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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 September 30, ~~2020~~2021


☐			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

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~~


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TRANSCONTINENTAL GAS PIPE LINE COMPANY, LLC

Index


			Page
Part I. Financial Information:
Item 1. Financial Statements
Condensed ~~Consolidated~~ Statement of ~~Comprehensive~~Net Income —Three and Nine Months Ended ~~September~~Sept ember 30, ~~2020~~2021 and ~~2019~~2020			4
Condensed ~~Consolidated~~ Balance Sheet — September 30, ~~2020~~2021 and December 31, ~~2019~~2020			5
Condensed ~~Consolidated~~ Statement of ~~Member's~~Member ’s Equity — Three and Nine Months Ended September 30, ~~2020~~2021 and ~~2019~~2020			7
Condensed ~~Consolidated~~ Statement of Cash Flows — Nine Months Ended September 30, ~~2020~~2021 and ~~2019~~2020			8
Notes to Condensed ~~Consolidated~~ Financial Statements:			9
Note 1 – Basis of Presentation			9
Note 2 – Revenue Recognition			9
Note 3 – Contingent Liabilities and Commitments			10
Note 4 – Debt and Financing Arrangements			11
Note 5 – ARO Trust			13
Note 6 – Fair Value Measurements			13
Note 7 – Transactions with Affiliates			14
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations			1716

Item 4. Controls and Procedures			2019

Part II. Other Information			2019

Item 1. Legal Proceedings			2019

Item 1A. Risk Factors			2120

Item 6. Exhibits			2221

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;


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•Expected in-service dates for capital projects;

•Financial condition and liquidity;

•Business strategy;

•Cash flow from operations or results of operations;

•Rate case filings;

•Natural gas prices, supply, and demand;

•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,~~matters, 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;

•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;


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

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

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

•Changes in the current geopolitical situation;

•Changes in U.S. governmental administration and policies;

•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 for the year ended December 31, 2020, as filed with the SEC on February 24, ~~2020, as supplemented by the disclosure in Part II, Item 1A. Risk Factors in our Quarterly Report on Form 10-Q filed with the SEC on May 4, 2020.~~2021.


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PART I — FINANCIAL INFORMATION


~~ITEM 1.~~			~~Financial Statements.~~

Item 1. Financial Statements

TRANSCONTINENTAL GAS PIPE LINE COMPANY, LLC

CONDENSED ~~CONSOLIDATED~~ STATEMENT OF ~~COMPREHENSIVE~~NET INCOME

(Thousands of Dollars)

(Unaudited)

Three months ended
September 30, Nine months ended
September 30,
2020 2019 2020 2019
Operating Revenues:
Natural gas sales $ 21,393 $ 41,547 $ 61,373 $ 88,062
Natural gas transportation 557,947 566,240 1,676,243 1,626,552
Natural gas storage 42,208 35,194 119,637 109,751
Other 4,407 2,735 11,761 8,255
Total operating revenues 625,955 645,716 1,869,014 1,832,620
Operating Costs and Expenses:
Cost of natural gas sales 21,393 41,547 61,373 88,062
Cost of natural gas transportation 15,175 15,395 42,100 38,970
Operation and maintenance 80,623 92,706 236,868 274,289
Administrative and general 46,793 49,997 139,728 155,506
Depreciation and amortization 115,821 112,296 343,291 320,103
Taxes — other than income taxes 20,441 19,316 64,872 58,253
Regulatory credit resulting from Tax Reform (7,688) (12,247) (23,064) (19,244)
Other (income) expense, net 3,821 (6,263) 8,563 19,451
Total operating costs and expenses 296,379 312,747 873,731 935,390
Operating Income 329,576 332,969 995,283 897,230
Other (Income) and Other Expenses:
Interest expense 80,545 71,980 232,403 214,059
Allowance for equity and borrowed funds used during construction (AFUDC) 2,729 (12,640) (17,518) (28,857)
Equity in earnings of unconsolidated affiliates 0 (847) 0 (2,441)
Miscellaneous other (income) expenses, net 588 194 737 (1,414)
Total other (income) and other expenses 83,862 58,687 215,622 181,347
Net Income 245,714 274,282 779,661 715,883
Other comprehensive loss:
Equity interest in unrealized loss on interest rate hedges (includes $(24) for the three months ended September 30, 2019 and $(153) for the nine months ended September 30, 2019, respectively, of accumulated other comprehensive loss reclassification for equity interest in realized gains on interest rate hedges) 0 (93) 0 (692)
Comprehensive Income $ 245,714 $ 274,189 $ 779,661 $ 715,191


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Operating Revenues:
Natural gas sales	$	19,506	$	21,393	$	49,733	$	61,373
Natural gas transportation	600,615		557,947		1,754,417		1,676,243
Natural gas storage	41,950		42,208		125,809		119,637
Other	3,814		4,407		10,942		11,761
Total operating revenues	665,885		625,955		1,940,901		1,869,014

Operating Costs and Expenses:
Cost of natural gas sales	19,506		21,393		49,733		61,373

Operation and maintenance	110,746		95,798		302,661		278,968
Administrative and general	55,085		46,793		152,262		139,728
Depreciation and amortization	122,159		115,821		357,715		343,291
Taxes — other than income taxes	23,235		20,441		72,181		64,872

Regulatory credit resulting from tax rate changes	(7,688)		(7,688)		(23,064)		(23,064)
Other expense, net	9,310		3,821		13,987		8,563
Total operating costs and expenses	332,353		296,379		925,475		873,731

Operating Income	333,532		329,576		1,015,426		995,283

Other (Income) and Other Expenses:
Interest expense	80,328		80,545		240,763		232,403
Allowance for equity and borrowed funds used during construction (AFUDC)	(7,080)		2,729		(16,801)		(17,518)

Miscellaneous other (income) expenses, net	273		588		226		737
Total other (income) and other expenses	73,521		83,862		224,188		215,622

Net Income	$	260,011	$	245,714	$	791,238	$	779,661

See accompanying notes.


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TRANSCONTINENTAL GAS PIPE LINE COMPANY, LLC

CONDENSED ~~CONSOLIDATED~~ BALANCE SHEET

(Thousands of Dollars)

(Unaudited)

September 30,
2020 December 31,
2019
ASSETS
Current Assets:
Cash $ 0 $ 0
Receivables:
Affiliates 965 669
Advances to affiliate 581,665 0
Trade and other 213,298 253,266
Transportation and exchange gas receivables 4,676 6,360
Inventories 71,057 64,992
Regulatory assets 62,407 69,440
Other 14,506 11,240
Total current assets 948,574 405,967
Property, Plant and Equipment:
Natural gas transmission plant 17,201,803 16,764,904
Less-Accumulated depreciation and amortization 4,730,876 4,438,077
Total property, plant and equipment, net 12,470,927 12,326,827
Other Assets:
Regulatory assets 294,481 290,923
Right-of-use assets 80,526 84,979
Other 227,642 210,017
Total other assets 602,649 585,919
Total assets $ 14,022,150 $ 13,318,713

~~(continued)~~


	September 30, 2021		December 31, 2020
ASSETS

Current Assets:
Cash	$	—	$	—
Receivables:
Affiliates	6,402		1,011
Advances to affiliate	1,448,300		642,734
Trade	215,634		223,864
Other	16,652		14,660
Transportation and exchange gas receivables	5,816		4,627
Inventories	62,882		56,297
Regulatory assets	81,937		62,861
Other	19,254		13,847
Total current assets	1,856,877		1,019,901

Property, Plant and Equipment:
Natural gas transmission plant	17,582,511		17,123,779
Less-Accumulated depreciation and amortization	5,129,262		4,802,256
Total property, plant and equipment, net	12,453,249		12,321,523

Other Assets:
Regulatory assets	269,525		281,870
Right-of-use assets	68,345		78,899
Other	272,683		252,051
Total other assets	610,553		612,820

Total assets	$	14,920,679	$	13,954,244

(continued)

See accompanying notes.


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TRANSCONTINENTAL GAS PIPE LINE COMPANY, LLC

CONDENSED ~~CONSOLIDATED~~ BALANCE SHEET

(Thousands of Dollars)

(Unaudited)

September 30,
2020 December 31,
2019
LIABILITIES AND MEMBER’S EQUITY
Current Liabilities:
Payables:
Affiliates $ 40,215 $ 47,740
Advances from affiliate 0 252,549
Trade and other 128,000 183,968
Transportation and exchange gas payables 1,883 3,961
Reserve for rate refunds 0 188,842
Regulatory liabilities 57,423 57,359
Accrued liabilities 217,222 199,128
Long-term debt due within one year 21,604 20,180
Total current liabilities 466,347 953,727
Long-Term Debt 5,221,827 4,044,790
Other Long-Term Liabilities:
Asset retirement obligations 393,664 426,505
Regulatory liabilities 947,424 966,961
Deferred revenue 207,673 215,598
Lease liability 80,085 84,528
Other 39,686 20,821
Total other long-term liabilities 1,668,532 1,714,413
Contingent Liabilities and Commitments (Note 3)
Member’s Equity:
Member’s capital 4,493,499 4,428,499
Retained earnings 2,171,945 2,177,284
Total member’s equity 6,665,444 6,605,783
Total liabilities and member’s equity $ 14,022,150 $ 13,318,713


	September 30, 2021		December 31, 2020
LIABILITIES AND MEMBER’S EQUITY

Current Liabilities:
Payables:
Affiliates	$	84,774	$	32,676
Trade and other	192,569		128,449
Transportation and exchange gas payables	3,893		1,905
Regulatory liabilities	58,199		57,086
Accrued liabilities	255,079		242,379
Long-term debt due within one year	24,213		22,640
Total current liabilities	618,727		485,135

Long-Term Debt	5,202,681		5,217,140

Other Long-Term Liabilities:
Asset retirement obligations	478,407		397,737
Regulatory liabilities	926,582		946,774
Deferred revenue	197,107		205,030
Lease liability	67,398		78,688
Other	73,648		42,921
Total other long-term liabilities	1,743,142		1,671,150

Contingent Liabilities and Commitments (Note 3)	0		0

Member’s Equity:
Member’s capital	4,815,499		4,543,499
Retained earnings	2,540,630		2,037,320
Total member’s equity	7,356,129		6,580,819

Total liabilities and member’s equity	$	14,920,679	$	13,954,244

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 September 30,
2020 2019
Member’s Capital:
Balance at beginning of period $ 4,428,499 $ 4,428,499
Cash contributions from parent 65,000 0
Balance at end of period 4,493,499 4,428,499
Retained Earnings:
Balance at beginning of period 2,176,231 2,195,168
Net income 245,714 274,282
Cash distributions to parent (250,000) (213,000)
Balance at end of period 2,171,945 2,256,450
Accumulated Other Comprehensive Loss:
Balance at beginning of period 0 (65)
Equity interest in unrealized loss in interest rate hedge 0 (93)
Balance at end of period 0 (158)
Total Member’s Equity $ 6,665,444 $ 6,684,791


		Nine Months Ended September 30,				Three Months Ended September 30,
		2020		2019				2021		2020
Member’s Capital:	Member’s Capital:						Member’s Capital:
Balance at beginning of period	Balance at beginning of period	$	4,428,499	$	4,428,499		Balance at beginning of period	$	4,676,499	$	4,428,499
Cash contributions from parent	Cash contributions from parent	65,000		0			Cash contributions from parent	139,000		65,000

Balance at end of period	Balance at end of period	4,493,499		4,428,499			Balance at end of period	4,815,499		4,493,499
Retained Earnings:	Retained Earnings:						Retained Earnings:
Balance at beginning of period	Balance at beginning of period	2,177,284		2,099,567			Balance at beginning of period	2,337,177		2,176,231
Net income	Net income	779,661		715,883			Net income	260,011		245,714
Cash distributions to parent	Cash distributions to parent	(785,000)		(559,000)			Cash distributions to parent	(56,558)		(250,000)

Balance at end of period	Balance at end of period	2,171,945		2,256,450			Balance at end of period	2,540,630		2,171,945
Accumulated Other Comprehensive Income (Loss):
Balance at beginning of period		0		534
Equity interest in unrealized loss in interest rate hedge		0		(692)
Balance at end of period		0		(158)

Total Member’s Equity	Total Member’s Equity	$	6,665,444	$	6,684,791		Total Member’s Equity	$	7,356,129	$	6,665,444


	Nine Months Ended September 30,
	2021		2020
Member’s Capital:
Balance at beginning of period	$	4,543,499	$	4,428,499
Cash contributions from parent	272,000		65,000


Balance at end of period	4,815,499		4,493,499
Retained Earnings:
Balance at beginning of period	2,037,320		2,177,284
Net income	791,238		779,661
Cash distributions to parent	(287,928)		(785,000)

Balance at end of period	2,540,630		2,171,945

Total Member’s Equity	$	7,356,129	$	6,665,444

See accompanying notes.


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TRANSCONTINENTAL GAS PIPE LINE COMPANY, LLC

CONDENSED ~~CONSOLIDATED~~ STATEMENT OF CASH FLOWS

(Thousands of Dollars)

(Unaudited)

Nine months ended September 30,
2020 2019
Cash flows from operating activities:
Net income $ 779,661 $ 715,883
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization 343,291 320,103
Allowance for equity funds used during construction (equity AFUDC) (10,855) (22,926)
Regulatory credit resulting from Tax Reform (23,064) (19,244)
Equity in earnings of unconsolidated affiliates 0 (2,441)
Distributions from unconsolidated affiliates 0 3,744
Changes in operating assets and liabilities:
Receivables — affiliates (296) (25)
— trade and other 39,968 (26,239)
Transportation and exchange gas receivable 1,684 259
Inventories (6,065) 6,584
Payables — affiliates (7,525) 3,781
— trade (18,288) (21,844)
Accrued liabilities 24,460 (18,575)
Reserve for rate refunds (188,842) 130,752
Asset retirement obligations (12,105) 7,615
Deferred revenue (7,925) (7,922)
Other, net (6,322) 15,264
Net cash provided by operating activities 907,777 1,084,769
Cash flows from financing activities:
Proceeds from long-term debt 1,195,629 0
Proceeds from other financing obligations 7,248 35,709
Payments on other financing obligations (14,848) (12,581)
Payments for debt issuance costs (11,209) 0
Cash distributions to parent (785,000) (559,000)
Cash contributions from parent 65,000 0
Advances from affiliate, net (252,549) 169,908
Net cash provided by (used in) financing activities 204,271 (365,964)
Cash flows from investing activities:
Capital expenditures* (504,987) (702,634)
Contributions and advances for construction costs 20,850 22,690
Disposal of property, plant and equipment, net (33,553) (37,014)
Advances to affiliate, net (581,665) 33,034
Contribution to unconsolidated affiliate 0 (12,250)
Purchase of ARO Trust investments (46,075) (52,272)
Proceeds from sale of ARO Trust investments 33,382 29,641
Net cash used in investing activities (1,112,048) (718,805)
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 $ (456,158) $ (686,270)
Changes in related accounts payable and accrued liabilities (48,829) (16,364)
Capital expenditures $ (504,987) $ (702,634)


	Nine Months Ended September 30,
	2021		2020
Cash flows from operating activities:
Net income	$	791,238	$	779,661
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	357,715		343,291
Allowance for equity funds used during construction (equity AFUDC)	(12,959)		(10,855)
Regulatory credit resulting from tax rate changes	(23,064)		(23,064)
Changes in operating assets and liabilities:
Receivables — affiliates	(5,391)		(296)
— trade and other	6,238		39,968
Transportation and exchange gas receivable	(1,189)		1,684
Inventories	(6,585)		(6,065)
Payables — affiliates	52,098		(7,525)
— trade	24,841		(18,288)
Accrued liabilities	37,400		24,460
Reserve for rate refunds	—		(188,842)
Asset retirement obligations	5,446		(12,105)
Deferred revenue	(7,922)		(7,925)
Other, net	(42,867)		(6,322)
Net cash provided by operating activities	1,174,999		907,777

Cash flows from financing activities:
Proceeds from long-term debt	—		1,195,629
Proceeds from other financing obligations	1,790		7,248

Payments on other financing obligations	(16,663)		(14,848)
Payments for debt issuance costs	(59)		(11,209)
Cash distributions to parent	(287,928)		(785,000)
Cash contributions from parent	272,000		65,000
Advances from affiliate, net	—		(252,549)

Net cash provided by (used in) financing activities	(30,860)		204,271

Cash flows from investing activities:
Capital expenditures (1)	(355,662)		(504,987)
Contributions and advances for construction costs	34,102		20,850
Disposal of property, plant and equipment, net	(20,545)		(33,553)
Advances to affiliate, net	(805,566)		(581,665)
Purchase of ARO Trust investments	(23,174)		(46,075)
Proceeds from sale of ARO Trust investments	26,706		33,382
Net cash used in investing activities	(1,144,139)		(1,112,048)

Increase (decrease) in cash	—		—
Cash at beginning of period	—		—
Cash at end of period	$	—	$	—
_______________________
(1) Increase to property, plant and equipment, exclusive of equity AFUDC	$	(378,004)	$	(456,158)
Changes in related accounts payable and accrued liabilities	22,342		(48,829)
Capital expenditures	$	(355,662)	$	(504,987)

See accompanying notes.


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TRANSCONTINENTAL GAS PIPE LINE COMPANY, LLC

NOTES TO CONDENSED ~~CONSOLIDATED~~ FINANCIAL STATEMENTS

(Unaudited)

~~1. BASIS OF PRESENTATION~~Note 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)~~(Transco) 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 accompanying 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 had equity method investments. 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 $3.7 million in the nine months ended September 30, 2019. We made a $12.3 million contribution to Pine Needle in the nine months ended September 30, 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~~2020 Annual Report on Form 10-K.

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

A reclassification within Operating Costs and Expenses in the Condensed Statement of Net 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 incometo include Cost 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 that govern a process to establish the rates that we are permitted to charge customers for~~ natural gas ~~sales~~transportation within Operation and ~~services, including~~maintenance of approximately $15.2 million and $42.1 million for the ~~transportation~~three 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)

~~Northeast Supply Enhancement~~

~~As of~~nine months ended September 30, 2020, ~~Property, plant, and equipment~~ in our Condensed Consolidated Balance Sheet includes approximately $215 million of capitalized project development costs for the Northeast Supply Enhancement project. Approvals required for the project from the New York State Department of Environmental Conservation and the New Jersey Department of Environmental Protection have been denied and we have not refiled at this time. Beginning in May 2020, we discontinued capitalization of costs related to this project.

The customer precedent agreements remain in effect and the project’s FERC certificate remains active. As such, we do not believe this project is probable of abandonment at this time and consider the carrying amount to be recoverable; thus no impairment chargerespectively, has been ~~recognized. It is reasonably possible that further adverse developments in~~made to conform to the ~~near future could change this determination, resulting in a future impairment charge of a substantial portion of the capitalized costs.~~2021 presentation.

~~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 September 30, 2020.

~~2. REVENUE RECOGNITION~~Note 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~~Net Income.

Contract Liabilities

The following table presents a reconciliation of our contract liabilities:


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(Thousands)
Balance at beginning of period	$	210,317	$	220,882	$	215,596	$	226,164
Recognized in revenue	(2,643)		(2,643)		(7,922)		(7,925)
Balance at end of period	$	207,674	$	218,239	$	207,674	$	218,239

Three Months Ended September 30, Nine Months Ended September 30,
2020 2019 2020 2019
(Thousands)
Balance at beginning of period $ 220,882 $ 231,451 $ 226,164 $ 236,730
Payments received and deferred 0 0 0 0
Recognized in revenue (2,643) (2,644) (7,925) (7,923)
Balance at end of period $ 218,239 $ 228,807 $ 218,239 $ 228,807


Notes (Continued)			Table of Contents

Remaining Performance Obligations

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 periodic review and approval by the ~~FERC,~~Federal Energy Regulatory Commission (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 September 30, ~~2020,~~2021, 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 September 30, ~~2020.~~2021.

Contract Liabilities Remaining Performance Obligations
(Thousands)
2020 (remainder) $ 2,643 $ 558,969
2021 10,566 2,152,826
2022 10,566 2,019,417
2023 10,566 1,775,468
2024 10,568 1,344,581
Thereafter 173,330 11,879,187
Total $ 218,239 $ 19,730,448


	Contract Liabilities		Remaining Performance Obligations
	(Thousands)
2021 (three months)	$	2,644	$	603,677
2022 (one year)	10,566		2,317,047
2023 (one year)	10,566		2,114,147
2024 (one year)	10,568		1,886,688
2025 (one year)	10,566		1,469,382
Thereafter 00	162,764		12,280,513
Total	$	207,674	$	20,671,454

Accounts Receivable

Receivables from contracts with customers are included within Receivables - Trade and Receivables - Affiliates, and receivables that are not related to contracts with customers are included within the balance of Receivables - Advances to affiliate and Receivables - Other in our Condensed ~~Consolidated~~ Balance Sheet.

~~3. CONTINGENT LIABILITIES AND COMMITMENTS~~Note 3 – Contingent Liabilities and Commitments

~~Rate~~

Environmental 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. 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 became effective on June 1, 2020. Refunds of $284.3 million were issued on July 1, 2020.

~~Notice of Inquiry (Docket No. PL19-4-000).~~ On May 21, 2020, the FERC issued a “Policy Statement on Determining Return on Equity for Natural Gas and Oil Pipelines” (Policy Statement) in Docket No. PL19-4-000 adopting changes to its policies concerning the calculation of a public utility return on equity (ROE). In this Policy Statement, the FERC revised its ROE policy for natural gas pipelines and oil pipelines to provide that the FERC will determine a pipeline’s ROE by averaging the results of the Discounted Cash Flow model and the Capital Asset Pricing Model, with each weighted equally. The FERC declined to adopt any additional policy changes at this time and will address all other issues concerning the determination of a pipeline’s ROE as they arise in future proceedings.

~~Our next general rate case must be filed no later than August 30, 2024.~~

~~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 September 30, ~~2020,~~2021, we have accrued approximately ~~$2.5~~$2.6 million for the expense portion of these estimated costs, $0.7 million of which is recorded in Accrued liabilities and ~~$1.8~~$1.9 million of which is recorded in Other Long-Term Liabilities - Other in the accompanying Condensed ~~Consolidated~~ Balance Sheet. At December 31, ~~2019,~~2020, we had a balance of approximately ~~$2.5~~$2.4 million for the expense portion of these estimated costs, ~~$1.2~~$0.7 million of which is recorded in Accrued liabilities and ~~$1.3~~$1.7 million of which is recorded in Other Long-Term Liabilities - Other in the accompanying Condensed ~~Consolidated~~ Balance Sheet.


Notes (Continued)			Table of Contents

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~~propose and ~~propose~~promulgate 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,~~review 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 regardingupdates to the National Ambient Air Quality Standards, and rules for ~~ground-level ozone.~~new and existing source performance standards for volatile organic compounds and methane. We ~~are monitoring the rule’s implementation as it will trigger additional federal~~continuously monitor these regulatory changes and ~~state regulatory actions that~~how they may impact our operations. Implementation of ~~the~~new or modified regulations ~~is expected to~~may result in impacts to our operations and increase the cost of additions to ~~Total property,~~Property, plant, and equipment, net in the Condensed ~~Consolidated~~ Balance Sheet for both new and existing facilities in affected ~~areas. We~~areas; however, due to regulatory uncertainty on final rule content and applicability timeframes, we are unable to reasonably estimate the cost of ~~additions that may be required to meet the regulations~~these regulatory impacts at this ~~time due to uncertainty created by various legal challenges to these regulations and the need for further specific regulatory guidance.~~time.

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~~Note 4 – Debt and Financing Arrangements

We, along with Williams and Northwest Pipeline LLC (Northwest), 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. At September 30, 2020, 0 letters of credit have been issued and 0 loans were outstanding under the credit facility.

Commercial Paper

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$4.0 billion of unsecured commercial paper notes. At September 30, ~~2020,~~2021, Williams had ~~$40 million of~~0 outstanding commercial paper. In connection with the amended and restated credit agreement described below, Williams reduced the size of its commercial paper program to $3.5 billion.


Notes (Continued)			Table of Contents

Credit Facility

In October 2021, we, along with Williams and Northwest Pipeline LLC (Northwest), the lenders named therein, and an administrative agent entered into an amended and restated credit agreement (Credit Agreement) that reduced aggregate commitments available from $4.5 billion to $3.75 billion, with up to an additional $500 million increase in aggregate commitments available under certain circumstances. The Credit Agreement was effective on October 8, 2021. The maturity date of the credit facility is October 8, 2026. However, the co-borrowers may request up to two extensions of the maturity date each for an additional one-year period to allow a maturity date as late as October 8, 2028, under certain circumstances. The Credit Agreement allows for swing line loans up to an aggregate of $200 million, subject to available capacity under the credit facility, and letters of credit commitments of $500 million. We and Northwest are each able to borrow up to $500 million under this credit facility to the extent not otherwise utilized by the other co-borrowers. At September 30, 2021, and as of October 8, 2021, the effective date of the amended and restated Credit Agreement, 0 letters of credit have been issued and 0 loans were outstanding under the credit facility.

The Credit Agreement contains the following terms and conditions:

•Various covenants may limit, among other things, a borrower’s and its material subsidiaries’ ability to grant certain liens supporting indebtedness, merge or consolidate, sell all or substantially all of its assets in certain circumstances, make certain distributions during an event of default, and each borrower and each borrower’s respective material subsidiaries’ ability to enter into certain restrictive agreements.

•If an event of default with respect to a borrower occurs under the credit facility, the lenders will be able to terminate the commitments for the respective borrowers and accelerate the maturity of the loans of the defaulting borrower under the credit facility and exercise other rights and remedies.

•Other than swing line loans, each time funds are borrowed, the applicable borrower may choose from two methods of calculating interest: a fluctuating base rate equal to an alternative base rate as defined in the Credit Agreement plus an applicable margin or a periodic fixed rate equal to the London Interbank Offered Rate (LIBOR) plus an applicable margin. Williams is required to pay a commitment fee based on the unused portion of the credit facility. The applicable margin is determined by reference to a pricing schedule based on the applicable borrower’s senior unsecured long-term debt ratings and the commitment fee is determined by reference to a pricing schedule based on Williams’ senior unsecured long-term debt ratings. The Credit Agreement also includes customary provisions to provide for replacement of LIBOR with an alternative benchmark rate when LIBOR ceases to be available.

The ratio of debt to capitalization (defined as net worth plus debt), each as defined in the Credit Agreement, must be no greater than 65 percent for each of Transco and Northwest Pipeline.

At September 30, 2021, we are in compliance with this covenant.

Other Financing Obligations

Dalton Expansion Project

At September 30, ~~2020,~~2021, the amount included in Long-Term Debt on our Condensed ~~Consolidated~~ Balance Sheet for this financing obligation is ~~$255.1~~$252.5 million, and the amount included in Long-term debt due within one year on our Condensed ~~Consolidated~~ Balance Sheet for this financing obligation is ~~$2.2~~$2.5 million.


Notes (Continued)			Table of Contents

Atlantic Sunrise Project

During the first nine months of ~~2020,~~2021, we received an additional ~~$7.2~~$1.8 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 September 30, ~~2020,~~2021, the amount included in Long-Term Debt on our Condensed ~~Consolidated~~ Balance Sheet for this financing obligation is ~~$831.6~~$812.4 million, and the amount included in Long-term debt due within one year on our Condensed ~~Consolidated~~ Balance Sheet for this financing obligation is ~~$19.4~~$21.7 million.

Leidy South Project

During the construction of our Leidy South project, we received funding from a co-owner for its proportionate share of construction costs related to an undivided ownership interest in certain parts of the project. Amounts received were recorded in Other Long-Term ~~Debt Due Within One Year~~

~~The long-term debt due within one year at September 30, 2020 is~~Liabilities: Other and 100 percent of the costs associated with construction were capitalized on our Condensed Balance Sheet. Upon placing the ~~previously described other financing obligations.~~

~~Issuance~~applicable portion of ~~Long-Term Debt~~

~~On May 8, 2020,~~the project in service during October 2021, we ~~issued $700~~began leasing this co-owner’s undivided interest in the facilities, including the associated pipeline capacity, and reclassified approximately $69.0 million of ~~3.25 percent senior unsecured notes due 2030 and $500 million~~funding previously received from our co-owner from Other Long-Term Liabilities: Other to debt to reflect the financing obligation payable to our co-owner over an expected term of 3.95 percent senior unsecured notes due 2050 to investors in a private debt placement. As part of the issuance, we entered into a registration rights agreement with the initial purchasers of the unsecured notes. We are obligated to file and consummate a registration statement for an offer to exchange the notes for a new issue of substantially identical notes registered under the Securities Act of 1933, as amended, within 365 days from closing and to use commercially reasonable efforts to complete the exchange offer. We are required to provide a shelf registration20 years.

statement to cover resales of the notes under certain circumstances. If we fail to fulfill these obligations, additional interest will accrue on the affected securities. The rate of additional interest will be 0.25 percent per annum on the principal amount of the affected securities for the first 90-day period immediately following the occurrence of a registration default, increasing by an additional 0.25 percent per annum with respect to each subsequent 90-day period thereafter, up to a maximum amount for all such registration defaults of 0.5 percent annually. Following the cure of any registration defaults, the accrual of additional interest will cease.

5.Note 5 – ARO ~~TRUST~~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 ARO 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~~annual funding obligation ~~(1) effective March 1, 2019 is approximately $23.8 million, and (2)~~ effective March 1, 2020 is approximately $16.0 ~~million.~~million, with deposits made monthly.

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

September 30, 2020 December 31, 2019
Amortized
Cost Basis Fair
Value Amortized
Cost Basis Fair
Value
Money Market Funds $ 17.1 $ 17.1 $ 15.8 $ 15.8
U.S. Equity Funds 59.5 94.2 55.3 83.3
International Equity Funds 34.2 37.7 31.8 35.4
Municipal Bond Funds 68.9 71.3 64.7 66.1
Total $ 179.7 $ 220.3 $ 167.6 $ 200.6


	September 30, 2021				December 31, 2020
	Amortized Cost Basis		Fair Value		Amortized Cost Basis		Fair Value
Money Market Funds	$	3.4	$	3.4	$	5.8	$	5.8
U.S. Equity Funds	52.6		111.6		59.9		108.0
International Equity Funds	31.7		42.9		34.2		43.7
Municipal Bond Funds	87.5		89.9		74.9		78.0
Total	$	175.2	$	247.8	$	174.8	$	235.5

~~6. FAIR VALUE MEASUREMENTS~~Note 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.

1413


Notes (Continued)			Table of Contents

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 September 30, 2020:
Measured on a recurring basis:
ARO Trust investments $ 220.3 $ 220.3 $ 220.3 $ 0 $ 0
Additional disclosures:
Long-term debt, including current portion (5,243.4) (6,689.2) 0 (6,689.2) 0
Assets (liabilities) at December 31, 2019:
Measured on a recurring basis:
ARO Trust investments $ 200.6 $ 200.6 $ 200.6 $ 0 $ 0
Additional disclosures:
Long-term debt, including current portion (4,065.0) (5,251.4) 0 (5,251.4) 0


					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 September 30, 2021:
Measured on a recurring basis:
ARO Trust investments	$	247.8	$	247.8	$	247.8	$	—	$	—
Additional disclosures:
Long-term debt, including current portion	(5,226.9)		(6,700.8)		—		(6,700.8)		—

Assets (liabilities) at December 31, 2020:
Measured on a recurring basis:
ARO Trust investments	$	235.5	$	235.5	$	235.5	$	—	$	—
Additional disclosures:
Long-term debt, including current portion	(5,239.8)		(6,949.0)		—		(6,949.0)		—

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~~(See Note 5 – ARO Trust for more information regarding the ARO Trust.)

Long-term debt, including current portion — 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)4 –Debt and Financing Arrangements).

~~7. TRANSACTIONS WITH AFFILIATES~~Note 7 – Transactions with Affiliates

We are a participant in Williams’ cash management program, and we receive advances from and make advances to Williams. At September 30, 2021 and December 31, 2020, our advances to Williams totaled approximately ~~$581.7 million.~~$1,448.3 million and $642.7 million, respectively. These advances are classified as Receivables - Advances to affiliate ~~in the accompanying Condensed Consolidated Balance Sheet. At December 31, 2019, our advances from Williams totaled approximately $252.5 million. These advances are classified as~~ ~~Payable - 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 September 30, ~~2020,~~2021, the interest rate was 0.01 percent.


Notes (Continued)			Table of Contents

Included in Operating Revenues in the accompanying Condensed ~~Consolidated~~ Statement of ~~Comprehensive~~Net Income are revenues received from affiliates of $15.4 million and $20.1 million for the three and nine months ended September 30, 2021, respectively, and $2.8 million and $8.0 million for the three and nine months ended September 30, 2020, ~~respectively, and $2.8 million and $8.4 million for the three and nine months ended September 30, 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~~Net Income are costs of gas purchased from affiliates of $1.4 million and $5.5 million for the three and nine months ended September 30, 2021, respectively, and $0.8 million and $3.8 million for the three and nine months ended September 30, 2020, ~~respectively, and $0.8 million and $3.0 million for the three and nine months ended September 30, 2019,~~ respectively. All gas purchases are made at market or contract prices.

We have 0no 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 $91.0~~In the accompanying Condensed Statement of Net Income, we have recorded approximately $82.1 million and ~~$269.5~~$237.8 million for the three and nine months ended September 30, 2021, respectively, and $68.7 million and $214.5 million for the three and nine months ended September 30, 2020, respectively, ~~and $110.7 million and $315.4 million for the three and nine months ended September 30, 2019, respectively,~~ for these ~~services. Such~~service expenses, which are primarily included in Operation and maintenance and Administrative and general ~~expenses in the accompanying Condensed Consolidated Statement of Comprehensive Income.~~expenses.

We provide services to certain of our affiliates. We recorded reductions in operating expenses for services provided to and reimbursed by our affiliates of $1.9 million and $5.4 million for the three and nine months ended September 30, 2021, respectively, and $1.6 million and $3.8 million for the three and nine months ended September 30, 2020, ~~respectively, and $1.2 million and $3.5 million for the three and nine months ended September 30, 2019,~~ respectively.

We made ~~equity~~cash distributions totaling ~~$785~~$287.9 million and ~~$559~~$785.0 million during the nine months ended September 30, ~~2020~~2021 and ~~2019,~~2020, respectively. During October ~~2020,~~2021, we made ~~an additional~~a distribution of ~~$235~~$55.8 million. Our parent made contributions to us totaling ~~$65~~$272.0 million and $65.0 million during the nine months ended September 30, 2021 and 2020, respectively, to fund a portion of our expenditures for additions to property, plant, and equipment. During October ~~2020,~~2021, our parent made an additional ~~$50~~$145.0 million contribution to us.


			Table of Contents


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

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~~2020 Annual Report on Form 10-K and with the Condensed ~~Consolidated~~ Financial Statements and Notes contained in this Form 10-Q.

~~Critical Accounting Estimates~~

~~Property, Plant, and Equipment and Other Identifiable Intangible Assets~~Results of Operations

~~As of September 30, 2020,~~
~~Property, plant, and equipment~~ in our Condensed Consolidated Balance Sheet includes approximately $215 million of capitalized project development costs for the Northeast Supply Enhancement project. Approvals required for the project from the New York State Department of Environmental Conservation and the New Jersey Department of Environmental Protection have been denied and we have not refiled at this time. Beginning in May 2020, we discontinued capitalization of costs related to this project.

The customer precedent agreements remain in effect and the project’s Federal Energy Regulatory Commission (FERC) certificate remains active. As such, we do not believe this project is probable of abandonment at this time and consider the carrying amount to be recoverable; thus no impairment charge has been recognized. It is reasonably possible that further adverse developments in the near future could change this determination, resulting in a future impairment charge of a substantial portion of the capitalized costs.

~~RESULTS OF OPERATIONS~~

Operating Income and Net Income

Operating Income for the nine months ended September 30, ~~2020~~2021 was ~~$995.3~~$1,015.4 million compared to ~~$897.2~~$995.3 million for the same period in ~~2019.~~2020. The increase in Operating Income of ~~$98.1~~$20.1 million ~~(10.9~~(2.0 percent) was primarily due to higher Natural gas transportation revenues in the first nine months of ~~2020~~2021 compared to the same period in ~~2019, and a favorable~~2020, partially offset by an unfavorable change in Operating Costs and Expenses, as discussed below.

Net Income for the nine months ended September 30, ~~2020~~2021 was ~~$779.7~~$791.2 million compared to ~~$715.9~~$779.7 million for the same period in ~~2019. The~~2020. In addition to the impacts to Operating Income mentioned above, the increase in Net Income of ~~$63.8~~$11.6 million ~~(8.9~~(1.5 percent) was ~~mostly attributable to the increase in~~further unfavorably impacted by ~~Operating Income~~Other (Income) and Other Expenses, as discussed below.

Operating Revenues

Natural gas sales decreased ~~$26.7~~$11.6 million ~~(30.3~~(19.0 percent) for the nine months ended September 30, ~~2020~~2021 compared to the same period in ~~2019.~~2020. The decrease was primarily due to ~~$26.6 million of~~ lower cash out ~~sales.~~sales, partially offset by higher prices. Cash out sales are offset in ~~our cost of natural gas sold~~operating costs and expenses and therefore have no impact on our ~~operating~~operating income or ~~net income.~~results of operations.

Natural gas transportation for the nine months ended September 30, ~~2020~~2021 increased ~~$49.7~~$78.2 million ~~(3.1~~(4.7 percent) over the same period in ~~2019.~~2020. The increase was primarily attributable to:

•$~~16.0~~51.8 million from our ~~Rivervale South to Market~~Southeastern Trail project placed in service in ~~September 2019;~~

•~~$12.3 million from our Gateway project placed in service in December 2019;~~

•~~$10.1 million from our Hillabee 2 project placed in service in May~~November 2020;

•$~~5.6~~16.5 million ~~due to one more billable day~~from our Leidy South project partially placed in service in November 2020;

•$~~5.1 million from revenues related to short-term firm transportation;~~

•~~$1.7 million from our St. James project placed in service in April 2019; and~~

•~~$1.2~~13.1 million higher electric power costs. Electric power costs are recovered from our customers through transportation rates and are offset in operating costs and expenses resulting in no net impact on our operating income or results of ~~operations.~~operations;

•$9.7 million higher revenues related to a cash out surcharge (offset in operating costs and expenses resulting in no net impact on our operating income or results of operations); and

•$7.9 million from our Hillabee 2 project placed in service in May 2020.

•Partially offset by ~~$2.6~~a decrease of $13.8 million primarily resulting from the implementation of lower rates for certain services coincident with the effective date of our last rate case settlement; and

•$6.0 million lower ~~commodity revenue.~~revenue due to one less billable day.

Natural gas storage increased $6.2 million (5.2 percent) for the nine months ended September 30, 2021 compared to the same period in 2020. The increase was primarily due to an increase in rates effective in the second quarter of 2020.


Management’s Discussion and Analysis (Continued)			Table of Contents

Operating Costs and Expenses

Excluding the Cost of natural gas sales, which is directly offset in operating revenues, our operating costs and expenses ~~decreased $34.9~~increased $63.4 million ~~(4.1~~(7.8 percent) for the nine months ended September 30, ~~2020~~2021 compared to the same period in ~~2019.~~2020. This ~~decrease~~increase was primarily attributable to:

•$~~37.4~~23.7 million ~~(13.6~~(8.5 percent) ~~favorable~~unfavorable change in Operation and maintenance costs primarily resulting from ~~$31.3~~(i) higher electric power costs of $13.1 million ~~decrease~~(electric power costs are recovered from customers through transportation rates and are offset in ~~direct~~operating revenues resulting in no net impact on our operating income or results of operations), (ii) employee labor and related ~~benefits due to~~benefit costs of $5.5 million, including charges associated with higher expected performance under the ~~voluntary separation program~~Williams incentive compensation plan and ~~restructuring initiated by Williams~~(iii) a $5.1 million increase in 2019, $6.7 million decrease due to the absence of costs transferred from capital in 2019, and $6.5 million decrease in contracted services mainly related to general maintenance and other testing on our pipeline, partly offset by a $8.6 million unfavorable change in capitalized labor;corporate allocations;

•$~~15.8~~14.4 million ~~(10.1~~(4.2 percent) ~~favorable~~increase in Depreciation and amortization primarily as a result of additional assets placed into service and, to a lesser extent, an increase in ARO asset depreciation due to revisions in expected timing of abandonment and expected future costs;

•$12.5 million (9.0 percent) unfavorable change in Administrative and general costs primarily due to ~~$9.5 million favorable change~~an increase in ~~direct~~ employee labor and related ~~benefits due to the voluntary separation program and restructuring initiated by Williams in 2019, $4.8 million favorable change in corporate allocations, and $1.5 million lower insurance expense;~~benefit costs;

•$~~10.9~~5.4 million ~~(56.0 percent) favorable~~unfavorable change in Other expense, net~~primarily due to $11.7~~ driven by $9.7 million ~~additional deferral of ARO related depreciation and $7.5 million favorable change related to the absence of costs transferred from capital in 2019,~~associated with a cash out surcharge, partially offset by ~~$3.9 million unfavorable change~~lower deferred other postretirement benefits costs of $3.4 million. Such amounts are offset in ~~the amortization of certain regulatory liabilities, and $3.3 million unfavorable change in project costs; and~~

•~~$3.8 million (19.9 percent) favorable change in~~ ~~Regulatory credit resulting from Tax Reform~~ ~~primarily related to general rate case Docket No. RP18-1126.~~

•~~Partially offset by $23.2 million (7.2 percent) increase in~~ ~~Depreciation and amortization~~ ~~costs primarily resulting from $11.7 million increase in ARO asset depreciation and $10.5 million increase in asset depreciation;~~

•~~$6.6 million (11.4 percent) increase in~~ ~~Taxes - other than income taxes~~ ~~related to an increase in property taxes in 2020; and~~

•~~$3.1 million (8.0 percent) increase in~~ ~~Cost of natural gas transportation~~ ~~primarily due to $1.2 million higher electric power costs and $1.1 million due to a fuel cost adjustment. Electric power costs are recovered from customers through transportation rates~~operating revenues resulting in no net ~~income~~ impact on our operating income or results of ~~operations.~~operations; and

•$7.3 million (11.3 percent) increase in Taxes — other than income taxes primarily due to an increase in estimated property taxes.

Other (Income) and Other Expenses

Other (income) and other expenses for the nine months ended September 30, ~~2020~~2021 had an unfavorable change of ~~$34.3~~$8.6 million ~~(18.9~~(4.0 percent) compared to the same period in ~~2019. This is mostly due to~~2020 driven by an ~~unfavorable change~~increase of ~~$18.3~~$8.4 million in interest expense primarily due to interest incurred on new debt issued May 2020, ~~and~~which was partially offset by the ~~Docket No. RP18-1126~~absence of interest expense associated with our rate reserve liability ~~and an unfavorable change of $11.3 million in~~ ~~Allowance~~ for ~~equity and borrowed funds used during construction (AFUDC)~~Docket No. RP18-1126.

Recent Developments

COVID-19

The outbreak of ~~novel coronavirus (COVID-19)~~COVID-19 has severely impacted global economic activity and caused significant volatility and negative pressure in financial markets. We ~~are monitoring~~continue to monitor the COVID-19 pandemic and ~~are taking~~have taken 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, as evidenced by the successful completion of our debt offerings during second-quarter 2020, and continue to have significant levels of unused capacity on our revolving credit facility with no significant debt maturities in the near future.

•We continue to monitor and adapt our remote working arrangements and limit 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.~~

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Management’s Discussion and Analysis (Continued)			Table of Contents

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. However, approvals required for the project from the New York State Department of Environmental Conservation and the New Jersey Department of Environmental Protection were denied in May 2020. We have not refiled our applications for those approvals. The project would increase capacity by 400 Mdth/d. See further discussion in Critical Accounting Estimates.

~~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 up to 230 Mdth/d of capacity under the project into service in the fourth quarter of 2020, and we plan to place the remainder of the project capacity into service in the first quarter of 2021. In total, the project is expected to increase capacity by 296 Mdth/d.

Leidy South

The Leidy South Project involves an expansion of our existing natural gas transmission system and an extension of our system through a capacity lease with National Fuel Gas Supply Corporation that will enable us to provide incremental firm transportation from Clermont, Pennsylvania and from the Zick interconnection on Transco’s Leidy Line to the River Road regulating station in Lancaster County, Pennsylvania. In July 2020, we received approval from the FERC for the project. We ~~plan to place up to~~placed 125 Mdth/d of capacity under the project into service in the fourth quarter of 2020, and in September and October of 2021, we placed approximately 382 Mdth/d of additional capacity into service. We plan to place the remainder of Transco’s facilities under the project into service ~~as early as the fourth quarter of 2021, assuming timely receipt of all necessary regulatory approvals.~~by year-end 2021. The project is expected to increase capacity by 582 Mdth/d.

Regional Energy Access

The Regional Energy Access Expansion involves an expansion of our existing natural gas transmission system to provide incremental firm transportation capacity from receipt points in northeastern Pennsylvania to multiple delivery points in Pennsylvania, New Jersey, and Maryland. ~~In June 2020, the FERC approved our request to use the FERC’s pre-filing review process for the project.~~ We ~~anticipate filing~~filed our certificate application for the project with the FERC ~~in the fourth quarter of 2020.We~~on March 26, 2021. We plan to place the project into service as early as the fourth quarter of 2023, assuming timely receipt of all necessary regulatory approvals. The project is expected to increase capacity ~~up to 760~~by 829 Mdth/d.

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			Table of Contents


~~ITEM~~ Item 4. Controls and Procedures			~~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~~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~~

On July 1, 2021, our parent implemented a new enterprise resource planning (ERP) system on a company-wide basis. We will continue to evaluate and test control changes in order to provide certification on the effectiveness, in all material respects, of our internal controls over financial reporting for the year ending December 31, 2021.

Other than as set forth above, there have been no changes during the third quarter of ~~2020~~2021 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

While it is not possible for us to predict the final outcome of any pending legal proceedings involving governmental authorities under federal, state, and local laws regulating the discharge of materials into the environment, we do not anticipate a material effect on our financial position if we were to receive an unfavorable outcome in any one or more of such proceedings. Our threshold for disclosing material environmental legal proceedings involving a governmental authority where potential monetary sanctions are involved is $1 million.


~~ITEM 1.~~			~~Legal Proceedings~~Table of Contents

~~Environmental~~

On September 2, 2020, we entered into a Consent Assessment of Civil Penalty with the Commonwealth of Pennsylvania, Department of Environmental Protection resolving permit violations observed by the Department and County Conservation Districts during the construction of our Atlantic Sunrise Project. The violations were largely attributable to the severe rain events we experienced during construction of the project. Pursuant to the Consent Assessment, we paid $736,294 as a civil penalty and contributed $100,000 to fund a community environmental project.

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

~~Other~~

The additional information called for by this item is provided in Note ~~3 of~~3. Contingent Liabilities and Commitments, included in the Notes to ~~Condensed Consolidated~~ Financial Statements included under Part I,1, Item 1. Financial Statements of this ~~report,~~Form 10-Q, which information is incorporated by reference into this item.


~~ITEM 1A.~~			Item 1A. Risk Factors

Part I, Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December ~~31, 2019, as supplemented by the disclosure Part II, Item 1A. in our Quarterly Report on Form 10-Q for the quarter ended March~~ 31, 2020 includes certain risk factors that could materially affect our business, financial condition, or future results. Those Risk Factors have not materially changed.

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~~ITEM~~ Item 6. Exhibits			~~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).

10.1						Credit Agreement dated as of October 8, 2021, between The Williams Companies, Inc., Northwest Pipeline LLC, and Transcontinental Gas Pipe Line Company, LLC, as co-borrowers, the lenders named therein, and Wells Fargo Bank, National Association, as Administrative Agent (filed on October 8, 2021 as Exhibit 10.1 to The Williams Companies, Inc.’s Current Report on Form 8-K (File No. 001-04174) 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.

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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:

November ~~2, 2020~~1, 2021

By:

/s/ Billeigh W. Mark

Billeigh W. Mark

Controller

(Principal Accounting Officer)


	September 30, 2020		December 31, 2019
ASSETS

Current Assets:
Cash	$	0	$	0
Receivables:
Affiliates	965		669
Advances to affiliate	581,665		0
Trade and other	213,298		253,266
Transportation and exchange gas receivables	4,676		6,360
Inventories	71,057		64,992
Regulatory assets	62,407		69,440
Other	14,506		11,240
Total current assets	948,574		405,967

Property, Plant and Equipment:
Natural gas transmission plant	17,201,803		16,764,904
Less-Accumulated depreciation and amortization	4,730,876		4,438,077
Total property, plant and equipment, net	12,470,927		12,326,827

Other Assets:
Regulatory assets	294,481		290,923
Right-of-use assets	80,526		84,979
Other	227,642		210,017
Total other assets	602,649		585,919

Total assets	$	14,022,150	$	13,318,713


	Three Months Ended September 30,
	2020		2019
Member’s Capital:
Balance at beginning of period	$	4,428,499	$	4,428,499
Cash contributions from parent	65,000		0


Balance at end of period	4,493,499		4,428,499
Retained Earnings:
Balance at beginning of period	2,176,231		2,195,168
Net income	245,714		274,282
Cash distributions to parent	(250,000)		(213,000)

Balance at end of period	2,171,945		2,256,450
Accumulated Other Comprehensive Loss:
Balance at beginning of period	0		(65)
Equity interest in unrealized loss in interest rate hedge	0		(93)
Balance at end of period	0		(158)

Total Member’s Equity	$	6,665,444	$	6,684,791


	September 30, 2020				December 31, 2019
	Amortized Cost Basis		Fair Value		Amortized Cost Basis		Fair Value
Money Market Funds	$	17.1	$	17.1	$	15.8	$	15.8
U.S. Equity Funds	59.5		94.2		55.3		83.3
International Equity Funds	34.2		37.7		31.8		35.4
Municipal Bond Funds	68.9		71.3		64.7		66.1
Total	$	179.7	$	220.3	$	167.6	$	200.6