Net cash used in financing activities	(208,794		)	(85,186		)
Cash flows from investing activities:
Capital expenditures*	(173,184		)	(184,556		)
Contributions and advances for construction costs	10,149			10,057
Disposal of property, plant and equipment, net	(4,782		)	(5,477		)
Advances to affiliate, net	—			33,034
Purchase of ARO Trust investments	(28,686		)	(19,518		)
Proceeds from sale of ARO Trust investments	15,073			9,767
Other, net	—			(2,346		)
Net cash used in investing activities	(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	$	(132,575	)	$	(161,741	)
Changes in related accounts payable and accrued liabilities	(40,609		)	(22,815		)
Capital expenditures	$	(173,184	)	$	(184,556	)

See accompanying notes.

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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 prior to December 31, 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 $1.2 million in the three months ended 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 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.

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

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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. (See Note 3)

Accounting Standards Issued and Adopted

In June 2016, the Financial Accounting Standards Board issued Accounting Standards Update (ASU) 2016-13 “Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments” (ASU 2016-13). ASU 2016-13 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 are required to use a forward-looking “expected loss” model that generally will result in the earlier recognition of allowances for losses. We adopted ASU 2016-13 effective January 1, 2020, which primarily applied to our short-term trade receivables. 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 have a 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:

	Year to Date March 31, 2020
	(Thousands)
Balance at beginning of period	$	226,164
Payments received and deferred	—
Recognized in revenue	(2,641		)
Balance at end of period	$	223,523

Our remaining performance obligations 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. Certain of our contracts contain evergreen provisions for periods beyond the initial term of the contract. The remaining performance obligations as of 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.

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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.

	Contract Liabilities		Remaining Performance Obligations
	(Thousands)
2020 (remainder)	$	7,928	$	1,701,586
2021	10,566		2,142,316
2022	10,566		2,042,192
2023	10,566		1,607,989
2024	10,568		1,394,930
Thereafter	173,329		12,782,399
Total	$	223,523	$	21,671,412

Accounts Receivable

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

3. 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. 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. At March 31, 2020, we have accrued approximately $248.3 million related to Docket No. RP18-1126, which we believe is adequate for any refunds that may be required.

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 March 31, 2020, and December 31, 2019, we had a balance of approximately $2.5 million for the expense portion of these estimated costs, $1.2 million recorded in Accrued liabilities and $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

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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.

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 billion are, subject to the $500 million borrowing sublimit applicable to us and Northwest, available to the borrowers. At March 31, 2020, no letters of credit have been issued and 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 billion of unsecured commercial paper notes. At March 31, 2020, Williams had no outstanding commercial paper.

Other Financing Obligations

Dalton Expansion Project

At March 31, 2020, the amount included in Long-Term Debt on our Condensed Consolidated Balance Sheet for this financing obligation is $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 $2.1 million.

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Atlantic Sunrise Project

During the first three months of 2020, we received an additional $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 March 31, 2020, the amount included in Long-Term Debt on our Condensed Consolidated Balance Sheet for this financing obligation is $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 $18.5 million.

Long-Term Debt Due Within One Year

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

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 $23.8 million, and 2) effective March 1, 2020 is approximately $16.0 million.

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

	March 31, 2020				December 31, 2019
	Amortized Cost Basis		Fair Value		Amortized Cost Basis		Fair Value
Money Market Funds	$	22.4	$	22.4	$	15.8	$	15.8
U.S. Equity Funds	63.3		74.5		55.3		83.3
International Equity Funds	36.8		32.3		31.8		35.4
Municipal Bond Funds	58.2		59.0		64.7		66.1
Total	$	180.7	$	188.2	$	167.6	$	200.6

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.

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							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)
	(Millions)
Assets (liabilities) at March 31, 2020:
Measured on a recurring basis:
ARO Trust investments	$	188.2		$	188.2		$	188.2	$	—		$	—
Additional disclosures:
Long-term debt, including current portion	(4,062.3		)	(4,634.9		)	—		(4,634.9		)	—
Assets (liabilities) at December 31, 2019:
Measured on a recurring basis:
ARO Trust investments	$	200.6		$	200.6		$	200.6	$	—		$	—
Additional disclosures:
Long-term debt, including current portion	(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 5 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 4).

7. TRANSACTIONS WITH AFFILIATES

We are a participant in Williams' cash management program, and we receive advances from and make advances to Williams. At March 31, 2020 and December 31, 2019, our advances from Williams totaled approximately $316.9 million and $252.5 million, respectively. These advances are classified as Payables - Advances from affiliate in the accompanying Condensed Consolidated Balance Sheet. Advances are stated at the historical carrying amounts. 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 March 31, 2020, the interest rate was 0.27 percent.

Included in Operating Revenues in the accompanying Condensed Consolidated Statement of Comprehensive Income are revenues received from affiliates of $2.6 million and $3.3 million for the three months ended 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 $2.5 million and $1.6 million for the three months ended March 31, 2020 and 2019, respectively. All gas purchases are made at market or contract prices.

14

We have no 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 $86.9 million and $92.2 million in the three months ended March 31, 2020, and 2019, 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.

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

We made equity distributions totaling $270.0 million and $176.0 million during the three months ended March 31, 2020 and 2019, respectively.

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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 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.

RESULTS OF OPERATIONS

Operating Income and Net Income

Operating Income for the three months ended March 31, 2020 was $339.8 million compared to $290.3 million for the three months ended March 31, 2019. The increase in Operating Income of $49.5 million (17.1 percent) was primarily due to higher Natural gas transportation revenues in the first three months of 2020 compared to the same period in 2019, and a favorable change in Operating Costs and Expenses, as discussed below. Net Income for the three months ended March 31, 2020 was $278.0 million compared to $229.7 million for the three months ended March 31, 2019. The increase in Net Income of $48.3 million (21.0 percent) was mostly attributable to the increase in Operating Income, as discussed below.

Operating Revenues

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

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

• $13.2 million related to implementation of new rates;

• $6.4 million from our Rivervale South to Market project placed in service in September 2019;

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

• $4.1 million from our Gateway project placed in service in December 2019;

• $2.0 million 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.

Operating Costs and Expenses

Excluding the Cost of natural gas sales, which is directly offset in revenues, our operating costs and expenses decreased approximately $14.8 million (5.2 percent) for the three months ended March 31, 2020 to the comparable period in 2019. This decrease was primarily attributable to:

• $10.1 million (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;

16

• $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 $4.4 million increase in ARO asset depreciation, and $3.8 million increase in asset depreciation.

Recent Developments

COVID-19

The outbreak of novel coronavirus (COVID-19) has severely impacted global economic activity and 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:

• Our financial condition, results of operations, and liquidity have not been materially impacted by direct effects of COVID-19.

• We believe we have the ability to access the debt market if necessary, and continue to have significant levels of 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 financial reporting and disclosure controls and 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 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. We placed Phase II into service on May 1, 2020. Together, the first two phases of the project increased capacity by 1,025 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 have addressed the technical issues identified by the agencies. We plan to place the project into service in the fall of 2021, assuming timely receipt of these remaining approvals. The project is expected to increase capacity by 400 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. In October 2019, we received approval from the FERC for the project. We plan to place the project into service in late 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

17

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 as early as the fourth quarter of 2021, assuming timely receipt of all necessary regulatory approvals. The project is expected to increase capacity by 582 Mdth/d.

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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 first quarter of 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 3 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

19

Part I, Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2019, includes certain risk factors that could materially affect our business, financial condition, or future results. Those Risk Factors have not materially 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.

20

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.

21

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:	May 4, 2020	By:	/s/ Billeigh Mark
			Billeigh Mark
			Controller
			(Principal Accounting Officer)

EX-31.1

Exhibit 31.1

SECTION 302 CERTIFICATION

I, Scott A. Hallam, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Transcontinental Gas Pipe Line Company, LLC;

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

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

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

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

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

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

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

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

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

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

Date: May 4, 2020

By:	/s/ Scott A. Hallam
	Scott A. Hallam
	Senior Vice President
	(Principal Executive Officer)

EX-31.2

Exhibit 31.2

SECTION 302 CERTIFICATION

I, John D. Porter, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Transcontinental Gas Pipe Line Company, LLC;

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

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

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

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

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

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

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

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

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

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

Date: May 4, 2020

By:	/s/ John D. Porter
	John D. Porter
	Vice President and Chief Accounting Officer
	(Principal Financial Officer)

EX-32

Exhibit 32

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Transcontinental Gas Pipe Line Company, LLC (the “Company”) on Form 10-Q for the period ending March 31, 2020 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), each of the undersigned hereby certifies, in his capacity as an officer of the Company, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that to his knowledge:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

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

/s/ Scott A. Hallam

Scott A. Hallam

Senior Vice President

May 4, 2020

/s/ John D. Porter

John D. Porter

Vice President and Chief Accounting Officer

May 4, 2020

A signed original of this written statement required by Section 906 has been provided to, and will be retained by, the Company and furnished to the Securities and Exchange Commission or its staff upon request.

The foregoing certification is being furnished to the Securities and Exchange Commission as an exhibit to the Report and shall not be considered filed as part of the Report.

XML

Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2020

Fair Value Disclosures [Abstract]

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
	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)
Assets (liabilities) at March 31, 2020:
Measured on a recurring basis:
ARO Trust investments	$	188.2		$	188.2		$	188.2	$	—		$	—
Additional disclosures:
Long-term debt, including current portion	(4,062.3		)	(4,634.9		)	—		(4,634.9		)	—
Assets (liabilities) at December 31, 2019:
Measured on a recurring basis:
ARO Trust investments	$	200.6		$	200.6		$	200.6	$	—		$	—
Additional disclosures:
Long-term debt, including current portion	(4,065.0		)	(5,251.4		)	—		(5,251.4		)	—

XML

Fair Value Measurements (Notes)

3 Months Ended

Mar. 31, 2020

Fair Value Disclosures [Abstract]

Fair Value Measurements

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
	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)
Assets (liabilities) at March 31, 2020:
Measured on a recurring basis:
ARO Trust investments	$	188.2		$	188.2		$	188.2	$	—		$	—
Additional disclosures:
Long-term debt, including current portion	(4,062.3		)	(4,634.9		)	—		(4,634.9		)	—
Assets (liabilities) at December 31, 2019:
Measured on a recurring basis:
ARO Trust investments	$	200.6		$	200.6		$	200.6	$	—		$	—
Additional disclosures:
Long-term debt, including current portion	(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 5 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 4).

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Fair Value Measurements (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Fair Value, Inputs, Level 1 [Member]
Additional Fair Value Elements [Abstract]
Long-term debt, including current portion	$ 0.0	$ 0.0
Fair Value, Inputs, Level 2 [Member]
Additional Fair Value Elements [Abstract]
Long-term debt, including current portion	(4,634.9)	(5,251.4)
Fair Value, Inputs, Level 3 [Member]
Additional Fair Value Elements [Abstract]
Long-term debt, including current portion	0.0	0.0
Reported Value Measurement [Member]
Additional Fair Value Elements [Abstract]
Long-term debt, including current portion	(4,062.3)	(4,065.0)
Estimate of Fair Value Measurement [Member]
Additional Fair Value Elements [Abstract]
Long-term debt, including current portion	(4,634.9)	(5,251.4)
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]
ARO Trust investments	188.2	200.6
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]
ARO Trust investments	0.0	0.0
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]
ARO Trust investments	0.0	0.0
Fair Value, Recurring [Member] | Reported Value Measurement [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]
ARO Trust investments	188.2	200.6
Fair Value, Recurring [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]
ARO Trust investments	$ 188.2	$ 200.6

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Contingent Liabilities and Commitments (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2020	Dec. 31, 2019
Commitments and Contingencies Disclosure [Abstract]
Reserve for rate refund	$ 248,300
Environmental assessment and remediation [Member]
Site Contingency [Line Items]
Accrued environmental assessment and remediation costs, total	2,500	$ 2,500
Accrued environmental assessment and remediation costs, current	1,200	1,200
Accrued environmental assessment and remediation costs, noncurrent	1,300	$ 1,300
Potentially responsible party at various Superfund and state waste disposal sites [Member] | Maximum [Member]
Site Contingency [Line Items]
Site Contingency, Loss Exposure Not Accrued, Best Estimate	$ 500

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Condensed Consolidated Statement of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Revenues [Abstract]
Natural gas sales	$ 19,654	$ 24,086
Natural gas transportation	566,006	534,160
Natural gas storage	38,374	36,085
Other	3,334	2,762
Total operating revenues	627,368	597,093
Operating Costs and Expenses:
Cost of natural gas sales	19,654	24,086
Cost of natural gas transportation	13,396	14,635
Operation and maintenance	80,689	83,448
Administrative and general	42,171	48,151
Depreciation and amortization	113,635	104,623
Taxes - other than income taxes	22,437	20,277
Regulatory credit resulting from Tax Reform	(7,688)	(1,749)
Other expense, net	3,290	13,349
Total operating costs and expenses	287,584	306,820
Operating Income	339,784	290,273
Other (Income) and Other Expenses:
Interest expense	73,109	71,091
Allowance for equity and borrowed funds used during construction (AFUDC)	(10,953)	(8,714)
Equity in earnings losses of unconsolidated affiliates	0	(771)
Miscellaneous other (income) expenses, net	(356)	(1,035)
Total other (income) and other expenses	61,800	60,571
Net Income	277,984	229,702
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)	0	(230)
Comprehensive Income	$ 277,984	$ 229,472

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Condensed Consolidated Statement of Cash Flows (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Cash flows from operating activities:
Net Income	$ 277,984	$ 229,702
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	113,635	104,623
Allowance for equity funds used during construction (equity AFUDC)	(8,121)	(6,510)
Regulatory credit resulting from Tax Reform	(7,688)	(1,749)
Equity in earnings losses of unconsolidated affiliates	0	(771)
Distribution from unconsolidated affiliates	0	1,248
Changes in operating assets and liabilities:
Receivables - affiliates	(1,016)	619
Receivables - trade and other	20,227	(33,047)
Transportation and exchange gas receivable	697	(1,824)
Inventories	1,130	(4,531)
Payables - afilliates	(6,973)	(4,242)
Payables - trade	(31,120)	(45,546)
Accrued liabilities	(40,343)	(35,238)
Reserve for rate refunds	59,449	22,133
Asset retirement obligations	5,432	18,577
Deferred revenue	(2,641)	(2,638)
Other, net	9,572	3,419
Net cash provided by operating activities	390,224	244,225
Cash flows from financing activities:
Proceeds from other financing obligations	1,685	7,914
Payments on other financing obligations	(4,837)	(3,680)
Cash distributions to parent	(270,000)	(176,000)
Advances from affiliate, net	64,358	86,580
Net cash used in financing activities	(208,794)	(85,186)
Cash flows from investing activities:
Capital expenditures	(173,184)	(184,556)
Contributions and advances for construction costs	10,149	10,057
Disposal of property, plant and equipment, net	(4,782)	(5,477)
Advances to affiliate, net	0	33,034
Purchase of ARO Trust investments	(28,686)	(19,518)
Proceeds from sale of ARO Trust investments	15,073	9,767
Other, net	0	(2,346)
Net cash used in investing activities	(181,430)	(159,039)
Increase (decrease) in cash	0	0
Cash at beginning of period	0	0
Cash at end of period	0	0
Increase to property, plant and equipment, exclusive of equity AFUDC	(132,575)	(161,741)
Changes in related accounts payable and accrued liabilities	(40,609)	(22,815)
Capital expenditures	$ (173,184)	$ (184,556)

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Condensed Consolidated Statement of Comprehensive Income (Unaudited) (Parentheticals) $ in Thousands	3 Months Ended
	Mar. 31, 2019 USD ($)
Accumulated other comprehensive income reclassification for equity interest in realized gains on interest rate hedges	$ (78)

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Basis of Presentation (Notes)

3 Months Ended

Mar. 31, 2020

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Presentation

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 prior to December 31, 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 $1.2 million in the three months ended 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 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.

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. (See Note 3)

Accounting Standards Issued and Adopted

In June 2016, the Financial Accounting Standards Board issued Accounting Standards Update (ASU) 2016-13 “Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments” (ASU 2016-13). ASU 2016-13 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 are required to use a forward-looking “expected loss” model that generally will result in the earlier recognition of allowances for losses. We adopted ASU 2016-13 effective January 1, 2020, which primarily applied to our short-term trade receivables. 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 have a material amount of significantly aged receivables at March 31, 2020.

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Transactions with Affiliates Related Party Transations (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2020 USD ($) employee	Mar. 31, 2019 USD ($)	Dec. 31, 2019 USD ($)
Related Party Transaction [Line Items]
Advances from affiliate	$ 316,900		$ 252,500
Related party transaction, rate	0.27%
Entity number of employees | employee	0
Expenses, related party	$ 86,900	$ 92,200
Equity distributions to parent	270,000	176,000
Affiliated Entity [Member]
Related Party Transaction [Line Items]
Operating revenues, related party	2,600	3,300
Cost of natural gas sales, related party	2,500	1,600
Expenses, related party	$ (1,000)	$ (1,200)

XML

Debt and Financing Arrangements Line of Credit Facility (Details)	Mar. 31, 2020 USD ($)
Line of Credit Facility [Line Items]
Letters of Credit Outstanding, Amount	$ 0
Letter of credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	500,000,000
Williams Companies Inc [Member] | Letter of credit [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	1,000,000,000
Credit Agreement Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	500,000,000
Letters of credit, loans outstanding	1,700,000,000
Commercial paper, outstanding	0
Credit Agreement Member] | Williams Companies Inc [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	4,500,000,000
Additional Amount By Which Credit Facility Can Be Increased	500,000,000
Commercial Paper [Member] | Williams Companies Inc [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 4,000,000,000

XML

Basis of Presentation (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Schedule of Equity Method Investments [Line Items]
Distribution from unconsolidated affiliates	$ 0	$ 1,248
Cardinal Pipeline Company, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	45.00%
Pine Needle LNG Company, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	35.00%

XML

Transactions with Affiliates (Notes)

3 Months Ended

Mar. 31, 2020

Related Party Transactions [Abstract]

Transactions with Affiliates

TRANSACTIONS WITH AFFILIATES

We are a participant in Williams' cash management program, and we receive advances from and make advances to Williams. At March 31, 2020 and December 31, 2019, our advances from Williams totaled approximately $316.9 million and $252.5 million, respectively. These advances are classified as Payables - Advances from affiliate in the accompanying Condensed Consolidated Balance Sheet. Advances are stated at the historical carrying amounts. 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 March 31, 2020, the interest rate was 0.27 percent.

Included in Operating Revenues in the accompanying Condensed Consolidated Statement of Comprehensive Income are revenues received from affiliates of $2.6 million and $3.3 million for the three months ended 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 $2.5 million and $1.6 million for the three months ended March 31, 2020 and 2019, respectively. All gas purchases are made at market or contract prices.

We have no 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 $86.9 million and $92.2 million in the three months ended March 31, 2020, and 2019, 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.

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

We made equity distributions totaling $270.0 million and $176.0 million during the three months ended March 31, 2020 and 2019, respectively.

XML

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2020	May 04, 2020
Document and Entity Information [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2020
Document Transition Report	false
Entity File Number	1-7584
Entity Registrant Name	TRANSCONTINENTAL GAS PIPE LINE COMPANY, LLC
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	74-1079400
Entity Address, Address Line One	2800 Post Oak Boulevard
Entity Address, City or Town	Houston
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77056
City Area Code	713
Local Phone Number	215-2000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Central Index Key	0000099250
Amendment Flag	false
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q1
Current Fiscal Year End Date	--12-31
Entity Common Stock, Shares Outstanding		0

XML

Condensed Consolidated Statement of Member's Equity (Unaudited) - USD ($) $ in Thousands	Total	Member Units [Member]	Retained Earnings [Member]	AOCI Attributable to Parent [Member]
Balance at beginning of period at Dec. 31, 2018		$ 4,428,499	$ 2,099,567	$ 534
Cash contributions from parent		0
Net Income	$ 229,702		229,702
Cash distributions to parent	(176,000)		(176,000)
Equity interest in unrealized loss in interest rate hedge	(230)			(230)
Balance at end of period at Mar. 31, 2019	6,582,072	4,428,499	2,153,269	304
Balance at beginning of period at Dec. 31, 2019	6,605,783	4,428,499	2,177,284	0
Cash contributions from parent		0
Net Income	277,984		277,984
Cash distributions to parent	(270,000)		(270,000)
Equity interest in unrealized loss in interest rate hedge	0			0
Balance at end of period at Mar. 31, 2020	$ 6,613,767	$ 4,428,499	$ 2,185,268	$ 0

XML

ARO Trust (Details) - USD ($) $ in Millions	Mar. 31, 2020	Mar. 01, 2020	Dec. 31, 2019	Mar. 01, 2019
Debt Securities, Available-for-sale [Line Items]
Trading Securities, Equity, Cost	$ 180.7		$ 167.6
Trading Securities, Equity	188.2		200.6
External trust [Member]
Debt Securities, Available-for-sale [Line Items]
Other Commitment, Due in Next Twelve Months		$ 16.0	35.9	$ 23.8
Money Market Funds [Member]
Debt Securities, Available-for-sale [Line Items]
Trading Securities, Equity, Cost	22.4		15.8
Trading Securities, Equity	22.4		15.8
U.S. Equity Funds [Member]
Debt Securities, Available-for-sale [Line Items]
Trading Securities, Equity, Cost	63.3		55.3
Trading Securities, Equity	74.5		83.3
International Equity Funds [Member]
Debt Securities, Available-for-sale [Line Items]
Trading Securities, Equity, Cost	36.8		31.8
Trading Securities, Equity	32.3		35.4
Municipal Bond Funds [Member]
Debt Securities, Available-for-sale [Line Items]
Trading Securities, Equity, Cost	58.2		64.7
Trading Securities, Equity	$ 59.0		$ 66.1

XML

Contingent Liabilities and Commitments (Notes)

3 Months Ended

Mar. 31, 2020

Commitments and Contingencies Disclosure [Abstract]

Contingent Liabilities and Commitments

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. 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. At March 31, 2020, we have accrued approximately $248.3 million related to Docket No. RP18-1126, which we believe is adequate for any refunds that may be required.

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 March 31, 2020, and December 31, 2019, we had a balance of approximately $2.5 million for the expense portion of these estimated costs, $1.2 million recorded in Accrued liabilities and $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.

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ARO Trust (Tables)

3 Months Ended

Mar. 31, 2020

Investments, Debt and Equity Securities [Abstract]

ARO Trust

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

	March 31, 2020				December 31, 2019
	Amortized Cost Basis		Fair Value		Amortized Cost Basis		Fair Value
Money Market Funds	$	22.4	$	22.4	$	15.8	$	15.8
U.S. Equity Funds	63.3		74.5		55.3		83.3
International Equity Funds	36.8		32.3		31.8		35.4
Municipal Bond Funds	58.2		59.0		64.7		66.1
Total	$	180.7	$	188.2	$	167.6	$	200.6

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ARO Trust (Notes)

3 Months Ended

Mar. 31, 2020

Investments, Debt and Equity Securities [Abstract]

ARO Trust

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 $23.8 million, and 2) effective March 1, 2020 is approximately $16.0 million.

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

	March 31, 2020				December 31, 2019
	Amortized Cost Basis		Fair Value		Amortized Cost Basis		Fair Value
Money Market Funds	$	22.4	$	22.4	$	15.8	$	15.8
U.S. Equity Funds	63.3		74.5		55.3		83.3
International Equity Funds	36.8		32.3		31.8		35.4
Municipal Bond Funds	58.2		59.0		64.7		66.1
Total	$	180.7	$	188.2	$	167.6	$	200.6

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Revenue Recognition Accounts Receivable (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Other Receivable [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, Net, Current	$ 9.2	$ 13.8

XML

Revenue Recognition Revenue Recogntion Contract Liabilities (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2020	Dec. 31, 2019
Revenue Recognition [Abstract]
Contract with Customer, Liability	$ 223,523	$ 226,164
Payments received and deferred	0
Recognized in revenue	(2,641)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-04-01
Revenue Recognition [Abstract]
Contract with Customer, Liability	7,928
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue Recognition [Abstract]
Contract with Customer, Liability	10,566
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue Recognition [Abstract]
Contract with Customer, Liability	10,566
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue Recognition [Abstract]
Contract with Customer, Liability	10,566
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue Recognition [Abstract]
Contract with Customer, Liability	10,568
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue Recognition [Abstract]
Contract with Customer, Liability	$ 173,329
Remaining Performance Obligations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	9 months
Remaining Performance Obligations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 1,701,586
Remaining Performance Obligations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 2,142,316
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Remaining Performance Obligations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 2,042,192
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Remaining Performance Obligations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 1,607,989
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Remaining Performance Obligations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 1,394,930
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Remaining Performance Obligations [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 21,671,412
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Performance Obligations Related To Contract Liabilities [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	9 months
Performance Obligations Related To Contract Liabilities [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Performance Obligations Related To Contract Liabilities [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Performance Obligations Related To Contract Liabilities [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Performance Obligations Related To Contract Liabilities [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Performance Obligations Related To Contract Liabilities [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year

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Revenue Recognition Revenue Recognition (Tables)

3 Months Ended

Mar. 31, 2020

Revenue Recognition [Abstract]

Contract with Customer, Asset and Liability [Table Text Block]

The following table presents a reconciliation of our contract liabilities:

	Year to Date March 31, 2020
	(Thousands)
Balance at beginning of period	$	226,164
Payments received and deferred	—
Recognized in revenue	(2,641		)
Balance at end of period	$	223,523

Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Table Text Block]

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.

	Contract Liabilities		Remaining Performance Obligations
	(Thousands)
2020 (remainder)	$	7,928	$	1,701,586
2021	10,566		2,142,316
2022	10,566		2,042,192
2023	10,566		1,607,989
2024	10,568		1,394,930
Thereafter	173,329		12,782,399
Total	$	223,523	$	21,671,412

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Debt and Financing Arrangements (Notes)

3 Months Ended

Mar. 31, 2020

Debt Disclosure [Abstract]

Debt and Financing Arrangements

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 billion are, subject to the $500 million borrowing sublimit applicable to us and Northwest, available to the borrowers. At March 31, 2020, no letters of credit have been issued and 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 billion of unsecured commercial paper notes. At March 31, 2020, Williams had no outstanding commercial paper.

Other Financing Obligations

Dalton Expansion Project

At March 31, 2020, the amount included in Long-Term Debt on our Condensed Consolidated Balance Sheet for this financing obligation is $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 $2.1 million.

Atlantic Sunrise Project

During the first three months of 2020, we received an additional $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 March 31, 2020, the amount included in Long-Term Debt on our Condensed Consolidated Balance Sheet for this financing obligation is $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 $18.5 million.

Long-Term Debt Due Within One Year

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

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Debt and Financing Arrangements Long-Term Debt Instruments (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Long-Term Debt	$ 4,041,622	$ 4,044,790
Long-term debt due within one year	20,644	$ 20,180
Dalton Expansion Project
Debt Instrument [Line Items]
Long-Term Debt	256,200
Long-term debt due within one year	2,100
Atlantic Sunrise Project [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of Other Long-term Debt	1,700
Long-Term Debt	835,900
Long-term debt due within one year	$ 18,500

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Revenue Recognition (Notes)

3 Months Ended

Mar. 31, 2020

Revenue Recognition [Abstract]

Revenue from Contract with Customer [Text Block]

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:

	Year to Date March 31, 2020
	(Thousands)
Balance at beginning of period	$	226,164
Payments received and deferred	—
Recognized in revenue	(2,641		)
Balance at end of period	$	223,523

Our remaining performance obligations 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. Certain of our contracts contain evergreen provisions for periods beyond the initial term of the contract. The remaining performance obligations as of 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.

	Contract Liabilities		Remaining Performance Obligations
	(Thousands)
2020 (remainder)	$	7,928	$	1,701,586
2021	10,566		2,142,316
2022	10,566		2,042,192
2023	10,566		1,607,989
2024	10,568		1,394,930
Thereafter	173,329		12,782,399
Total	$	223,523	$	21,671,412

Accounts Receivable

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

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Condensed Consolidated Balance Sheet (Unaudited) - USD ($) $ in Thousands	Mar. 31, 2020	Dec. 31, 2019
Current Assets:
Cash	$ 0	$ 0
Receivables:
Affiliates	1,685	669
Trade and other	233,039	253,266
Transportation and exchange gas receivables	5,663	6,360
Inventories	63,862	64,992
Regulatory assets	62,559	69,440
Other	10,753	11,240
Total current assets	377,561	405,967
Property, Plant and Equipment
Natural gas transmission plant	16,888,643	16,764,904
Less-Accumulated depreciation and amortization	4,528,011	4,438,077
Total property, plant and equipment, net	12,360,632	12,326,827
Other Assets:
Regulatory assets	318,200	290,923
Right-of-use assets	83,342	84,979
Other	196,426	210,017
Total other assets	597,968	585,919
Total Assets	13,336,161	13,318,713
Payables:
Affiliate	40,767	47,740
Advances from affiliate	316,907	252,549
Trade and other	118,607	183,968
Transportation and exchange gas payables	607	3,961
Reserve for rate refunds	248,291	188,842
Regulatory liabilities	57,092	57,359
Accrued liabilities	158,908	199,128
Long-term debt due within one year	20,644	20,180
Total current liabilities	961,823	953,727
Long-Term Debt	4,041,622	4,044,790
Other Long-Term Liabilities:
Asset retirement obligations	431,937	426,505
Regulatory liabilities	962,945	966,961
Deferred revenue	212,957	215,598
Lease liability	83,107	84,528
Other	28,003	20,821
Total other long-term liabilities	1,718,949	1,714,413
Contingent Liabilities and Commitments (Note 3)
Members' Equity
Member's capital	4,428,499	4,428,499
Retained earnings	2,185,268	2,177,284
Total member's equity	6,613,767	6,605,783
Total liabilities and member's equity	$ 13,336,161	$ 13,318,713