Targa Resources (TRGP) 10-K 15 Feb 24 2023 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Feb. 09, 2024	Jun. 30, 2023
Cover [Abstract]
Entity Registrant Name	TARGA RESOURCES CORP.
Trading Symbol	TRGP
Entity Central Index Key	0001389170
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		223,155,363
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	FY
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2023
Entity Small Business	false
Entity Shell Company	false
Entity Emerging Growth Company	false
Entity Current Reporting Status	Yes
Entity Tax Identification Number	20-3701075
Entity File Number	001-34991
Entity Address, Address Line One	811 Louisiana Street
Entity Address, Address Line Two	Suite 2100
Entity Address, City or Town	Houston
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77002
City Area Code	713
Local Phone Number	584-1000
Entity Interactive Data Current	Yes
Title of 12(b) Security	Common Stock
Security Exchange Name	NYSE
Entity Incorporation, State or Country Code	DE
Document Annual Report	true
Document Transition Report	false
Entity Well-known Seasoned Issuer	Yes
Entity Public Float			$ 16,811.5
Entity Voluntary Filers	No
ICFR Auditor Attestation Flag	true
Document Financial Statement Error Correction [Flag]	false
Auditor Firm ID	238
Auditor Name	PricewaterhouseCoopers LLP
Auditor Location	Houston, Texas
Documents Incorporated by Reference	DOCUMENTS INCORPORATED BY REFERENCE Portions of the registrant’s definitive proxy statement for the 2024 Annual Meeting of Stockholders, to be filed no later than 120 days after the end of the fiscal year to which this Annual Report on Form 10-K relates, are incorporated by reference into Part III of this Annual Report on Form 10-K.

CONSOLIDATED BALANCE SHEETS (Un

CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Current assets:
Cash and cash equivalents	$ 141.7	$ 219
Trade receivables, net of allowances of $2.5 million and $2.2 million at December 31, 2023 and December 31, 2022	1,471	1,408.4
Inventories	371.5	393.8
Assets from risk management activities	111.9	179.9
Other current assets	98.5	155.5
Total current assets	2,194.6	2,356.6
Property, plant and equipment, net	15,806.4	14,214.6
Intangible assets, net	2,350.6	2,734.6
Long-term assets from risk management activities	33.3	24.5
Investments in unconsolidated affiliates	146.3	131.3
Other long-term assets	140.6	98.4
Total assets	20,671.8	19,560
Current liabilities:
Accounts payable	1,574.9	1,448.8
Accrued liabilities	281.7	289.5
Interest payable	229.6	174
Liabilities from risk management activities	54	320.1
Current debt obligations	620.7	834.3
Total current liabilities	2,760.9	3,066.7
Long-term debt	12,333.2	10,702.1
Long-term liabilities from risk management activities	16.8	140.1
Deferred income taxes, net	535.8	327.7
Other long-term liabilities	415.1	341.2
Commitments and Contingencies (see Notes 17 and 18)	0	0
Targa Resources Corp. stockholders' equity:
Common stock ($0.001 par value, 450,000,000 shares authorized as of December 31, 2023 and December 31, 2022)	0.2	0.2
Preferred stock ($0.001 par value, after designation of Series A Preferred Stock: 98,800,000 shares authorized, zero shares issued and outstanding)	0	0
Additional paid-in capital	3,058.8	3,702.3
Retained earnings (deficit)	492	(626.8)
Accumulated other comprehensive income (loss)	85.6	54.7
Treasury stock, at cost (17,484,440 shares as of December 31, 2023 and 11,896,829 shares as of December 31, 2022)	(896.9)	(464.7)
Total Targa Resources Corp. stockholders' equity	2,739.7	2,665.7
Noncontrolling interests	1,870.3	2,316.5
Total owners' equity	4,610	4,982.2
Total liabilities, Series A Preferred Stock and owners' equity	20,671.8	19,560
Series A Preferred Stock [Member]
Current liabilities:
Series A Preferred 9.5% Stock, $1,000 per share liquidation preference (1,200,000 shares authorized, zero shares issued and outstanding as of December 31, 2023 and December 31, 2022), net of discount	$ 0	$ 0

CONSOLIDATED BALANCE SHEETS (_2

CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Current assets:
Trade receivables, allowances	$ 2.5	$ 2.2
Targa Resources Corp. stockholders' equity:
Common stock, par value (in dollars per share)	$ 0.001	$ 0.001
Common stock, shares authorized (in shares)	450,000,000	450,000,000
Common stock, shares issued (in shares)	240,095,699	237,939,058
Common stock, shares outstanding (in shares)	222,611,259	226,042,229
Preferred stock, par value (in dollar per share)	$ 0.001	$ 0.001
Preferred stock, shares authorized (in shares)	98,800,000	98,800,000
Preferred stock, shares issued (in shares)	0	0
Preferred stock, shares outstanding (in shares)	0	0
Treasury stock, shares (in shares)	17,484,440	11,896,829
Series A Preferred Stock [Member]
LIABILITIES, SERIES A PREFERRED STOCK AND OWNERS' EQUITY
Preferred Series A Liquidation Stock Percentage	9.50%	9.50%
Preferred Stock, Liquidation Preference Per Share	$ 1,000	$ 1,000
Preferred Stock, Shares Authorized	1,200,000	1,200,000
Preferred Stock, Shares Issued	0	0
Preferred Stock, Shares Outstanding	0	0

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) - USD ($) shares in Millions, $ in Millions		12 Months Ended
		Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Revenues:
Total revenues		$ 16,060.3	$ 20,929.8	$ 16,949.8
Costs and expenses:
Product purchases and fuel		10,676.4	16,882.1	13,729.5
Operating expenses		1,077.9	912.8	747
Depreciation and amortization expense		1,329.6	1,096	870.6
General and administrative expense		348.7	309.7	273.2
Impairment of long-lived assets				452.3
Other operating (income) expense		1.5	0.2	12.4
Income (loss) from operations		2,626.2	1,729	864.8
Other income (expense):
Interest expense, net		(687.8)	(446.1)	(387.9)
Equity earnings (loss)		9	9.1	(23.9)
Gain (loss) from financing activities		(2.1)	(49.6)	(16.6)
Gain (loss) from sale of equity-method investment			435.9
Other, net		(2.8)	(15.1)	0.5
Income (loss) before income taxes		1,942.5	1,663.2	436.9
Income tax (expense) benefit		(363.2)	(131.8)	(14.8)
Net income (loss)		1,579.3	1,531.4	422.1
Less: Net income (loss) attributable to noncontrolling interests		233.4	335.9	350.9
Net income (loss) attributable to Targa Resources Corp.		1,345.9	1,195.5	71.2
Premium on repurchase of noncontrolling interests, net of tax	[1]	510.1	53.2
Dividends on Series A Preferred Stock			30	87.3
Deemed dividends on Series A Preferred Stock			215.5
Net income (loss) attributable to common shareholders		$ 835.8	$ 896.8	$ (16.1)
Net income (loss) per common share - basic		$ 3.69	$ 3.95	$ (0.07)
Net income (loss) per common share - diluted		$ 3.66	$ 3.88	$ (0.07)
Weighted average shares outstanding - basic		224.6	227.3	228.6
Weighted average shares outstanding - diluted		226	231.1	228.6
Sales of Commodities [Member]
Revenues:
Total revenues		$ 13,962.1	$ 19,066	$ 15,602.5
Fees from Midstream Services [Member]
Revenues:
Total revenues		$ 2,098.2	$ 1,863.8	$ 1,347.3
[1] Represents premium paid on the Grand Prix Transaction, Carnero Acquisition and the DevCo JV Repurchase. See Note 4 – Acquisitions and Divestitures

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Unaudited) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Net income (loss)	$ 1,579.3	$ 1,531.4	$ 422.1
Commodity hedging contracts:
Other comprehensive income (loss), pre-tax	40	367.4	(117.3)
Other comprehensive income (loss), related income tax	(9.1)	(81.8)	28.2
Other comprehensive income (loss), after tax	30.9	285.6	(89.1)
Comprehensive income (loss)	1,610.2	1,817	333
Less: Comprehensive income (loss) attributable to noncontrolling interests	233.4	335.9	350.9
Comprehensive income (loss) attributable to Targa Resources Corp.	1,376.8	1,481.1	(17.9)
Commodity Contracts [Member]
Commodity hedging contracts:
Change in fair value, pre-tax	193.4	(5.6)	(534.6)
Change in fair value, related income tax	(44.3)	1.3	128.4
Change in fair value, after tax	149.1	(4.3)	(406.2)
Settlements reclassified to revenues, pre-tax	(153.4)	373	417.3
Settlements reclassified to revenues, related income tax	35.2	(83.1)	(100.2)
Settlements reclassified to revenues, after tax	$ (118.2)	$ 289.9	$ 317.1

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN OWNERS' EQUITY AND SERIES A PREFERRED STOCK - USD ($) $ in Millions	Total	Cumulative Effect, Period of Adoption, Adjustment [Member]	Common Stock [Member]	Additional Paid-in Capital [Member]	Additional Paid-in Capital [Member] Cumulative Effect, Period of Adoption, Adjustment [Member]	Retained Earnings (Accumulated Deficit) [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Treasury Stock [Member]	Noncontrolling Interests [Member]	Series A Preferred Stock	Series A Preferred Stock Cumulative Effect, Period of Adoption, Adjustment [Member]
Balance at Dec. 31, 2020	$ 5,903.2	$ (448.3)	$ 0.2	$ 4,839.9	$ (448.3)	$ (1,893.5)	$ (141.8)	$ (150.9)	$ 3,249.3
Balance (in shares) at Dec. 31, 2020			228,062,000					6,731,000
Series A Preferred Stock at Dec. 31, 2020										$ 301.4	$ 448.3
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Compensation on equity grants	59.2			59.2
Dividend equivalent rights	(3.1)			(3.1)
Shares issued under compensation program (in shares)			1,312,000
Shares tendered for tax withholding obligations	(13.2)							$ (13.2)
Shares tendered for tax withholding obligations (in shares)			(397,000)					397,000
Repurchases of common stock	$ (40)							$ (40)
Repurchases of common stock (in shares)	(756,478)		(756,000)					756,000
Series A Preferred Stock dividends
Preferred stock dividends	$ (87.3)					(87.3)
Dividends in excess of retained earnings				(87.3)		87.3
Common stock dividends
Common stock dividends	(91.5)					(91.5)
Dividends in excess of retained earnings				(91.5)		91.5
Distributions to noncontrolling interests	(449.1)								(449.1)
Contributions from noncontrolling interests	15.8								15.8
Other comprehensive income (loss)	(89.1)						(89.1)
Net income (loss)	422.1					71.2			350.9
Balance at Dec. 31, 2021	5,178.7		$ 0.2	4,268.9		(1,822.3)	(230.9)	$ (204.1)	3,166.9
Balance (in shares) at Dec. 31, 2021			228,221,000					7,884,000
Series A Preferred Stock at Dec. 31, 2021										749.7
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Compensation on equity grants	57.5			57.5
Dividend equivalent rights	(7.1)			(7.1)
Shares issued under compensation program (in shares)			1,834,000
Shares tendered for tax withholding obligations	(35.8)							$ (35.8)
Shares tendered for tax withholding obligations (in shares)			(601,000)					601,000
Repurchases of common stock	$ (224.8)							$ (224.8)
Repurchases of common stock (in shares)	(3,412,354)		(3,412,000)					3,412,000
Series A Preferred Stock dividends
Preferred stock dividends	$ (30)					(30)
Dividends in excess of retained earnings				(30)		30
Deemed dividends - redemption of Series A Preferred Stock	(215.5)			(215.5)
Common stock dividends
Common stock dividends	(318.3)					(318.3)
Dividends in excess of retained earnings				(318.3)		318.3
Redemption of Series A preferred Stock										(749.7)
Distributions to noncontrolling interests	(354.5)								(354.5)
Contributions from noncontrolling interests	26.1								26.1
Repurchase of noncontrolling interests, net of tax	(911.1)			(53.2)					(857.9)
Other comprehensive income (loss)	285.6						285.6
Net income (loss)	1,531.4					1,195.5			335.9
Balance at Dec. 31, 2022	4,982.2		$ 0.2	3,702.3		(626.8)	54.7	$ (464.7)	2,316.5
Balance (in shares) at Dec. 31, 2022			226,042,000					11,897,000
Series A Preferred Stock at Dec. 31, 2022										0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Compensation on equity grants	62.4			62.4
Dividend equivalent rights	(3.9)			(2.3)		(1.6)
Shares issued under compensation program (in shares)			2,156,000
Shares tendered for tax withholding obligations	(55.8)							$ (55.8)
Shares tendered for tax withholding obligations (in shares)			(716,000)					716,000
Repurchases of common stock	$ (373.7)							$ (373.7)
Repurchases of common stock (in shares)	(4,870,559)		(4,871,000)					4,871,000
Excise tax on repurchases of common stock	$ (2.7)							$ (2.7)
Common stock dividends
Common stock dividends	(419)					(419)
Dividends in excess of retained earnings				193.5		(193.5)
Distributions to noncontrolling interests	(230)								(230)
Contributions from noncontrolling interests	9.7								9.7
Repurchase of noncontrolling interests, net of tax	(969.4)			(510.1)					(459.3)
Other comprehensive income (loss)	30.9						30.9
Net income (loss)	1,579.3					1,345.9			233.4
Balance at Dec. 31, 2023	$ 4,610		$ 0.2	$ 3,058.8		$ 492	$ 85.6	$ (896.9)	$ 1,870.3
Balance (in shares) at Dec. 31, 2023			222,611,000					17,484,000
Series A Preferred Stock at Dec. 31, 2023										$ 0

CONSOLIDATED STATEMENTS OF CH_2

CONSOLIDATED STATEMENTS OF CHANGES IN OWNERS' EQUITY AND SERIES A PREFERRED STOCK (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Statement of Stockholders' Equity [Abstract]
Preferred stock dividends, per share	$ 47.5	$ 95
Common stock dividends, per share	$ 1.4	$ 0.4

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Cash flows from operating activities
Net income (loss)	$ 1,579.3	$ 1,531.4	$ 422.1
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Amortization in interest expense	13.2	10.5	10.3
Compensation on equity grants	62.4	57.5	59.2
Depreciation and amortization expense	1,329.6	1,096	870.6
Impairment of long-lived assets			452.3
(Gain) loss on sale or disposition of assets	(5.3)	(9.6)	2
Write-downs of assets	6.9	9.8	10.3
Accretion of asset retirement obligations	5.9	4.8	4
Deferred income tax expense (benefit)	349.6	125.1	12.1
Equity (earnings) loss of unconsolidated affiliates	(9)	(9.1)	23.9
Distributions of earnings received from unconsolidated affiliates	13.1	12.2	84
Risk management activities	(275.4)	302.5	116
(Gain) loss from financing activities	2.1	49.6	16.6
(Gain) loss from sale of equity-method investment		(435.9)
Changes in operating assets and liabilities, net of acquisitions:
Receivables and other assets	(20.6)	219.7	(392.4)
Inventories	36	(236.2)	40.6
Accounts payable, accrued liabilities and other liabilities	68.2	(383)	565.4
Interest payable	55.6	35.5	5.9
Net cash provided by operating activities	3,211.6	2,380.8	2,302.9
Cash flows from investing activities
Outlays for property, plant and equipment	(2,385.4)	(1,334.3)	(505.1)
Outlays for business acquisition, net of cash acquired		(3,503.9)
Outlays for asset acquisition, net of cash acquired		(205.2)
Proceeds from sale of assets	4.7	23	12.2
Investments in unconsolidated affiliates	(24.6)	(1.5)	(0.6)
Proceeds from sale of equity-method investment		857
Return of capital from unconsolidated affiliates	5.5	16.8	20.2
Other, net	(1)	(1.6)	0.1
Net cash provided by (used in) investing activities	(2,400.8)	(4,149.7)	(473.2)
Debt obligations:
Proceeds from borrowings under credit facilities		5,845	620
Repayments of credit facilities	(290)	(5,555)	(1,455)
Proceeds from borrowings of commercial paper notes	59,002.8	30,504.3
Repayments of commercial paper notes	(59,836.5)	(29,495.6)
Proceeds from borrowings under term loan facility		1,500
Repayments of term loan facility	(1,000)
Proceeds from borrowings under accounts receivable securitization facility	143.1	1,230	630
Repayments of accounts receivable securitization facility	(368.1)	(580)	(830)
Proceeds from issuance of senior notes	3,727.7	2,741.4	1,000
Redemption of senior notes		(1,473.2)	(1,132)
Principal payments of finance leases	(42.9)	(19.7)	(12.5)
Costs incurred in connection with financing arrangements	(36.1)	(45.7)	(9.6)
Repurchase of shares	(429.5)	(260.6)	(53.2)
Contributions from noncontrolling interests	9.7	26.1	15.8
Distributions to noncontrolling interests	(222.1)	(316.4)	(500)
Repurchase of noncontrolling interests	(1,118.9)	(926.3)
Redemption of Series A Preferred Stock		(965.2)
Dividends paid to common and Series A Preferred shareholders	(427.3)	(379.7)	(187.5)
Net cash provided by (used in) financing activities	(888.1)	1,829.4	(1,914)
Net change in cash and cash equivalents	(77.3)	60.5	(84.3)
Cash and cash equivalents, beginning of period	219	158.5	242.8
Cash and cash equivalents, end of period	$ 141.7	$ 219	$ 158.5

Pay vs Performance Disclosure

Pay vs Performance Disclosure - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Pay vs Performance Disclosure
Net Income (Loss)	$ 1,345.9	$ 1,195.5	$ 71.2

Insider Trading Arrangements

Insider Trading Arrangements	Nov. 13, 2023 shares
Trading Arrangements, by Individual
Material Terms of Trading Arrangement	On November 13, 2023 , Julie H. Boushka , our Senior Vice President and Chief Accounting Officer , adopted a Rule 10b5-1 trading arrangement that is intended to satisfy the affirmative defense of Rule 10b5-1(c) for the sale of up to 10,000 shares of our common stock until March 5, 2025 .
Julie H. Boushka [Member]
Trading Arrangements, by Individual
Name	Julie H. Boushka
Title	Senior Vice President and Chief Accounting Officer
Rule 10b5-1 Arrangement Adopted	true
Adoption Date	November 13, 2023
Termination Date	March 5, 2025
Aggregate Available	10,000

Organization and Operations

Organization and Operations	12 Months Ended
	Dec. 31, 2023
Organization [Abstract]
Organization and Operations	Note 1 — Organizati on and Operations Our Organization Targa Resources Corp. (NYSE: TRGP) owns, operates, acquires, and develops a diversified portfolio of complementary domestic midstream infrastructure assets. In this Annual Report, unless the context requires otherwise, references to “we,” “us,” “our,” “the Company,” “Targa” or “TRGP” are intended to mean our consolidated business and operations. TRGP controls the general partner of and owns all of the outstanding common units representing limited partner interests in Targa Resources Partners LP, referred to herein as the “Partnership”. Targa consolidates the Partnership and its subsidiaries under GAAP, and the accompanying consolidated financial statements have been prepared under the rules and regulations of the SEC. Targa’s consolidated financial statements include differences from the consolidated financial statements of the Partnership. The most noteworthy differences are: • the inclusion of the TRGP senior revolving credit facility and term loan facility; • the inclusion of the TRGP senior notes; • the inclusion of the TRGP commercial paper notes; • the inclusion of Series A Preferred Stock (“Series A Preferred”) prior to full redemption in May 2022; and • the impacts of TRGP’s treatment as a corporation for U.S. federal income tax purposes. Our Operations The Company is primarily engaged in the business of: • gathering, compressing, treating, processing, transporting, and purchasing and selling natural gas; • transporting, storing, fractionating, treating, and purchasing and selling NGLs and NGL products, including services to LPG exporters; and • gathering, storing, terminaling, and purchasing and selling crude oil. See Note 23 – Segment Information for certain financial information regarding our business segments.

Basis of Presentation

Basis of Presentation	12 Months Ended
	Dec. 31, 2023
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation	Note 2 — Basis of Presentation These accompanying financial statements and related notes present our consolidated financial position as of December 31, 2023 and 2022, and the results of operations, comprehensive income (loss), cash flows, and changes in owners’ equity for the years ended December 31, 2023, 2022 and 2021 . We have prepared these consolidated financial statements in accordance with GAAP. All significant intercompany balances and transactions have been eliminated in consolidation. Certain amounts in prior periods have been reclassified to conform to the current year presentation.

Significant Accounting Policies

Significant Accounting Policies	12 Months Ended
	Dec. 31, 2023
Accounting Policies [Abstract]
Significant Accounting Policies	Note 3 — Significant Accounting Policies Consolidation Policy Our consolidated financial statements include the accounts of all entities that we control and our proportionate interest in the accounts of certain gas gathering and processing facilities in which we own an undivided interest and are responsible for our proportionate share of the costs and expenses of the facilities. Third party ownership interests in our controlled subsidiaries are presented as noncontrolling interests within the equity section of our Consolidated Balance Sheets, except in the case of undivided interest ownership. In our Consolidated Statements of Operations and Consolidated Statements of Comprehensive Income (Loss), noncontrolling interests reflect the attribution of results to third-party investors. All intercompany balances and transactions have been eliminated in consolidation. As of December 31, 2023, our consolidated joint ventures include the following: Gathering and Processing Segment • 60 % ownership interest in Centrahoma Processing LLC; • 55 % ownership interest in Targa Badlands LLC; • 72.8 % undivided interest in the assets of Targa Pipeline Mid-Continent WestTex LLC; and • 76.8 % ownership interest in Venice Energy Services Company, LLC. Logistics and Transportation Segment • 88 % ownership interest in Cedar Bayou Fractionators, L.P.; and • 80 % ownership interest in Targa Train 7 LLC. We apply the equity method of accounting to investments over which we exercise significant influence over the operating and financial policies of our investee, but do not exercise control. We evaluate our equity investments for impairment when evidence indicates the carrying amount of our investment is no longer recoverable. Evidence of a loss in value might include, but would not necessarily be limited to, absence of an ability to recover the carrying amount of the investment or inability of the equity method investee to sustain an earnings capacity that would justify the carrying amount of the investment. When the estimated fair value of an equity investment is less than its carrying value and the loss in value is determined to be other than temporary, we recognize the excess of the carrying value over the estimated fair value as a non-cash pre-tax impairment loss within Equity earnings (loss) in our Consolidated Statements of Operations. As of December 31, 2023, our investments in unconsolidated affiliates include the following: Gathering and Processing Segment • 50 % ownership interest in Little Missouri 4 LLC (“Little Missouri 4”). Logistics and Transportation Segment • 50 % ownership interest in Cayenne Pipeline, LLC (“Cayenne”); and • 38.8 % ownership interest in Gulf Coast Fractionators (“GCF”). Use of Estimates The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the amounts reported in these financial statements and accompanying notes. Estimates and judgments are based on information available at the time such estimates and judgments are made. Changes in facts and circumstances may result in revised estimates and actual results could differ materially from those estimates. Estimates and judgments are used in, among other things, (i) estimating unbilled revenues, product purchases and operating and general and administrative cost accruals, (ii) developing fair value assumptions, including estimates of future cash flows and discount rates, (iii) analyzing long-lived assets for possible impairment, (iv) estimating the useful lives of assets and (v) estimating contingencies, guarantees and indemnifications. Cash and Cash Equivalents Cash and cash equivalents include all cash on hand, demand deposits, and short-term, highly liquid investments that are readily convertible into cash, and have original maturities of three months or less. Allowanc e for Credit Losses Estimated losses on accounts receivable are provided through an allowance for credit losses. We estimate the allowance for credit losses through various procedures, including extensive review of our trade receivable balances by counterparty, assessing economic events and conditions, our historical experience with counterparties, the counterparty’s financial condition and the amount and age of past due accounts. We continuously evaluate our ability to collect amounts owed to us. Receivables are considered past due if full payment is not received by the contractual due date. Our evaluation procedures also include performing account reconciliations, dispute resolution and payment confirmation. As the financial condition of any counterparty changes, circumstances develop or additional information becomes available, adjustments to our allowance may be required. Inventories Our inventories consist primarily of NGL product inventories, which are valued at the lower of cost or net realizable value, using the average cost method. Most NGL product inventories turn over monthly, but some inventory, primarily propane, is acquired and held during the year to meet anticipated heating season requirements of our customers. Commodity inventories that are not physically or contractually available for sale under normal operations (“deadstock”) are included in Property, plant and equipment. Product Exchanges Exchanges of NGL products are executed to satisfy timing and logistical needs of the exchange parties. Volumes received and delivered under exchange agreements are recorded as inventory. If the locations of receipt and delivery are in different markets, an exchange differential may be billed or owed. The exchange differential is recorded as either accounts receivable or accrued liabilities. Gas Processing Imbalances Quantities of natural gas and/or NGLs over-delivered or under-delivered, related to certain gas plant operational balancing agreements, are recorded monthly as inventory or as a payable using the weighted average price at the time the imbalance was created. Inventory imbalances receivable are valued at the lower of cost or net realizable value using the average cost method; inventory imbalances payable are valued at replacement cost. These imbalances are settled either by current cash-out settlements or by adjusting future receipts or deliveries of natural gas or NGLs. Derivative Instruments We utilize derivative instruments to manage the volatility of our cash flows due to fluctuating energy commodity prices. For balance sheet classification purposes, we analyze the fair values of the derivative instruments on a contract by contract basis and report the related fair values and any related collateral by counterparty on a gross basis. Cash flows from derivative instruments designated as hedges are recognized in the same financial statement line item as the cash flows from the respective item being hedged. We formally document all relationships between hedging instruments and hedged items, as well as its risk management objectives and strategy for undertaking the hedge. This documentation includes the specific identification of the hedging instrument and the hedged item, the nature of the risk being hedged and the manner in which the hedging instrument’s effectiveness will be assessed. At the inception of the hedge and on an ongoing basis, we assess whether the derivatives used in hedging transactions are highly effective in achieving the offset of changes in cash flows attributable to the hedged risk. We record all derivative instruments at fair value with the exception of those that we apply the normal purchases and normal sales election. The table below summarizes the accounting treatment for our derivative instruments, and the impact on our consolidated financial statements: Recognition and Measurement Derivative Treatment Balance Sheet Income Statement Normal Purchases and Normal Sales Fair value not recorded Earnings recognized when volumes are physically delivered or received Mark-to-Market Recorded at fair value Change in fair value recognized currently in earnings Cash Flow Hedge Recorded at fair value with changes in fair value deferred in Accumulated Other Comprehensive Income (“AOCI”) The gain/loss on the derivative instrument is reclassified out of AOCI into earnings when the forecasted transaction occurs We will discontinue hedge accounting on a prospective basis when a hedge instrument is terminated, ceases to be highly effective or the forecasted transaction is no longer probable to occur. Gains and losses deferred in AOCI related to cash flow hedges for which hedge accounting has been discontinued remain deferred until the forecasted transaction occurs. If it is probable that a hedged forecasted transaction will not occur, deferred gains or losses on the hedging instrument are reclassified to earnings immediately. Property, Plant and Equipment Property, plant and equipment is recorded at acquisition cost less accumulated depreciation. Depreciation is computed using the straight-line method over the estimated useful lives of the assets. The determination of the useful lives of property, plant and equipment requires us to make various assumptions, including our expected use of the asset and the supply of, and demand for, hydrocarbons in the markets served, normal wear and tear of the facilities, and the extent and frequency of maintenance programs. Upon disposition or retirement of property, plant and equipment, any gain or loss is recorded to operations. Expenditures for routine maintenance and repairs are expensed as incurred. Expenditures to refurbish an asset that increases its existing service potential or prevents environmental contamination are capitalized and depreciated over the remaining useful life of the asset or major asset component. Certain costs directly related to the construction of assets, including internal labor costs, interest and engineering costs, are capitalized. Impairment of Long-Lived Assets We evaluate long-lived assets, including intangible assets, for impairment when events or changes in circumstances indicate our carrying amount of an asset may not be recoverable, including changes to our estimates that could have an impact on our assessment of asset recoverability. Asset recoverability is measured by comparing the carrying value of the asset or asset group with its expected future pre-tax undiscounted cash flows. Individual assets are grouped at the lowest level for which the related identifiable cash flows are largely independent of the cash flows of other assets and liabilities. These cash flow estimates require us to make judgments and assumptions related to operating and cash flow results, economic obsolescence, the business climate, contractual, legal and other factors. If the carrying amount exceeds the expected future undiscounted cash flows, we recognize a non-cash pre-tax impairment loss equal to the excess of net book value over fair value as determined by quoted market prices in active markets or present value techniques if quotes are unavailable. The estimated cash flows used to assess recoverability of our long-lived assets and measure fair value of our asset groups are derived from current business plans, which are developed using near-term price and volume projections reflective of the current environment and management's projections for long-term average prices and volumes. In addition to near and long-term price assumptions, other key assumptions include volume projections, operating costs, timing of incurring such costs, and the use of an appropriate terminal value and discount rate. Any changes we make to these projections and assumptions could result in significant revisions to our evaluation of recoverability of our long-lived assets and the recognition of additional impairments. We believe our estimates and models used to determine fair value are similar to what a market participant would use. Goodwill Goodwill is a residual intangible asset that results when the cost of an acquisition exceeds the fair value of the net identifiable assets of the acquired business. Goodwill is not subject to amortization but is tested for impairment at least annually. This test requires us to attribute goodwill to an appropriate reporting unit, which is an operating segment or one level below an operating segment (also known as a component). We evaluate goodwill for impairment on November 30 of each year, or whenever impairment indicators are present. Prior to us conducting the goodwill impairment test, we complete a review of the carrying values of our long-lived assets, including property, plant and equipment and other intangible assets. If it is determined that the carrying values are not recoverable, we reduce the carrying values of the long-lived assets pursuant to our policy on property, plant and equipment. As part of our goodwill impairment test, we may first assess qualitative factors to determine if the quantitative goodwill impairment test is necessary. If we choose to bypass this qualitative assessment or determine that a goodwill impairment test is required, our annual goodwill impairment test is performed by comparing the fair value of a reporting unit with its carrying amount (including attributed goodwill). We recognize an impairment loss in our Consolidated Statements of Operations and a corresponding reduction of goodwill on our Consolidated Balance Sheets for the amount by which the carrying amount exceeds the reporting unit’s fair value. The goodwill impairment loss will not exceed the total amount of goodwill allocated to that reporting unit. Additionally, when measuring goodwill, we consider income tax effects from any tax-deductible goodwill on the carrying amount of the reporting unit, if applicable. Intangible Assets Our intangible assets include producer dedications under long-term contracts and customer relationships associated with business and asset acquisitions. The fair value of these acquired intangible assets was determined at the date of acquisition based on the present value of estimated future cash flows. We amortize the costs of our assets in a manner that closely resembles the expected benefit pattern of the intangible assets or on a straight-line basis, where such pattern is not readily determinable, over the periods in which we benefit from services provided to customers. Asset Retirement Obligations Asset retirement obligations (“AROs”) are legal obligations associated with the retirement of tangible long-lived assets that result from their acquisition, construction, development and/or normal operation. We record a liability and increase the basis in the underlying asset for the present value of each expected ARO when there is a legal obligation to settle under existing or enacted law, statute, written or oral contract or by legal construction. Our obligations are estimated based on discounted cash flow (“DCF”) estimates. Over time, the ARO liability is accreted to its present value as a period cost and the capitalized amount is depreciated over the asset’s respective useful life. At least annually, we review the projected timing and amount of AROs and reflect revisions as an increase or decrease in the carrying amount of the liability and the basis in the underlying asset. Upon settlement, we will recognize any difference between the recorded amount and the actual settlement cost as a gain or loss. Debt Issuance Costs Costs incurred in connection with the issuance of long-term debt and any original issue discount or premium are deferred and charged to interest expense over the term of the related debt. Debt issuance costs related to revolving credit facilities and the term loan facility are amortized on a straight-line basis and those related to long-term debt are amortized using the effective-interest method. Debt issuance costs related to revolving credit facilities are presented as other long-term assets, and debt issuance costs related to long-term debt obligations with scheduled maturities are reflected as a deduction to the carrying amount of long-term debt on the Consolidated Balance Sheets. Gains or losses on debt repurchases, redemptions and debt extinguishments include any associated unamortized debt issuance costs. Accounts Receivable Securitization Facility Proceeds from the sale or contribution of certain receivables under the Partnership’s accounts receivable securitization facility (the “Securitization Facility”) are treated as collateralized borrowings in our financial statements. Proceeds and repayments under the Securitization Facility are reflected as cash flows from financing activities in our Consolidated Statements of Cash Flows. Commercial Paper Program Under the terms of the unsecured commercial paper note program (the “Commercial Paper Program”), we may issue, from time to time, unsecured commercial paper notes with varying maturities of less than one year. Amounts available under the Commercial Paper Program may be issued, repaid, and re-issued from time to time, with the maximum aggregate face or principal amount outstanding at any one time not to exceed $ 2.75 billion. We maintain a minimum available borrowing capacity under the $ 2.75 billion TRGP senior revolving credit facility (the “TRGP Revolver”) equal to the aggregate amount outstanding under the Commercial Paper Program as support. The Commercial Paper Program is guaranteed by each subsidiary that guarantees the TRGP Revolver. The outstanding borrowings of the commercial paper program are classified as noncurrent because we intend to refinance the borrowings on a long-term basis through the TRGP Revolver. We confirm, on a quarterly basis, that there is sufficient liquidity under the TRGP Revolver to refinance outstanding borrowings of the Commercial Paper Program and such liquidity is not overcommitted for other anticipated uses. As the outstanding borrowings of the Commercial Paper Program are included as part of long-term debt (i.e., classified as noncurrent), we report Commercial Paper Program borrowings and repayments gross on the statement of cash flows (consistent with the presentation of cash flows associated with the TRGP Revolver). Debt Modification and Extinguishment When similar debt instruments are issued and redeemed in the same period, we evaluate whether the issuance of the new instrument should be accounted for as a modification of the existing debt or as an extinguishment of the existing debt and issuance of new debt. We account for these debt transactions as modifications unless they are considered substantially different debt instruments, in which case we account for them as debt extinguishments and new issuances. Transactions involving the issuance of a new debt instrument to one lender and the concurrent satisfaction of an existing debt instrument with another unrelated lender are always accounted for as an extinguishment of the existing debt and issuance of new debt. Debt instruments are considered substantially different if the present value of the cash flows under the terms of the new debt instrument is at least 10 percent different from the present value of the remaining cash flows under the terms of the existing debt instrument. We consider changes in principal amounts, interest rates, and maturity dates of the existing and new instruments when evaluating the change in cash flows between the instruments. Transactions accounted for as modifications do no t result in a gain or loss. We calculate a new effective interest rate based on the revised cash flows. Fees paid to existing lenders are capitalized and amortized while expenses paid to third parties are expensed. Transactions accounted for as extinguishments result in derecognition of the extinguished debt and recording the new debt at fair value. A gain or loss is recognized for the difference between the carrying value of the extinguished debt and the fair value of the new debt. New fees paid to existing lenders are expensed while fees paid to third parties are capitalized and amortized as debt issuance costs. Environmental Liabilities and Other Loss Contingencies We accrue a liability for loss contingencies, including environmental remediation costs arising from claims, assessments, litigation, fines, penalties and other sources, when the loss is probable and reasonably estimable. Income Taxes We file many income tax returns with the U.S. Department of the Treasury, as well as numerous states. We are required to estimate our income taxes in each of the jurisdictions in which we operate. This process involves estimating our actual current tax payable and related tax expense, together with assessing temporary differences resulting from differing treatment of certain items, such as depreciation, for tax and accounting purposes. These differences can result in deferred tax assets and liabilities, which are reported on a net basis by jurisdiction within our Consolidated Balance Sheets. We report these timing differences based on statutory tax rates applicable to the scheduled timing difference reversal periods. We assess the likelihood that we will recover our deferred tax assets from future taxable income. We establish a valuation allowance if we believe that it is more likely than not (a likelihood of more than 50 percent) that some portion or all of the deferred tax assets will not be realized. Any change in the valuation allowance would impact our income tax provision and net income in the period in which such a determination is made. We consider all available evidence to determine whether, based on the weight of the evidence, we need a valuation allowance. Evidence used includes information about our current financial position and our results of operations for the current and preceding years, as well as all currently available information about future years, including our anticipated future performance, the reversal of deferred tax liabilities and tax planning strategies. Dividends Preferred and common dividends declared are recorded as a reduction of retained earnings to the extent that retained earnings was available at the close of the prior quarter, with any excess recorded as a reduction of additional paid-in capital. Comprehensive Income Comprehensive income includes net income and other comprehensive income (“OCI”), which includes changes in the fair value of derivative instruments that are designated as cash flow hedges . Revenue Recognition Our operating revenues are primarily derived from the following activities: • sales of natural gas, NGLs, condensate and crude oil; • services related to compressing, gathering, treating, and processing of natural gas; and • services related to NGL fractionation, terminaling and storage, transportation and treating. We have multiple types of contracts with commercial counterparties and many of these contracts contain embedded fees with settlement provisions that deduct these fees from the sales price paid by Targa in exchange for commodities. The commercial relationship of the counterparty in such contracts is inherently one of a supplier, rather than a customer, and therefore, such contracts are excluded from the provisions of the revenue recognition guidance in Topic 606, Revenue from Contracts with Customers . Any cash inflows or fees that are realized on these supply type contracts are reported as a reduction of Product purchases and fuel. Our revenues, therefore, are measured based on consideration specified in a contract with parties designated as customers. We recognize revenue when we satisfy a performance obligation by transferring control over a commodity or service to a customer. Sales and other taxes we collect, that are both imposed on and concurrent with revenue-producing activities, are excluded from revenues. We generally report sales revenues on a gross basis in our Consolidated Statements of Operations, as we typically act as the principal in the transactions where we receive and control commodities. However, buy-sell transactions that involve purchases and sales of inventory with the same counterparty, which are legally contingent or in contemplation of one another, as well as other instances where we do not control the commodities, but rather are acting as an agent to the supplier, are reported as a single revenue transaction on a combined net basis. Our commodity sales contracts typically contain multiple performance obligations, whereby each distinct unit of commodity to be transferred to the customer is a separate performance obligation. Under such contracts, revenue is recognized at the point in time each unit is transferred to the customer because the customer is able to direct the use of, and obtain substantially all of the remaining benefits from, the commodity at that time. In certain instances, it may be determinable that the customer receives and consumes the benefits of each unit as it is transferred. Under such contracts, we have a single performance obligation comprised of a series of distinct units of commodity; and in such instance, revenue is recognized over time using the units delivered output method, as each distinct unit is transferred to the customer. Our commodity sales contracts are typically priced at a market index, but may also be set at a fixed price. When our sales are priced at a market index, we apply the allocation exception for variable consideration and allocate the market price to each distinct unit when it is transferred to the customer. The fixed price in our commodity sales contracts generally represents the standalone selling price, and therefore, when each distinct unit is transferred to the customer, we recognize revenue at the fixed price. Our service contracts typically contain a single performance obligation. The underlying activities performed by us are considered inputs to an integrated service and not separable because such activities in combination are required to successfully transfer the single overall service that the customer has contracted for and expects to receive. Therefore, the underlying activities in such contracts are not considered to be distinct services. However, in certain instances, the customer may contract for additional distinct services and therefore additional performance obligations may exist. In such instances, the transaction price is allocated to the multiple performance obligations based on their relative standalone selling prices. The performance obligation(s) in our service contracts is a series of distinct days of the applicable service over the life of the contract (fundamentally a stand-ready service), whereby we recognize revenue over time using an output method of progress based on the passage of time (i.e., each day of service). This output method is appropriate because it directly relates to the value of service transferred to the customer to date, relative to the remaining days of service promised under the contract. The transaction price for our service contracts is typically comprised of variable consideration, which is primarily dependent on the volume and composition of the commodities delivered and serviced. The variable consideration is generally commensurate with our efforts to perform the service and the terms of the variable payments relate specifically to our efforts to satisfy each day of distinct service. Therefore, the variable consideration is typically not estimated at contract inception, but rather the allocation exception for variable consideration is applied, whereby the variable consideration is allocated to each day of service and recognized as revenue when each day of service is provided. When we are entitled to noncash consideration in the form of commodities, the variability related to the form of consideration (market price) and reasons other than form (volume and composition) are interrelated to the service, and therefore, we measure the noncash consideration at the point in time when the volume, mix and market price related to the commodities retained in-kind are known. This results in the recognition of revenue based on the market price of the commodity when the service is performed. In addition, if the transaction price includes a fixed component (i.e., a fixed capacity reservation fee), the fixed component is recognized ratably on a straight-line basis over the contract term, as each day of service has elapsed, which is consistent with the output method of progress selected for the performance obligation. Our customers are typically billed on a monthly basis, or earlier, if final delivery and sale of commodities is made prior to month-end, and payment is typically due within 10 to 30 days . As a practical matter, we define the unit of account for revenue recognition purposes based on the passage of time ranging from one month to one quarter, rather than each day. This is because the financial reporting outcome is the same regardless of whether each day or month/quarter is treated as the distinct service in the series. That is, at the end of each month or quarter, the variability associated with the amount of consideration for which we are entitled to, is resolved, and can be included in that month or quarter’s revenue. We have certain long-term contractual arrangements under which we have received consideration, but for which all conditions for revenue recognition have not been met. These arrangements result in deferred revenue, which will be recognized over the periods that performance will be provided. We have certain contracts that contain provisions in which customers provide contributions in aid of construction in exchange for Targa constructing assets to fulfill the services in the contract. In general, these arrangements result in deferred revenue, which will be recognized over the contract term. Contract Assets We classify our contract assets as receivables because we generally have an unconditional right to payment for the commodities sold or services performed at the end of the reporting period. We enter into various contractual arrangements that result in the transfer of assets for no upfront compensation or cash payments, resulting in more favorable long-term contractual terms. The fair value of the assets transferred is reflected as long-term contract assets. These deferred amounts are amortized over the term of the related contract into the appropriate revenue or cost of sales accounts. Share-Based Compensation We award share-based compensation to employees and non-employee directors in the form of restricted stock, restricted stock units and performance share units. Compensation expense on our equity-classified awards is recorded at grant-date fair value. Compensation expense is recognized in general and administrative expense over the requisite service period of each award, and forfeitures are recognized as they occur. We may purchase a portion of the shares issued to satisfy employees’ tax withholding obligations on vested awards. These shares are recorded in treasury stock, at cost, and cash paid is classified as a financing activity in our Consolidated Statements of Cash Flows. All excess tax benefits and tax deficiencies related to share-based compensation are recognized as income tax benefit or expense in our Consolidated Statements of Operations, with the tax effects of exercised or vested awards treated as discrete items in the reporting period which they occur. Excess tax benefits are classified as an operating activity. Earnings per Share We calculate basic earnings (loss) per common share (“EPS”) using the two-class method, which is an earnings allocation formula that determines net income (loss) per share for each class of common stock and participating security according to dividends declared and participation rights in undistributed earnings. Our participating securities consist of unvested restricted stock units that vest no later than three years following grant date as well as certain four-year retention awards that participate in nonforfeitable dividends with the common equity owners. EPS is net income (loss) attributable to common shareholders less earnings allocated to participating securities divided by the sum of the weighted-average number of common shares outstanding. Earnings are allocated to common stock and participating securities based on the amount of dividends paid in the current period plus an allocation of the undistributed earnings to the extent that each security participates in earnings. Diluted EPS includes any dilutive effect of preferred stock, unvested restricted stock, restricted stock units and performance share units. The dilutive effect is calculated through the application of (i) the if-converted method for convertible preferred s

Acquisitions and Divestitures

Acquisitions and Divestitures	12 Months Ended
	Dec. 31, 2023
Business Combinations [Abstract]
Acquisitions and Divestitures	Note 4 – Acquisitions and Divestitures Delaware Basin Acquisition In July 2022, we completed the acquisition of all of the interests in Lucid Energy Delaware, LLC (“Lucid”) from Riverstone Holdings LLC and Goldman Sachs Asset Management for approximately $ 3.5 billion in cash (the “Delaware Basin Acquisition”), subject to customary closing adjustments. We received a final net working capital adjustment payment of approximately $ 11.4 million in the fourth quarter of 2022. We funded the acquisition with (i) $ 1.5 billion in proceeds drawn under our Term Loan Agreement with Mizuho Bank, Ltd. (“Mizuho”) as the Administrative Agent and a lender, and other lenders party thereto (the “Term Loan Facility”), (ii) $ 750.0 million in aggregate principal amount of our 5.200 % Senior Notes due 2027 (the “ 5.200 % Notes”) and $ 500.0 million in aggregate principal amount of our 6.250 % Senior Notes due 2052 (the “ 6.250 % Notes”) pursuant to an underwritten public offering that closed in July 2022 and (iii) $ 800.0 million drawn on our $ 2.75 billion TRGP revolving credit facility (the “TRGP Revolver”). We recorded $ 16.9 million of debt issuance costs related to the Term Loan Facility, the 5.200 % Notes and the 6.250 % Notes in our Consolidated Balance Sheets. See Note 8 – Debt Obligations for further details on our financing activities. The assets acquired in the Delaware Basin Acquisition provide natural gas gathering, treating, and processing services in the Delaware Basin, through owning and operating approximately 1,050 miles of natural gas pipelines and approximately 1.4 billion cubic feet per day (“Bcf/d”) of cryogenic natural gas processing capacity primarily in Eddy and Lea counties of New Mexico. The Delaware Basin Acquisition assets increased our footprint in the Delaware Basin and are integrated into our Permian Delaware operations. The Delaware Basin Acquisition was accounted for under the acquisition method in accordance with ASC 805, Business Combinations , which requires, among other things, assets acquired and liabilities assumed to be recorded at their fair value on the acquisition date. The valuation of the acquired assets and liabilities was prepared using fair value methods and assumptions, including projections of future production volumes, commodity prices, and other cash flows, market-participant assumptions (e.g., discount rate and exit multiple), expectations regarding customer contracts and relationships, tangible asset replacement costs, and other management estimates. The fair value measurements of assets acquired and liabilities assumed are based on inputs that are not observable in the market and therefore represent Level 3 inputs, as defined in Note 15 – Fair Value Measurements. These inputs require judgments and estimates at the time of valuation. The following table summarizes the purchase price allocation based on the final fair values assigned to assets acquired and liabilities assumed (in millions): Cash and cash equivalents $ 9.9 Trade receivables, net of allowances (1) 211.0 Other current assets 3.5 Property, plant and equipment, net 1,669.0 Intangible assets, net 1,882.0 Other long-term assets 57.3 Current liabilities ( 236.7 ) Other long-term liabilities ( 100.7 ) Purchase price $ 3,495.3 (1) The fair value of the assets acquired included trade receivables of $ 211.0 million. The gross amount due under contract was $ 213.4 million, of which $ 2.4 million was expected to be uncollectible. Trade receivables, net of allowances, excluded $ 18.5 million that was due from Targa. We reflected this settlement of a preexisting relationship as a reduction of the purchase price in accordance with ASC 805. The value of property, plant and equipment is determined using the cost approach and is primarily comprised of Gathering and Processing assets that will be depreciated on a straight-line basis over an estimated weighted-average useful life of 20 years . The associated useful lives of property, plant and equipment were based on the period over which the assets are expected to contribute directly or indirectly to our future cash flows. The value of intangible assets is comprised of customer relationships, which represent estimated value of long-term contracts with customers that will be amortized in a manner that closely resembles the expected benefit pattern of the intangible assets over an estimated useful life of 14 years . The associated useful lives of intangible assets were based on the period over which the assets are expected to contribute directly or indirectly to our future cash flows. The fair value of customer relationships was determined at the date of acquisition based on the present value of estimated future cash flows using the multi-period excess earnings method. The significant assumptions used by management in determining the fair value of customer relationships intangible assets include future revenues, discount rate, and customer attrition rates. The fair values of the tangible and intangible assets are Level 3 measurements in the fair value hierarchy. The fair value of the intangible assets was determined by applying a discounted cash flow approach, which utilized a discount rate of approximately 19 % based on our estimate of the risk that a theoretical market participant would assign to the respective intangible assets, and customer attrition rates of approximately 5 %. The results of operations attributable to the assets and liabilities acquired in the Delaware Basin Acquisition have been included in our consolidated financial statements as part of our Permian Delaware operations in the Gathering and Processing segment since the date of the acquisition. Revenue and Net Income attributable to the assets acquired for the period August 1, 2022 through December 31, 2022 were $ 374.1 million and $ 7.9 million, respectively. As of December 31, 2022, we had incurred $ 14.4 million of acquisition-related costs. Unaudited Pro Forma Financial Information The following unaudited pro forma summary presents the consolidated results of operations for the years ended December 31, 2022 and 2021 as if the Delaware Basin Acquisition had occurred on January 1, 2021. The unaudited pro forma financial information is presented for informational purposes only and is not necessarily indicative of our results of operations that would have occurred had the transaction been consummated at the beginning of the period presented, nor is it necessarily indicative of future results. Year Ended December 31, 2022 2021 Revenues $ 21,268.9 $ 17,464.7 Net income (loss) 1,477.4 215.7 The summarized unaudited pro forma information has been calculated after applying our accounting policies and reflects adjustments for the following: • Reflects depreciation and amortization based on the fair values of property, plant and equipment and intangible assets, respectively. Property, plant and equipment are depreciated utilizing a straight-line approach. Intangible assets are amortized in a manner that closely resembles their expected benefit pattern; • Excludes $ 14.4 million of acquisition-related costs incurred as of December 31, 2022 from pro forma net income for the year ended December 31, 2022. Pro forma net income for the year ended December 31, 2021 was adjusted to include those costs ; • Excludes the impact of operations previously sold by Lucid, prior to Targa’s acquisition of Lucid; • Excludes the impact of historical activity between Targa and Lucid, prior to Targa’s acquisition of Lucid; • Excludes general and administrative expense related to Lucid’s former parent company, which Targa did not acquire; • Excludes amortization of interest expense and debt issuance costs associated with Lucid’s debt, which was not assumed by Targa; • Includes interest expense and debt issuance cost amortization associated with Targa’s borrowings to finance the Delaware Basin Acquisition; and • Reflects the income tax effects of the above pro forma adjustments. South Texas Acquisition In April 2022, we completed the acquisition of Southcross Energy Operating LLC and its subsidiaries (“Southcross”) for a purchase price of $ 201.9 million (the “South Texas Acquisition”), subject to customary closing adjustments. We made a final net working capital adjustment payment of approximately $ 1.5 million in the fourth quarter of 2022. We acquired a portfolio of complementary midstream infrastructure assets and associated contracts that have been integrated into our SouthTX Gathering and Processing operations, including the remaining interests in the two joint ventures in South Texas that we previously held as investments in unconsolidated affiliates and that have been consolidated beginning in the second quarter of 2022. We accounted for the purchase as an asset acquisition and capitalized $ 1.8 million of acquisition-related costs and assumed liabilities of $ 1.8 million as components of the cost of assets acquired. We allocated $ 28.1 million to our purchase of Southcross’ interest in the two joint ventures for purposes of consolidation and $ 169.7 million, $ 3.9 million and $ 5.3 million of the residual cost to property, plant and equipment, current assets and liabilities, net and other non-current assets, respectively. See Note 7 – Investments in Unconsolidated Affiliates for further discussion on South Texas Acquisition. Joint Ventures Acquisitions and Divestitures In February 2018, we formed three development joint ventures (“DevCo JVs”) with investment vehicles affiliated with Stonepeak Infrastructure Partners (“Stonepeak”) to fund portions of Grand Prix NGL Pipeline (“Grand Prix”), Gulf Coast Express Pipeline (“GCX”) and a 110 MBbl/d fractionator in Mont Belvieu, Texas (“Train 6”). For a four-year period beginning on the date that all three projects commenced commercial operations, we had the option to acquire all or part of Stonepeak’s interests in the DevCo JVs (the “DevCo JV Call Right”). The purchase price payable for such partial or full interests was based on a predetermined fixed return or multiple on invested capital, including distributions received by Stonepeak from the DevCo JVs. In January 2022, we exercised the DevCo JV Call Right and closed on the purchase of all of Stonepeak’s interests in the DevCo JVs for $ 926.3 million (the “DevCo JV Repurchase”). Following the DevCo JV Repurchase, we owned a 75 % interest in the Permian to Mont Belvieu segment of Grand Prix through Grand Prix Pipeline LLC (the “Grand Prix Joint Venture”) (prior to the Grand Prix Transaction, as defined below), a 100 % interest in Train 6 and a 25 % equity interest in GCX (prior to the GCX Sale as defined below in February 2022). The changes in our ownership interests were accounted for as equity transactions representing the acquisitions of noncontrolling interests. The amount of the redemption price in excess of the carrying amount, net of tax was $ 53.2 million, which was accounted for as a premium on repurchase of noncontrolling interests, and resulted in a reduction to Net income (loss) attributable to common shareholders. In May 2022, we completed the sale of Targa GCX Pipeline LLC, which held a 25 % equity interest in GCX, to a third party for $ 857.0 million (the “GCX Sale”). As a result of the GCX Sale, we recognized a gain of $ 435.9 million in Gain (loss) from sale of equity method investment in our Consolidated Statements of Operations in 2022. See Note 7 – Investments in Unconsolidated Affiliates for further discussion on GCX Sale. In January 2023, we completed the acquisition of Blackstone Energy Partners’ 25 % interest in the Grand Prix Joint Venture (the “Grand Prix Transaction”) for aggregate consideration of $ 1.05 billion in cash and a final closing adjustment of $ 41.9 million. Following the closing of the Grand Prix Transaction, we own 100 % of the interest in Grand Prix. The change in our ownership interests was accounted for as an equity transaction representing the acquisition of noncontrolling interests. The amount of the redemption price in excess of the carrying amount, net of tax, was $ 489.4 million, which was accounted for as a premium on repurchase of noncontrolling interests, and resulted in a reduction to Net income (loss) attributable to common shareholders. In December 2023, we completed the acquisition of the remaining 50 % membership interest in Carnero G&P LLC (“Carnero”) from our joint venture partner for cash consideration of $ 27.0 million (the “Carnero Acquisition”). The change in our ownership interests was accounted for as an equity transaction representing the acquisition of noncontrolling interests. The amount of the consideration in excess of the carrying amount, net of tax, was $ 20.1 million, which was accounted for as a premium on repurchase of noncontrolling interests, and resulted in a reduction to Net income (loss) attributable to common shareholders.

Property, Plant and Equipment a

Property, Plant and Equipment and Intangible Assets	12 Months Ended
	Dec. 31, 2023
Property Plant And Equipment And Intangible Assets [Abstract]
Property, Plant and Equipment and Intangible Assets	Note 5 — Property, Plant and E quipment and Intangible Assets Property, Plant and Equipment and Intangible Assets December 31, 2023 December 31, 2022 Estimated Useful Lives (In Years) Gathering systems $ 10,858.3 $ 10,403.1 5 to 20 Processing and fractionation facilities 8,285.5 7,421.2 5 to 25 Terminaling and storage facilities 1,403.9 1,341.6 5 to 25 Transportation assets 3,294.0 2,919.3 10 to 50 Other property, plant and equipment 430.5 387.6 3 to 50 Land 185.0 163.3 — Construction in progress 1,456.1 1,011.0 — Finance lease right-of-use assets 351.9 266.1 5 to 14 Property, plant and equipment 26,265.2 23,913.2 Accumulated depreciation, amortization and impairment ( 10,458.8 ) ( 9,698.6 ) Property, plant and equipment, net $ 15,806.4 $ 14,214.6 Intangible assets 4,378.0 4,379.7 10 to 20 Accumulated amortization and impairment ( 2,027.4 ) ( 1,645.1 ) Intangible assets, net $ 2,350.6 $ 2,734.6 For each of the years ended December 31, 2023, 2022 and 2021 depreciation expense was $ 945.6 million, $ 853.8 million and $ 739.6 million, respectively. Intangible Assets Intangible assets consist of customer contracts and customer relationships acquired in prior business combinations. The fair value of these acquired intangible assets were determined at the date of acquisition based on the present values of estimated future cash flows. Amortization expense attributable to these assets is recorded over the periods in which we benefit from services provided to customers. For each of the years ended December 31, 2023, 2022 and 2021 amortization expense was $ 384.0 million, $ 242.2 million and $ 131.0 million, respectively. The estimated annual amortization expense for intangible assets is approximately $ 373.2 million, $ 326.0 million, $ 279.8 million, $ 252.2 million and $ 234.0 million for each of the years 2024 through 2028. As of December 31, 2023 , the weighted average amortization period for our intangible assets was approximately 11.4 years. The changes in our intangible assets are as follows: December 31, 2023 December 31, 2022 Balance at beginning of period $ 2,734.6 $ 1,094.8 Additions from Delaware Basin Acquisition — 1,882.0 Amortization ( 384.0 ) ( 242.2 ) Balance at end of period $ 2,350.6 $ 2,734.6 Impairments of Long-Lived Assets We review and evaluate our long-lived assets, including intangible assets, for impairment when events or changes in circumstances indicate that the related carrying amount of such assets may not be recoverable, including changes to our estimates that could have an impact on our assessment of asset recoverability. 2021 In the fourth quarter of 2021, we recorded a non-cash pre-tax impairment charge of $ 452.3 million, comprised of $ 295.7 million for the impairment of certain gas processing facilities and gathering systems, and $ 156.6 million related to the impairment of intangible customer relationships associated with our Central operations in the Gathering and Processing segment. The impairment was a result of our assessment that forecasted undiscounted future net cash flows from operations, while positive, will not be sufficient to recover the existing total net book value of the underlying assets. Underlying our assessment were lower expectations regarding volumes and rates associated with the renewal of future expiring contracts and negotiation of new contracts in the South Texas region. For the 2021 impairment assessment discussed above, we determined fair value through the use of discounted estimated cash flows to measure the impairment loss for each asset group for which undiscounted future net cash flows were not sufficient to recover the net book value. The estimated cash flows used to assess recoverability of our long-lived assets and measure fair value of our asset groups are derived from current business plans, which are developed using near-term price and volume projections reflective of the current environment and management’s projections for long-term average prices and volumes. In addition to near and long-term price assumptions, other key assumptions include volume projections, operating costs, timing of incurring such costs, and the use of an appropriate terminal value and discount rate. We believe our estimates and models used to determine fair value are similar to what a market participant would use. The fair value measurement of our long-lived assets was based, in part, on significant inputs not observable in the market (as discussed above) and thus represents a Level 3 measurement. The significant unobservable inputs used include discount rates and determination of terminal values. We utilized a weighted average discount rate of 9.5 % when deriving the fair value of the asset groups impaired during 2021. The weighted average discount rate and terminal values reflect management’s best estimate of inputs a market participant would utilize. The carrying value adjustments are included in Impairment of long-lived assets in our Consolidated Statements of Operations. We may identify additional triggering events in the future, which will require additional evaluations of the recoverability of the carrying value of our long-lived assets and may result in future impairments.

Goodwill

Goodwill	12 Months Ended
	Dec. 31, 2023
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill	Note 6 – Goodwill As of December 31, 2023, we had $ 45.2 million of goodwill included in Other long-term assets on the Consolidated Balance Sheets related to the March 2017 acquisition of gas gathering and processing and crude oil gathering assets in the Permian Basin. December 31, 2023 December 31, 2022 Permian Midland $ 23.2 $ 23.2 Permian Delaware 22.0 22.0 Goodwill $ 45.2 $ 45.2 The future cash flows and resulting fair values of these reporting units are sensitive to changes in crude oil, natural gas and NGL prices. The direct and indirect effects of significant declines in commodity prices from the date of acquisition would likely cause the fair values of these reporting units to fall below their carrying values, and could result in an impairment of goodwill. As described in Note 3 – Significant Accounting Policies, we evaluate goodwill for impairment at least annually on November 30, or more frequently if we believe necessary based on events or changes in circumstances. For our 2023, 2022 and 2021 annual evaluations, we performed a qualitative assessment, which indicated that it is not more likely than not that the fair values of the Permian Midland and Permian Delaware reporting units were less than their carrying amounts, and therefore, a quantitative goodwill impairment test was not necessary. Our qualitative assessment considered, among other things, the overall financial performance and future outlook of the Permian Midland and Permian Delaware reporting units, industry and market considerations, and other relevant entity-specific events. The fair value measurements utilized for the evaluation of goodwill for impairment are based on inputs that are not observable in the market and therefore represent Level 3 inputs, as defined in Note 15 – Fair Value Measurements. These inputs require significant judgments and estimates at the time of valuation.

Investments in Unconsolidated A

Investments in Unconsolidated Affiliates	12 Months Ended
	Dec. 31, 2023
Equity Method Investments and Joint Ventures [Abstract]
Investments in Unconsolidated Affiliates	Note 7 – Investments in Unconsolidated Affiliates Our investments in unconsolidated affiliates consist of the following: Gathering and Processing Segment • 50 % operated ownership interest in Little Missouri 4. Logistics and Transportation Segment • 38.8 % operated ownership interest in GCF; and • 50 % operated ownership interest in Cayenne. The terms of these joint venture agreements do not afford us the degree of control required for consolidating them in our consolidated financial statements, but do afford us the significant influence required to employ the equity method of accounting. In April 2022, we completed the South Texas Acquisition. Prior to closing the South Texas Acquisition, we had two operated joint ventures in South Texas: a 75 % interest in T2 LaSalle Gathering Company L.L.C. (“T2 LaSalle”) and a 50 % interest in T2 Eagle Ford Gathering Company L.L.C. (“T2 Eagle Ford” and, together with T2 LaSalle, the “T2 Joint Ventures”). Following the closing of the South Texas Acquisition, we own 100 % of the interest in the T2 Joint Ventures. In May 2022, we completed the GCX Sale. Prior to the GCX Sale, we owned a 25 % non-operated ownership interest in GCX. Following the announcement of the GCX Sale in February 2022, we ceased recognizing equity earnings (loss) due to the terms of the sales agreement. As a result of the GCX Sale, we recognized a gain of $ 435.9 million in Gain (loss) from sale of equity method investment in our Consolidated Statements of Operations in 2022. The following table shows the activity related to our investments in unconsolidated affiliates: Balance at December 31, 2020 Equity Earnings (Loss) Cash Distributions Disposition/ Contributions Balance at December 31, 2021 GCX $ 435.2 $ 63.4 $ ( 78.1 ) $ — $ 0.5 $ 421.0 Little Missouri 4 104.7 10.9 ( 17.5 ) — — 98.1 T2 Eagle Ford 79.8 ( 57.0 ) ( 1.0 ) — 0.1 21.9 T2 LaSalle 39.6 ( 35.0 ) ( 0.4 ) — — 4.2 GCF (1) 38.5 ( 8.6 ) ( 1.1 ) — — 28.8 Cayenne 16.2 2.4 ( 6.1 ) — — 12.5 Total $ 714.0 $ ( 23.9 ) $ ( 104.2 ) $ — $ 0.6 $ 586.5 Balance at December 31, 2021 Equity Earnings (Loss) Cash Distributions Disposition/ Contributions Balance at December 31, 2022 GCX $ 421.0 $ 5.7 $ ( 14.3 ) $ ( 412.4 ) $ — $ — Little Missouri 4 98.1 5.5 ( 12.9 ) — — 90.7 GCF (1) 28.8 ( 3.2 ) — — 1.5 27.1 T2 Eagle Ford (2) 21.9 ( 0.6 ) ( 0.8 ) ( 20.5 ) — — T2 LaSalle (2) 4.2 ( 0.3 ) — ( 3.9 ) — — Cayenne 12.5 2.0 ( 1.0 ) — — 13.5 Total $ 586.5 $ 9.1 $ ( 29.0 ) $ ( 436.8 ) $ 1.5 $ 131.3 Balance at December 31, 2022 Equity Earnings (Loss) Cash Distributions Disposition/ Contributions Balance at December 31, 2023 Little Missouri 4 $ 90.7 $ 7.7 $ ( 11.3 ) $ — $ — $ 87.1 GCF (1) 27.1 ( 4.1 ) ( 2.0 ) — 24.6 45.6 Cayenne 13.5 5.4 ( 5.3 ) — — 13.6 Total $ 131.3 $ 9.0 $ ( 18.6 ) $ — $ 24.6 $ 146.3 (1) In January 2021, the GCF facility was temporarily idled and Targa assumed operatorship in the first half of 2021. In January 2023, we reached an agreement with our partners to reactivate the GCF facility. The facility is expected to be operational in the second quarter of 2024. (2) Following the closing of the South Texas Acquisition in April 2022, the T2 Joint Ventures are 100 % owned and consolidated by Targa. Our equity loss for the year ended December 31, 2021 included the effect of impairments in the carrying values of our investments in the T2 Joint Ventures. As a result of the decrease in current and expected future utilization of the underlying assets, we determined that factors indicated that a decrease in the value of our investments occurred that was other than temporary. As a result of the evaluation, we recorded non-cash pre-tax impairment losses of $ 47.3 million and $ 29.9 million on our investments in T2 Eagle Ford and T2 LaSalle, respectively, in the fourth quarter of 2021. The impairment losses represented our proportionate share of impairment charges recorded by the joint ventures, as well as impairments of the unamortized excess fair values resulting from the purchase accounting related to the mergers with Atlas Energy L.P. and Atlas Pipeline Partners L.P. in 2015.

Debt Obligations

Debt Obligations	12 Months Ended
	Dec. 31, 2023
Debt Disclosure [Abstract]
Debt Obligations	Note 8 — De bt Obligations December 31, 2023 December 31, 2022 Current: Partnership accounts receivable securitization facility, due August 2024 (1) $ 575.0 $ 800.0 Finance lease liabilities 45.7 34.3 Current debt obligations 620.7 834.3 Long-term: Term loan facility, variable rate, due July 2025 500.0 1,500.0 TRGP senior revolving credit facility, variable rate, due February 2027 (2) 175.0 1,298.7 Senior unsecured notes issued by TRGP: 5.200 % fixed rate, due July 2027 750.0 750.0 6.150 % fixed rate, due March 2029 1,000.0 — 4.200 % fixed rate, due February 2033 750.0 750.0 6.125 % fixed rate, due March 2033 900.0 — 6.500 % fixed rate, due March 2034 1,000.0 — 4.950 % fixed rate, due April 2052 750.0 750.0 6.250 % fixed rate, due July 2052 500.0 500.0 6.500 % fixed rate, due February 2053 850.0 — Unamortized discount ( 29.5 ) ( 8.4 ) Senior unsecured notes issued by the Partnership: (3) 6.500 % fixed rate, due July 2027 705.2 705.2 5.000 % fixed rate, due January 2028 700.3 700.3 6.875 % fixed rate, due January 2029 679.3 679.3 5.500 % fixed rate, due March 2030 949.6 949.6 4.875 % fixed rate, due February 2031 1,000.0 1,000.0 4.000 % fixed rate, due January 2032 1,000.0 1,000.0 12,179.9 10,574.7 Debt issuance costs, net of amortization ( 90.8 ) ( 65.6 ) Finance lease liabilities 244.1 193.0 Long-term debt 12,333.2 10,702.1 Total debt obligations $ 12,953.9 $ 11,536.4 Irrevocable standby letters of credit: (2) Letters of credit outstanding under the TRGP senior revolving credit facility $ 22.3 $ 33.2 (1) As of December 31, 2023, the Partnership had $ 575.0 million of qualifying receivables under its $ 600.0 million accounts receivable securitization facility (the “Securitization Facility”), resulting in $ 25.0 million of availability. (2) We maintain an unsecured commercial paper note program (the “Commercial Paper Program”), the borrowings of which are supported through maintaining a minimum available borrowing capacity under the TRGP Revolver equal to the aggregate amount outstanding under the Commercial Paper Program. As of December 31, 2023 , the TRGP Revolver had no borrowings outstanding and the Commercial Paper Program had $ 175.0 million borrowings outstanding, resulting in approximately $ 2.6 billion of available liquidity, after accounting for outstanding letters of credit. (3) As of February 2022, we guarantee all of the Partnership’s outstanding senior unsecured notes. The following table shows the range of interest rates and weighted average interest rate incurred on our variable-rate debt obligations during the year ended December 31, 2023: Range of Interest Rates Incurred Weighted Average Interest Rate Incurred TRGP Revolver and Commercial Paper Program 5.2 % - 6.2 % 5.9 % Securitization Facility 5.2 % - 6.3 % 5.8 % Term Loan Facility 5.8 % - 6.8 % 6.5 % Compliance with Debt Covenants As of December 31, 2023, we were in compliance with the covenants contained in our various debt agreements. In February 2022, we and certain of our subsidiaries entered into a parent guarantee whereby each party to the agreement unconditionally guarantees, jointly and severally, the payment of all of the obligations of the Partnership and Targa Resources Partners Finance Corporation (together with the Partnership, the “Partnership Issuers”) under the respective indentures governing the Partnership Issuers’ senior unsecured notes. Debt Obligations Partnership’s Accounts Receivable Securitization Facility In August 2023, the Partnership amended the Securitization Facility to decrease the size of the Securitization Facility from $ 800.0 million to $ 600.0 million and to extend the termination date of the Securitization Facility to August 29, 2024 . The Securitization Facility provides up to $ 600.0 million of borrowing capacity at SOFR rates plus a margin through August 29, 2024 . Under the Securitization Facility, certain Partnership subsidiaries sell or contribute certain qualifying receivables, without recourse, to another of its consolidated subsidiaries (Targa Receivables LLC or “TRLLC”), a special purpose consolidated subsidiary created for the sole purpose of the Securitization Facility. TRLLC, in turn, sells an undivided percentage ownership in the eligible receivables to third-party financial institutions. Sold or contributed receivables up to the amount of the outstanding debt under the Securitization Facility are not available to satisfy the claims of the creditors of the selling or contributing subsidiaries or the Partnership. Any excess receivables are eligible to satisfy the claims. TRGP Credit Agreement In February 2022, the Company entered into the TRGP Revolver with Bank of America, N.A., as the Administrative Agent, Collateral Agent and Swing Line Lender, and the other lenders party thereto. The TRGP Revolver provides for a revolving credit facility in an initial aggregate principal amount up to $ 2.75 billion (with an option to increase such maximum aggregate principal amount by up to $ 500.0 million in the future, subject to the terms of the TRGP Revolver) and a swing line sub-facility of up to $ 100.0 million. The TRGP Revolver matures on February 17, 2027 . In February 2022, TRGP and the Partnership received a corporate investment grade credit rating from Standard & Poor’s Financial Services LLC (“S&P”) and Fitch Ratings Inc., and in March 2022, the Partnership received a corporate investment grade credit rating from Moody’s Investors Service, Inc. (“Moody’s”). As a result, in accordance with the TRGP Revolver, the collateral under the TRGP Revolver was released from the liens securing our obligations thereunder. The revolving credit facility bears interest at the Company’s option at: (a) the Base Rate, which is the highest of Bank of America’s prime rate, the federal funds rate plus 0.5 % and the Term SOFR (as such term is defined in the TRGP Revolver) rate plus 1.0 % (subject in each case to a floor of 0.0 %), plus an applicable margin ranging from 0.125 % to 0.75 %, dependent on the Company’s non-credit-enhanced senior unsecured long-term debt ratings (or, if no such debt is outstanding at such time, then the corporate, issuer or similar rating with respect to the Company that has been most recently announced) (the “Debt Rating”), or (b) Term SOFR (which includes, for Term SOFR loans, a SOFR adjustment of plus 0.10 %) plus an applicable margin ranging from 1.125 % to 1.75 %, dependent on the Company’s Debt Rating. The Company is required to pay a commitment fee equal to an applicable rate ranging from 0.125 % to 0.35 % (dependent on the Company’s Debt Rating), in each case times the actual daily unused portion of the revolving credit facility. The obligations under the TRGP Revolver are guaranteed by substantially all material wholly-owned domestic subsidiaries of the Company, including by the Partnership. The TRGP Revolver requires the Company to maintain a ratio of consolidated funded indebtedness to consolidated adjusted EBITDA (the “Consolidated Leverage Ratio”), determined as of the last day of each quarter for the four-fiscal quarter period ending on the date of determination, of no more than 5.50 to 1.00 . The TRGP Revolver restricts the Company’s ability to make dividends to stockholders if an event of default (as defined in the TRGP Revolver) exists or would result from such distribution. In addition, the TRGP Revolver contains various covenants that may limit, among other things, the Company’s ability to incur indebtedness, grant liens, make investments, repay or amend the terms of certain other indebtedness, merge or consolidate, sell assets, and engage in transactions with affiliates. Term Loan Facility In July 2022, we entered into the Term Loan Facility. The Term Loan Facility provides for a three-year , $ 1.5 billion unsecured term loan facility and matures in July 2025 . We used the proceeds from the Term Loan Facility to fund a portion of the Delaware Basin Acquisition. The Term Loan Facility bears interest at the Company’s option at: (a) the Base Rate (as defined in the Term Loan Facility), which is the highest of the (i) federal funds rate plus 0.5 %, (ii) Mizuho’s prime rate, and (iii) the Term SOFR (as defined in the Term Loan Facility) rate plus 1.0 % (subject in each case to a floor of 0.0 %), plus an applicable margin ranging from 0.125 % to 0.75 % dependent on the Company’s non-credit-enhanced senior unsecured long-term debt ratings (or, if no such debt is outstanding at such time, then the corporate, issuer or similar rating with respect to the Company that has been most recently announced) (the “Debt Rating”), or (b) Term SOFR plus 0.10 % plus an applicable margin ranging from 1.125 % to 1.75 % dependent on the Debt Rating . Our obligations under the Term Loan Facility are guaranteed by substantially all material wholly-owned domestic restricted subsidiaries of the Company, including the Partnership. The Term Loan Facility requires the Company to maintain a Consolidated Leverage Ratio (as defined in the Term Loan Facility), determined as of the last day of each quarter for the four-fiscal-quarter-period ending on the date of determination, of no more than 5.50 to 1.00 . For any four-fiscal-quarter-period during which a material acquisition or disposition occurs, the total leverage ratio will be determined on a pro forma basis as though such event had occurred as of the first day of such four-fiscal-quarter-period. The Term Loan Facility limits the Company’s ability to make dividends to stockholders if an event of default (as defined in the Term Loan Facility) exists or would result from such distribution. In addition, the Term Loan Facility contains various covenants that may limit, among other things, the Company’s ability to incur subsidiary indebtedness, grant liens, make investments, merge or consolidate, and engage in transactions with affiliates. Commercial Paper Program In July 2022, we established the Commercial Paper Program. Under the terms of the Commercial Paper Program, we may issue, from time to time, unsecured commercial paper notes with varying maturities of less than one year. Amounts available under the Commercial Paper Program may be issued, repaid and re-issued from time to time, with the maximum aggregate face or principal amount outstanding at any one time not to exceed $ 2.75 billion. We maintain a minimum available borrowing capacity under the TRGP Revolver equal to the aggregate amount outstanding under the Commercial Paper Program as support. The Commercial Paper Program is guaranteed by each subsidiary that guarantees the TRGP Revolver. The commercial paper notes are presented in Long-term debt on our Consolidated Balance Sheets. TRGP’s Senior Unsecured Notes All issues of our senior unsecured notes (the “TRGP Notes”) rank pari passu with our existing and future senior indebtedness, including debt issued under the TRGP Revolver, the Commercial Paper Program and the Term Loan Facility, and rank senior in right of payment to any of our future subordinated indebtedness. The TRGP Notes are unconditionally guaranteed by certain of our subsidiaries that guarantee the TRGP Revolver. Each guarantee ranks equally in right of payment with all of such guarantor’s existing and future unsecured senior debt and other unsecured guarantees of senior debt. The notes and the guarantees are effectively junior to any secured indebtedness of ours or any guarantor to the extent of the value of the assets securing such indebtedness and structurally subordinated to all indebtedness and other obligations of our subsidiaries that do not guarantee the notes. Interest on all issues of TRGP Notes is payable semi-annually. The indenture governing the TRGP Notes restricts (i) our ability and the ability of our subsidiaries to incur liens and (ii) TRGP’s ability to merge or consolidate with or sell, lease, convey, transfer or otherwise dispose of all or substantially all of its assets to another company. These covenants are subject to a number of important exceptions and qualifications. We may redeem the TRGP Notes, in whole or in part, at any time prior to the applicable par call date at a redemption price equal to the principal amount plus an applicable make-whole premium, plus accrued and unpaid interest, to the redemption date, as specified in the indenture of each series. After the applicable par call date, the TRGP Notes may be redeemed at a price equal to par, plus accrued and unpaid interest to the redemption date, as specified in the indenture of each series. In the future, we may redeem, purchase or exchange certain of our outstanding debt through redemption calls, cash purchases and/or exchanges for other debt, in open market purchases, privately negotiated transactions or otherwise. Such calls, repurchases or exchanges, if any, will depend on prevailing market conditions, our liquidity requirements, contractual restrictions and other factors. The amounts involved may be material. Partnership’s Senior Unsecured Notes All issues of the Partnership’s senior unsecured notes are pari passu with the Partnership’s existing and future senior indebtedness. They are senior in right of payment to any of the Partnership’s future subordinated indebtedness and are unconditionally guaranteed by the Partnership’s restricted subsidiaries. These notes are effectively subordinated to all secured indebtedness under the Securitization Facility, which is secured by accounts receivable pledged under the facility, to the extent of the value of the collateral securing that indebtedness. Interest on all issues of senior unsecured notes is payable semi-annually in arrears. The Partnership’s senior unsecured notes and associated indenture agreements restrict, among other things, (i) the Partnership’s ability and the ability of certain of its subsidiaries to incur liens and (ii) the Partnership’s ability to merge or consolidate with or sell, lease, convey, transfer or otherwise dispose of all or substantially all of its assets to another company. These covenants are subject to a number of important exceptions and qualifications. The Partnership may redeem its senior unsecured notes, in whole or in part, at any time prior to their applicable maturity at a redemption price equal to the principal amount plus an applicable make-whole premium, plus accrued and unpaid interest and liquidation damages, if any, to the redemption date, as specified in the indenture of each series. The Partnership may also redeem up to 35 % of the aggregate principal amount of each series of its senior unsecured notes at the redemption dates and prices set forth in the indenture governing such series plus accrued and unpaid interest and liquidation damages, if any, to the redemption date with the net cash proceeds of one or more equity offerings, provided that: (i) at least 65 % of the aggregate principal amount of each such notes (excluding notes held by the Partnership and its subsidiaries) remains outstanding immediately after the occurrence of such redemption; and (ii) the redemption occurs within 180 days of the date of the closing of such equity offering. In the future, we or the Partnership may redeem, purchase or exchange certain of our and the Partnership’s outstanding debt through redemption calls, cash purchases and/or exchanges for other debt, in open market purchases, privately negotiated transactions or otherwise. Such calls, repurchases or exchanges, if any, will depend on prevailing market conditions, our liquidity requirements, contractual restrictions and other factors. The amounts involved may be material. Senior Unsecured Notes Issuances In February 2021, the Partnership issued $ 1.0 billion aggregate principal amount of 4.000 % Senior Notes due 2032 (the “February 2021 Offering”), resulting in net proceeds of approximately $ 991 million. The 4.000 % Senior Notes due 2032 have substantially similar terms and covenants as the Partnership’s other series of senior notes. A portion of the net proceeds from the issuance was used to fund the concurrent cash tender offer (the “February Tender Offer”) and subsequent redemption for the Partnership’s 5.125 % Senior Notes due 2025 (the “5.125% Notes”), with the remainder used for repayment of borrowings under the Partnership's senior secured revolving credit facility (the “Partnership Revolver”) and our previous TRGP senior secured revolving credit facility (the “Previous TRGP Revolver”). See “Debt Repurchases and Extinguishments” for further details of the February Tender Offer. In April 2022, we completed an underwritten public offering of (i) $ 750.0 million aggregate principal amount of our 4.200 % Senior Notes due 2033 (the “ 4.200 % Notes”) and (ii) $ 750.0 million aggregate principal amount of our 4.950 % Senior Notes due 2052 (the “ 4.950 % Notes”), resulting in net proceeds of approximately $ 1.5 billion. The 4.200 % Notes and the 4.950 % Notes are fully and unconditionally guaranteed, jointly and severally, on a senior unsecured basis by our subsidiaries that guarantee the TRGP Revolver, so long as such subsidiary guarantors satisfy certain conditions. The 4.200 % Notes and the 4.950 % Notes were issued pursuant to the Indenture, dated as of April 6, 2022, as supplemented by that certain First Supplemental Indenture, dated as of April 6, 2022, among us, such subsidiary guarantors and U.S. Bank Trust Company, National Association, as trustee. A portion of the net proceeds from the issuance was used to fund the concurrent cash tender offer (the “March Tender Offer”) and the subsequent redemption of the Partnership’s 5.875 % Senior Notes due April 2026 (the “ 5.875 % Notes”), with the remainder of the net proceeds used for repayment of the outstanding borrowings under the TRGP Revolver. See “Debt Repurchases and Extinguishments” for further details of the March Tender Offer. In July 2022, we completed an underwritten public offering of the 5.200 % Notes and the 6.250 % Notes, resulting in net proceeds of approximately $ 1.2 billion. The 5.200 % Notes and the 6.250 % Notes are fully and unconditionally guaranteed, jointly and severally, on a senior unsecured basis by our subsidiaries that guarantee the TRGP Revolver, so long as such subsidiary guarantors satisfy certain conditions. The 5.200 % Notes and the 6.250 % Notes were issued pursuant to the Indenture, dated as of April 6, 2022, as supplemented by that certain Third Supplemental Indenture, dated as of July 7, 2022, among us, such subsidiary guarantors and U.S. Bank Trust Company, National Association, as trustee. We used the net proceeds from the issuance to fund a portion of the Delaware Basin Acquisition. In January 2023, we completed an underwritten public offering of (i) $ 900.0 million aggregate principal amount of our 6.125 % Senior Notes due 2033 (the “ 6.125 % Notes”) and (ii) $ 850.0 million aggregate principal amount of our 6.500 % Senior Notes due 2053 (the “January 2023 6.500 % Notes”), resulting in net proceeds of approximately $ 1.7 billion. The 6.125 % Notes and the January 2023 6.500 % Notes are fully and unconditionally guaranteed, jointly and severally, on a senior unsecured basis by our subsidiaries that guarantee the TRGP Revolver, so long as such subsidiary guarantors satisfy certain conditions. The 6.125 % Notes and the January 2023 6.500% Notes were issued pursuant to the Indenture, dated as of April 6, 2022, as supplemented by that certain Fifth Supplemental Indenture, dated as of January 9, 2023, among us, such subsidiary guarantors and U.S. Bank Trust Company, National Association, as trustee. We used a portion of the net proceeds from the issuance to fund the Grand Prix Transaction and the remaining proceeds for general corporate purposes, including to reduce borrowings under the TRGP Revolver and the Commercial Paper Program. In November 2023, we completed an underwritten public offering of (i) $ 1.0 billion aggregate principal amount of our 6.150 % Senior Notes due 2029 (the “2023 6.150 % Notes”) and (ii) $ 1.0 billion aggregate principal amount of our 6.500 % Senior Notes due 2034 (the “November 2023 6.500 % Notes”), resulting in net proceeds of approximately $ 2.0 billion. The 2023 6.150 % Notes and the November 2023 6.500 % Notes are fully and unconditionally guaranteed, jointly and severally, on a senior unsecured basis by our subsidiaries that guarantee the TRGP Revolver, so long as such subsidiary guarantors satisfy certain conditions. The 2023 6.150 % Notes and the November 2023 6.500 % Notes were issued pursuant to the Indenture, dated as of April 6, 2022, as supplemented by that certain Seventh Supplemental Indenture, dated as of November 9, 2023, among us, such subsidiary guarantors and U.S. Bank Trust Company, National Association, as trustee. We used a portion of the net proceeds to repay $ 1.0 billion in borrowings under the Term Loan Facility and the remaining net proceeds for general corporate purposes, including to repay borrowings under the Commercial Paper Program. Debt Repurchases & Extinguishments Concurrent with the February 2021 Offering, the Partnership commenced the February Tender Offer to redeem subject to certain terms and conditions, any and all of our outstanding 5.125 % Notes. As a result of the February Tender Offer and the subsequent redemption of the 5.125% Notes, we recorded a loss due to debt extinguishment of $ 14.9 million comprised of $ 12.5 million of premiums paid and a write-off of $ 2.4 million of debt issuance costs. Additionally, Targa Pipeline Partners LP (the “TPL”) redeemed all of the outstanding TPL 4.750 % Senior Notes due 2021 and TPL 5.875 % Senior Notes due 2023 (collectively, the “TPL Notes”) in February 2021 with available liquidity under the Partnership Revolver. As a result of the redemptions of the TPL Notes, we recorded a gain due to debt extinguishment of $ 0.2 million. The Partnership redeemed all of the outstanding 4.250 % Senior Notes due 2023 (the “4.250% Senior Notes”) in May 2021 with available liquidity under the Partnership Revolver. As a result of the redemption of the 4.250% Senior Notes, we recorded a loss due to debt extinguishment of $ 1.9 million. In February 2022, in connection with entering into the TRGP Revolver, we terminated the Previous TRGP Revolver and Partnership Revolver. As a result of the termination of the Previous TRGP Revolver and the Partnership Revolver, we recorded a loss of $ 0.8 million due to a write-off of debt issuance costs. The Partnership redeemed all of the outstanding 5.375 % Senior Notes due 2027 (the “5.375% Notes”) in March 2022 with available liquidity under the TRGP Revolver. As a result of the redemption of the 5.375% Notes, we recorded a loss due to debt extinguishment of $ 15.0 million comprised of $ 12.6 million of premiums paid and a write-off of $ 2.4 million of debt issuance costs. Concurrent with the 4.200 % Notes and the 4.950 % Notes offering, we commenced the March Tender Offer to redeem subject to certain terms and conditions, any and all of the Partnership’s outstanding 5.875 % Notes. As a result of the March Tender Offer and the subsequent redemption of the 5.875% Notes, we recorded a loss due to debt extinguishment of $ 33.8 million comprised of $ 29.3 million of premiums paid and a write-off of $ 4.5 million of debt issuance costs. In November 2023, in connection with the 2023 6.150 % Notes and November 2023 6.500 % Notes, we repaid borrowings under the Term Loan Facility and the Commercial Paper Program. As a result of the repayment of borrowings under the Term Loan Facility, we recorded a loss of $ 2.1 million due to a write-off of debt issuance costs. The following table shows the contractually scheduled maturities of our debt obligations outstanding at December 31, 2023, for the next five years, and in total thereafter: Scheduled Maturities of Debt Total 2024 2025 2026 2027 2028 Thereafter TRGP Revolver and Commercial Paper Program $ 175.0 $ — $ — $ — $ 175.0 $ — $ — TRGP Senior unsecured notes 6,500.0 — — — 750.0 — 5,750.0 Term Loan Facility 500.0 — 500.0 — — — — Partnership’s Senior unsecured notes 5,034.4 — — — 705.2 700.3 3,628.9 Securitization Facility 575.0 575.0 — — — — — Total $ 12,784.4 $ 575.0 $ 500.0 $ — $ 1,630.2 $ 700.3 $ 9,378.9

Other Long-term Liabilities

Other Long-term Liabilities	12 Months Ended
	Dec. 31, 2023
Other Liabilities, Noncurrent [Abstract]
Other Long-term Liabilities	Note 9 — Other Long-term Liabilities Other long-term liabilities are comprised of the following obligations: December 31, 2023 December 31, 2022 Deferred revenue $ 248.8 $ 198.8 Asset retirement obligations 103.0 97.9 Operating lease liabilities 56.5 28.6 Other liabilities 6.8 15.9 Total other long-term liabilities $ 415.1 $ 341.2 Deferred Revenue Deferred revenue as of December 31, 2023 and 2022 was $ 248.8 million and $ 198.8 million, respectively, which includes $ 129.0 million of payments received from Vitol Americas Corp. (“Vitol”) (formerly known as Noble Americas Corp.), a subsidiary of Vitol US Holding Co., in 2016, 2017, and 2018 as part of an agreement (the “Splitter Agreement”) related to the construction and operation of a crude oil and condensate splitter. In December 2018, Vitol elected to terminate the Splitter Agreement. The Splitter Agreement provides that the first three annual payments are ours if Vitol elects to terminate, which Vitol disputes. The timing of revenue recognition related to the Splitter Agreement deferred revenue is dependent on the outcome of current litigation with Vitol. See Note 18 - Contingencies for more information. Deferred revenue includes nonmonetary consideration received in a 2015 amendment (the “gas contract amendment”) to a gas gathering and processing agreement. We measured the estimated fair value of the gathering assets transferred to us using significant other observable inputs representative of a Level 2 fair value measurement. In December 2017, we received monetary consideration to further amend the terms of the gas gathering and processing agreement. The deferred revenue related to these amendments is being recognized through the end of the agreement’s term in 2035. Deferred revenue also includes contributions in aid of construction received from customers for which revenue is recognized over the expected contract term. For the years ended December 31, 2023, 2022 and 2021, we recognized $ 17.4 million, $ 7.5 million and $ 3.9 million of revenue for these transactions, respectively. The following table shows the components of deferred revenue: December 31, 2023 December 31, 2022 Splitter agreement $ 129.0 $ 129.0 Gas contract amendment 29.8 32.3 Contributions in aid of construction (1) 86.4 31.7 Other 3.6 5.8 Total deferred revenue $ 248.8 $ 198.8 (1) Increase in contributions in aid of construction was due to additions of deferred revenue in West Texas and Badlands. The following table shows the changes in deferred revenue: 2023 2022 Balance at beginning of period $ 198.8 $ 171.8 Additions 67.4 34.5 Revenue recognized ( 17.4 ) ( 7.5 ) Balance at end of period $ 248.8 $ 198.8 Asset Retirement Obligations Our ARO primarily relate to certain gas gathering pipelines and processing facilities and NGL pipelines. The changes in our ARO are as follows: 2023 2022 Beginning of period $ 97.9 $ 72.1 Additions (1) — 20.2 Accretion expense 5.9 4.8 Change in cash flow estimate 4.9 0.8 Retirements ( 5.7 ) — End of period $ 103.0 $ 97.9 (1) Amount reflects additions of ARO in 2022 related to the Delaware Basin Acquisition.

Leases

Leases	12 Months Ended
	Dec. 31, 2023
Leases [Abstract]
Leases	Note 10 – L eases We have non-cancellable operating leases primarily associated with our office facilities, compressors, rail assets, land, storage and terminal assets. We have finance leases primarily associated with our substations, compressors, tractors and vehicles. Our leases have remaining lease terms of 1 to 9 years, some of which include options to extend the lease term for up to 20 years. The balances of right-of-use assets and liabilities of finance leases and operating leases, and their locations on our Consolidated Balance Sheets are as follows: December 31, Balance Sheet Location 2023 2022 Right-of-use assets Operating leases, gross Other long-term assets $ 101.1 $ 57.3 Finance leases, gross (1) Property, plant and equipment 351.9 266.1 Lease liabilities Current: Operating leases Accrued liabilities $ 21.8 $ 14.4 Finance leases (1) Current debt obligations 45.7 34.3 Non-current: Operating leases Other long-term liabilities $ 56.5 $ 28.6 Finance leases (1) Long-term debt 244.1 193.0 (1) The December 31, 2022 balance includes $ 171.2 million of assets and $ 167.0 million of liabilities related to compressor leases from the Delaware Basin Acquisition that were subsequently amended and extended. Operating lease costs and short-term lease costs are included in Operating expenses or General and administrative expense in our Consolidated Statements of Operations, depending on the nature of the leases. Finance lease costs are included in Depreciation and amortization expense and Interest expense, net in our Consolidated Statements of Operations. The components of lease expense were as follows: Year Ended December 31, 2023 2022 2021 Lease cost Operating lease cost $ 18.3 $ 17.7 $ 12.2 Short-term lease cost 56.7 35.0 20.4 Variable lease cost 26.0 17.9 5.7 Finance lease cost Amortization of right-of-use assets 48.2 20.3 13.3 Interest expense 14.0 3.5 1.1 Total lease cost $ 163.2 $ 94.4 $ 52.7 Other supplemental information related to our leases are as follows: Year Ended December 31, 2023 2022 2021 Cash paid for amounts included in the measurement of lease liabilities Operating cash flows for operating leases $ 21.4 $ 18.8 $ 14.1 Operating cash flows for finance leases 13.9 2.7 1.0 Financing cash flows for finance leases 42.9 19.7 12.5 The weighted-average remaining lease terms for operating leases and finance leases are 5 years and 6 years , respectively. The weighted-average discount rates for operating leases and finance leases are 5.0 % and 5.0 % , respectively. The following table presents the maturities of our lease liabilities under non-cancellable leases as of December 31, 2023: Operating Leases Finance Leases 2024 $ 25.5 $ 57.5 2025 16.8 56.5 2026 11.2 55.0 2027 10.3 48.9 2028 10.1 41.4 Thereafter 14.4 72.8 Total undiscounted cash flows 88.3 332.1 Less imputed interest ( 10.0 ) ( 42.3 ) Total lease liabilities $ 78.3 $ 289.8

Preferred Stock

Preferred Stock	12 Months Ended
	Dec. 31, 2023
Equity [Abstract]
Preferred Stock	Note 11 – P referred Stock Preferred Stock Prior to the redemption in May 2022, our Series A Preferred had a liquidation value of $ 1,000 per share and bore a cumulative 9.5 % fixed dividend payable quarterly 45 days after the end of each fiscal quarter . The Series A Preferred had no mandatory redemption date, but was redeemable at our election on or prior to March 16, 2022 for a 10 % premium to the liquidation preference and for a 5 % premium to the liquidation preference thereafter. The Series A Preferred ranked senior to the common outstanding stock with respect to the payment of dividends and distributions in liquidation. The holders of Series A Preferred generally only had voting rights in certain circumstances, subject to certain exceptions, which included: • the issuance or the increase by the Company of any specific class or series of stock that was senior to the Series A Preferred, • the issuance or the increase by any of the Company’s consolidated subsidiaries of any specific class or series of securities, • changes to the Certificates of Incorporation or Designations of the Series A Preferred that would have materially and adversely affected the Preferred Stock holder, • the issuance of stock on parity with the Series A Preferred, subject to certain exceptions, if the Company had exceeded a stipulated fixed charge coverage ratio or an aggregate amount of net proceeds from all future issuances of Parity Stock, or would have used the proceeds of such issuance to pay dividends, • the incurrence of indebtedness, other than indebtedness that complies with a stipulated fixed charge coverage ratio or under the TRGP Revolver (or replacement commercial bank facilities) in an aggregate amount up to $ 2.75 billion. The Series A Preferred did not qualify as a liability instrument because it was not mandatorily redeemable. However, as SEC Regulation S-X, Rule 5-02-27 does not permit a probability assessment for a change of control provision, our Series A Preferred must be presented as mezzanine equity between liabilities and shareholders’ equity on our Consolidated Balance Sheets because a change of control event, although not considered probable, could have forced the Company to redeem the Series A Preferred. A maximum of 44,260,953 common shares would have been issued upon conversion of the Series A Preferred. Preferred Stock Redemption In May 2022, we redeemed all of our issued and outstanding shares of Series A Preferred at a redemption price of $ 1,050.00 per share, plus $ 8.87 per share, which is the amount of accrued and unpaid dividends from April 1, 2022 up to, but not including, the redemption date of May 3, 2022 . The difference between the consideration paid of $ 973.4 million (including unpaid dividends of $ 8.2 million) and the net carrying value of the shares redeemed was $ 223.7 million, of which $ 215.5 million was recorded as deemed dividends in our Consolidated Statements of Operations in the second quarter of 2022. Following the redemption, we have no Series A Preferred outstanding and all rights of the holders of shares of Series A Preferred were terminated. Preferred Stock Dividends During the year ended December 31, 2022, we paid $ 51.8 million of dividends to Series A Preferred Shareholders. During the year ended December 31, 2021 we paid $ 87.3 million of dividends at a rate of $ 23.75 per share each quarter to Series A Preferred shareholders attributable to accretion of the preferred discount resulting from the beneficial conversion feature accounting model. Such accretion was included in the book value of the Series A Preferred. After adoption of ASU 2020-06, Debt - Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging - Contracts in Entity’s Own Equity (Subtopic 815-40): Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity in 2021, we no longer recognize such accretion.

Common Stock and Related Matter

Common Stock and Related Matters	12 Months Ended
	Dec. 31, 2023
Class of Stock Disclosures [Abstract]
Common Stock and Related Matters	Note 12 — C ommon Stock and Related Matters Public Offerings of Common Stock On May 9, 2017, we entered into an equity distribution agreement under the May 2016 Shelf (the “May 2017 EDA”), pursuant to which we may sell through our sales agents, at our option, up to an aggregated amount of $ 750.0 million of our common stock (“2017 ATM Program”). On September 20, 2018, we entered into an equity distribution agreement under the May 2016 Shelf (the “September 2018 EDA”), pursuant to which we may sell through our sales agents, at our option, up to an aggregated amount of $ 750.0 million of our common stock (“2018 ATM Program”). In March 2022, we filed with the SEC a universal shelf registration statement on Form S-3 that registers the issuance and sale of certain debt and equity securities from time to time in one or more offerings (the “March 2022 Shelf”). The March 2022 Shelf will expire in March 2025. During 2023, 2022 and 2021, no shares of common stock were issued under either the May 2017 EDA or the September 2018 EDA. As a result, we have $ 382.1 million and $ 750.0 million remaining under the May 2017 EDA and September 2018 EDA, respectively, as of December 31, 2023. Common Share Repurchase Program In October 2020, our Board of Directors approved a share repurchase program (the “2020 Share Repurchase Program”) for the repurchase of up to $ 500.0 million of our outstanding common stock. In May 2023, our Board of Directors approved a new share repurchase program (the “2023 Share Repurchase Program”) for the repurchase of up to $ 1.0 billion of our outstanding common stock. During the second quarter of 2023, we exhausted the 2020 Share Repurchase Program. As of December 31, 2023, there was $ 770.1 million remaining under the 2023 Share Repurchase Program. We are not obligated to repurchase any specific dollar amount or number of shares under the 2023 Share Repurchase Program and may discontinue the program at any time. For the year ended December 31, 2023, we repurchased 4,870,559 shares of our common stock at a weighted average price per share of $ 76.72 for a total net cost of $ 373.7 million. For the year ended December 31, 2022, we repurchased 3,412,354 shares of our common stock at a weighted average price per share of $ 65.87 for a total net cost of $ 224.8 million. For the year ended December 31, 2021, we repurchased 756,478 shares of our common stock at a weighted average price per share of $ 52.81 for a total net cost of $ 40.0 million. Common Stock Dividends In April 2023, we declared an increase to our common dividend to $ 0.50 per common share or $ 2.00 per common share annualized effective for the first quarter of 2023. The following table details the dividends declared and/or paid by us to common shareholders for the years ended December 31, 2023, 2022 and 2021: Three Months Ended Date Paid or Total Common Amount of Common Dividends on Dividends Declared per Share of Common Stock (In millions, except per share amounts) 2023 December 31, 2023 February 15, 2024 $ 112.8 $ 111.6 $ 1.2 $ 0.50000 September 30, 2023 November 15, 2023 113.0 111.5 1.5 0.50000 June 30, 2023 August 15, 2023 113.6 111.8 1.8 0.50000 March 31, 2023 May 15, 2023 114.7 113.0 1.7 0.50000 2022 December 31, 2022 February 15, 2023 $ 80.5 $ 79.3 $ 1.2 $ 0.35000 September 30, 2022 November 15, 2022 80.5 79.2 1.3 0.35000 June 30, 2022 August 15, 2022 80.7 79.3 1.4 0.35000 March 31, 2022 May 16, 2022 81.2 79.8 1.4 0.35000 2021 December 31, 2021 February 15, 2022 $ 81.4 $ 80.1 $ 1.3 $ 0.35000 September 30, 2021 November 15, 2021 23.3 22.9 0.4 0.10000 June 30, 2021 August 16, 2021 23.3 22.9 0.4 0.10000 March 31, 2021 May 14, 2021 23.3 22.9 0.4 0.10000

Earnings per Common Share

Earnings per Common Share	12 Months Ended
	Dec. 31, 2023
Earnings Per Share [Abstract]
Earnings per Common Share	Note 13 — Ea rnings per Common Share In March 2023, the Compensation Committee amended the Restricted Stock Units Grant Agreements that govern the Restricted Stock Unit awards (“RSUs”) that vest no later than three years following the RSUs’ grant date. The amendment resulted in quarterly cash dividend payments to RSU holders beginning with the common stock dividend paid in May 2023. As the amended RSUs and certain four-year retention awards participate in nonforfeitable dividends with the common equity owners of the Company, they are considered participating securities. We calculate earnings per share using the two-class method. Earnings are allocated to common stock and participating securities based on the amount of dividends paid in the current period plus an allocation of the undistributed earnings to the extent that each security participates in earnings. The following table sets forth a reconciliation of net income and weighted average shares outstanding used in computing basic and diluted net income per common share: Year Ended December 31, 2023 2022 2021 (In millions, except per share amounts) Net income (loss) attributable to Targa Resources Corp. $ 1,345.9 $ 1,195.5 $ 71.2 Less: Premium on repurchase of noncontrolling interests, net of tax (1) 510.1 53.2 — Less: Dividends on Series A Preferred Stock (2) — 30.0 87.3 Less: Deemed dividends on Series A Preferred (3) — 215.5 — Net income (loss) attributable to common shareholders 835.8 896.8 ( 16.1 ) Less: Participating share-based earnings (4) 7.6 — — Net income (loss) allocated to common shareholders for basic earnings per share $ 828.2 $ 896.8 $ ( 16.1 ) Weighted average shares outstanding - basic 224.6 227.3 228.6 Dilutive effect of unvested stock awards (5) 1.4 3.8 — Weighted average shares outstanding - diluted 226.0 231.1 228.6 Net income (loss) available per common share - basic $ 3.69 $ 3.95 $ ( 0.07 ) Net income (loss) available per common share - diluted $ 3.66 $ 3.88 $ ( 0.07 ) (1) Represents premium paid on the Grand Prix Transaction, Carnero Acquisition and the DevCo JV Repurchase. See Note 4 – Acquisitions and Divestitures . (2) Includes $ 8.2 million attributable to the dividends paid upon the full redemption of Series A Preferred in 2022. (3) Includes $ 215.5 million attributable to the full redemption of Series A Preferred in 2022. See Note 11 – Preferred Stock for further discussion. (4) Represents the distributed and undistributed earnings of the Company attributable to the participating securities. The dilutive effect of the reallocation of participating securities to diluted net income attributable to common shareholders was immaterial. (5) For the year ended December 31, 2021, all unvested restricted stock awards and Series A Preferred were antidilutive because a net loss existed in the period. The following potential common stock equivalents are excluded from the determination of diluted earnings per share because the inclusion of such shares would have been anti-dilutive (in millions on a weighted-average basis): Year Ended December 31, 2023 2022 2021 Unvested restricted stock awards 1.5 — 3.3 Series A Preferred (1) — 14.9 44.3 (1) The Series A Preferred had no mandatory redemption date, but was redeemable at our election for a 5 % premium to the liquidation preference subsequent to March 16, 2022 . In May 2022, we redeemed all of our issued and outstanding Series A Preferred at a redemption price of $ 1,050.00 per share, plus $ 8.87 per share, which is the amount of accrued and unpaid dividends from April 1, 2022 up to, but not including, the redemption date of May 3, 2022 . See Note 11 – Preferred Stock for further discussion.

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	12 Months Ended
	Dec. 31, 2023
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	Not e 14 — Derivative Instruments and Hedging Activities The primary purpose of our commodity risk management activities is to manage our exposure to commodity price risk and reduce volatility in our operating cash flow due to fluctuations in commodity prices. We have entered into derivative instruments to hedge the commodity price risks associated with a portion of our expected (i) natural gas, NGL, and condensate equity volumes in our Gathering and Processing operations that result from percent-of-proceeds processing arrangements, (ii) future commodity purchases and sales in our Logistics and Transportation segment and (iii) natural gas transportation basis risk in our Logistics and Transportation segment. The hedge positions associated with (i) and (ii) above will move favorably in periods of falling commodity prices and unfavorably in periods of rising commodity prices and are primarily designated as cash flow hedges for accounting purposes. The hedges generally match the NGL product composition and the NGL delivery points of our physical equity volumes. Our natural gas hedges are a mixture of specific gas delivery points and Henry Hub. The NGL hedges may be transacted as specific NGL hedges or as baskets of ethane, propane, normal butane, isobutane and natural gasoline based upon our expected equity NGL composition. We believe this approach avoids uncorrelated risks resulting from employing hedges on crude oil or other petroleum products as “proxy” hedges of NGL prices. Our natural gas and NGL hedges are settled using published index prices for delivery at various locations. We hedge a portion of our condensate equity volumes using crude oil hedges that are based on the NYMEX futures contracts for West Texas Intermediate light, sweet crude, which approximates the prices received for condensate. This exposes us to a market differential risk if the NYMEX futures do not move in exact parity with the sales price of our underlying condensate equity volumes. We also enter into derivative instruments to help manage other short-term commodity-related business risks and take advantage of market opportunities. We have not designated these derivatives as hedges and record changes in fair value and cash settlements to revenues as current income. At December 31, 2023, the notional volumes of our commodity derivative contracts were: Commodity Instrument Unit 2024 2025 2026 2027 Natural Gas Swaps MMBtu/d 107,242 58,179 14,297 — Natural Gas Basis Swaps MMBtu/d 478,374 256,658 122,500 35,000 NGL Swaps Bbl/d 31,893 21,354 5,589 — NGL Futures Bbl/d 14,511 4,767 — — Condensate Swaps Bbl/d 4,531 3,447 1,092 — Our derivative contracts are subject to netting arrangements that permit our contracting subsidiaries to net cash settle offsetting asset and liability positions with the same counterparty within the same Targa entity. The master netting provisions reduced our maximum loss due to counterparty credit risk by $ 32.2 million as of December 31, 2023. The range of losses attributable to our individual counterparties would be between $ 0.2 million and $ 21.6 million, depending on the counterparty in default. We record derivative assets and liabilities on our Consolidated Balance Sheets on a gross basis, without considering the effect of master netting arrangements. The following schedules reflect the fair value of our derivative instruments and their location on our Consolidated Balance Sheets as well as pro forma reporting assuming that we reported derivatives subject to master netting agreements on a net basis: Fair Value as of December 31, 2023 Fair Value as of December 31, 2022 Balance Sheet Derivative Derivative Derivative Derivative Location Assets Liabilities Assets Liabilities Derivatives designated as hedging instruments Commodity contracts Current $ 103.5 $ ( 16.4 ) $ 158.7 $ ( 93.8 ) Long-term 29.0 ( 3.0 ) 24.2 ( 30.9 ) Total derivatives designated as hedging instruments $ 132.5 $ ( 19.4 ) $ 182.9 $ ( 124.7 ) Derivatives not designated as hedging instruments Commodity contracts Current $ 8.4 $ ( 37.6 ) $ 21.2 $ ( 226.3 ) Long-term 4.3 ( 13.8 ) 0.3 ( 109.2 ) Total derivatives not designated as hedging instruments $ 12.7 $ ( 51.4 ) $ 21.5 $ ( 335.5 ) Total current position $ 111.9 $ ( 54.0 ) $ 179.9 $ ( 320.1 ) Total long-term position 33.3 ( 16.8 ) 24.5 ( 140.1 ) Total derivatives $ 145.2 $ ( 70.8 ) $ 204.4 $ ( 460.2 ) The pro forma impact of reporting derivatives on our Consolidated Balance Sheets on a net basis is as follows: Gross Presentation Pro Forma Net Presentation December 31, 2023 Asset Liability Collateral Asset Liability Current Position Counterparties with offsetting positions or collateral $ 111.7 $ ( 54.0 ) $ 3.6 $ 69.2 $ ( 7.9 ) Counterparties without offsetting positions - assets 0.2 — — 0.2 — Counterparties without offsetting positions - liabilities — — — — — 111.9 ( 54.0 ) 3.6 69.4 ( 7.9 ) Long-Term Position Counterparties with offsetting positions or collateral 31.7 ( 16.8 ) ( 0.1 ) 17.0 ( 2.2 ) Counterparties without offsetting positions - assets 1.6 — — 1.6 — Counterparties without offsetting positions - liabilities — — — — — 33.3 ( 16.8 ) ( 0.1 ) 18.6 ( 2.2 ) Total Derivatives Counterparties with offsetting positions or collateral 143.4 ( 70.8 ) 3.5 86.2 ( 10.1 ) Counterparties without offsetting positions - assets 1.8 — — 1.8 — Counterparties without offsetting positions - liabilities — — — — — $ 145.2 $ ( 70.8 ) $ 3.5 $ 88.0 $ ( 10.1 ) Gross Presentation Pro Forma Net Presentation December 31, 2022 Asset Liability Collateral Asset Liability Current Position Counterparties with offsetting positions or collateral $ 162.2 $ ( 316.7 ) $ 12.2 $ 27.2 $ ( 169.5 ) Counterparties without offsetting positions - assets 17.7 — — 17.7 — Counterparties without offsetting positions - liabilities — ( 3.4 ) — — ( 3.4 ) 179.9 ( 320.1 ) 12.2 44.9 ( 172.9 ) Long-Term Position Counterparties with offsetting positions or collateral 24.5 ( 137.4 ) 22.4 7.3 ( 97.8 ) Counterparties without offsetting positions - assets — — — — — Counterparties without offsetting positions - liabilities — ( 2.7 ) — — ( 2.7 ) 24.5 ( 140.1 ) 22.4 7.3 ( 100.5 ) Total Derivatives Counterparties with offsetting positions or collateral 186.7 ( 454.1 ) 34.6 34.5 ( 267.3 ) Counterparties without offsetting positions - assets 17.7 — — 17.7 — Counterparties without offsetting positions - liabilities — ( 6.1 ) — — ( 6.1 ) $ 204.4 $ ( 460.2 ) $ 34.6 $ 52.2 $ ( 273.4 ) Some of our hedges are futures contracts executed through brokers that clear the hedges through an exchange. We maintain a margin deposit with the brokers in an amount sufficient to cover the fair value of our open futures positions. The margin deposit is considered collateral, which is located within Other current assets on our Consolidated Balance Sheets and is not offset against the fair value of our derivative instruments. Our derivative instruments other than our futures contracts are executed under International Swaps and Derivatives Association agreements (“ISDAs”), which govern the key terms with our counterparties. Our ISDAs contain credit-risk related contingent features. Following the release of the collateral securing our TRGP Revolver, our derivative positions are no longer secured. As of December 31, 2023, we have outstanding net derivative positions that contain credit-risk related contingent features that are in a net liability position of $ 9.9 million. We have not been required to post any collateral related to these positions due to our credit rating. If our credit rating was to be downgraded one notch below investment grade by both Moody’s and S&P, as defined in our ISDAs, we estimate that as of December 31, 2023 , we would no t be required to post collateral to any counterparties per the terms of our ISDAs. The fair value of our derivative instruments, depending on the type of instrument, was determined by the use of present value methods or standard option valuation models with assumptions about commodity prices based on those observed in underlying markets. The estimated fair value of our derivative instruments was a net asset of $ 74.4 million as of December 31, 2023. The estimated fair value is net of an adjustment for credit risk based on the default probabilities as indicated by market quotes for the counterparties’ credit default swap rates. The credit risk adjustment was immaterial for all periods presented. Our futures contracts that are cleared through an exchange are margined daily and do not require any credit adjustment. The following tables reflect amounts recorded in OCI and amounts reclassified from OCI to revenue for the periods indicated: Derivatives in Cash Flow Gain (Loss) Recognized in OCI on Derivatives (Effective Portion) Hedging Relationships 2023 2022 2021 Commodity contracts $ 193.4 $ ( 5.6 ) $ ( 534.6 ) Gain (Loss) Reclassified from OCI into Income (Effective Portion) Location of Gain (Loss) 2023 2022 2021 Revenues $ 153.4 $ ( 373.0 ) $ ( 417.3 ) Based on valuations as of December 31, 2023, we expect to reclassify commodity hedge related deferred gains of $ 103.4 million included in accumulated other comprehensive income (loss) into earnings before income taxes through the end of 2026, with $ 77.5 million of gains to be reclassified over the next twelve months. Our consolidated earnings are also affected by the use of the mark-to-market method of accounting for derivative instruments that do not qualify for hedge accounting or that have not been designated as hedges. The changes in fair value of these instruments are recorded on the balance sheet and through earnings rather than being deferred until the anticipated transaction settles. The use of mark-to-market accounting for financial assets and liabilities (“financial instruments”) can cause non-cash earnings volatility due to changes in the underlying commodity price indices. For the year ended December 31, 2023, the unrealized mark-to-market gains are primarily attributable to favorable movements in natural gas forward basis prices, as compared to our positions. Derivatives Not Designated Location of Gain (Loss) Recognized in Gain (Loss) Recognized in Income on Derivatives as Hedging Instruments Income on Derivatives 2023 2022 2021 Commodity contracts Revenue $ 287.7 $ ( 381.7 ) $ ( 73.3 ) See Item 7A. Quantitative and Qualitative Disclosures About Market Risk, Note 15 – Fair Value Measurements and Note 23 – Segment Information for additional disclosures related to derivative instruments and hedging activities.

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2023
Fair Value Disclosures [Abstract]
Fair Value Measurements	Note 15 — Fair Value Measurements Under GAAP, our Consolidated Balance Sheets reflect a mixture of measurement methods for financial assets and liabilities (“financial instruments”). Derivative financial instruments are reported at fair value on our Consolidated Balance Sheets. Other financial instruments are reported at historical cost or amortized cost on our Consolidated Balance Sheets. The following are additional qualitative and quantitative disclosures regarding fair value measurements of financial instruments. Fair Value of Derivative Financial Instruments Our derivative instruments consist of financially settled commodity swaps, futures, option contracts and fixed-price forward commodity contracts with certain counterparties. We determine the fair value of our derivative instruments using present value methods or standard option valuation models with assumptions about commodity prices based on those observed in underlying markets. We have consistently applied these valuation techniques in all periods presented and we believe we have obtained the most accurate information available for the types of derivative contracts we hold. The fair values of our derivative instruments are sensitive to changes in forward pricing on natural gas, NGLs and crude oil. The derivatives at December 31, 2023, represent a net asset of $ 74.4 million, and reflects the present value, adjusted for counterparty credit risk, of the amount we expect to receive or pay in the future on our derivative contracts. If forward pricing on natural gas, NGLs and crude oil were to increase by 10%, the result would be a fair value reflecting a net liability of $ 42.8 million. If forward pricing on natural gas, NGLs and crude oil were to decrease by 10%, the result would be a fair value reflecting a net asset of $ 192.0 million. Fair Value of Other Financial Instruments Due to their cash or near-cash nature, the carrying value of other financial instruments included in working capital (i.e., cash and cash equivalents, accounts receivable, accounts payable) approximates their fair value. Long-term debt is primarily the other financial instrument for which carrying value could vary significantly from fair value. We determined the supplemental fair value disclosures for our long-term debt as follows: • the TRGP Revolver, commercial paper notes, Securitization Facility and Term Loan Facility are based on carrying value, which approximates fair value as their interest rates are based on prevailing market rates; and • the TRGP senior unsecured notes and the Partnership’s senior unsecured notes are based on quoted market prices derived from trades of the debt. Fair Value Hierarchy We categorize the inputs to the fair value measurements of financial assets and liabilities at each balance sheet reporting date using a three-tier fair value hierarchy that prioritizes the significant inputs used in measuring fair value: • Level 1 – observable inputs such as quoted prices in active markets; • Level 2 – inputs other than quoted prices in active markets that we can directly or indirectly observe to the extent that the markets are liquid for the relevant settlement periods; and • Level 3 – unobservable inputs in which little or no market data exists, therefore we must develop our own assumptions. The following table shows a breakdown by fair value hierarchy category for (i) financial instruments measurements included on our Consolidated Balance Sheets at fair value and (ii) supplemental fair value disclosures for other financial instruments: December 31, 2023 Carrying Fair Value Value Total Level 1 Level 2 Level 3 Financial Instruments Recorded on Our Assets from commodity derivative contracts (1) $ 144.6 $ 144.6 $ — $ 144.6 $ — Liabilities from commodity derivative contracts (1) 70.2 70.2 — 70.2 Financial Instruments Recorded on Our Cash and cash equivalents 141.7 141.7 — — — TRGP Revolver and Commercial Paper Program 175.0 175.0 — 175.0 — TRGP Senior unsecured notes 6,470.5 6,598.7 — 6,598.7 — Term Loan Facility 500.0 500.0 — 500.0 — Partnership’s Senior unsecured notes 5,034.4 4,945.1 — 4,945.1 — Securitization Facility 575.0 575.0 — 575.0 — December 31, 2022 Carrying Fair Value Value Total Level 1 Level 2 Level 3 Financial Instruments Recorded on Our Assets from commodity derivative contracts (1) $ 201.6 $ 201.6 $ — $ 201.6 $ — Liabilities from commodity derivative contracts (1) 457.4 457.4 — 457.4 — Financial Instruments Recorded on Our Cash and cash equivalents 219.0 219.0 — — — TRGP Revolver and Commercial Paper Program 1,298.7 1,298.7 — 1,298.7 — TRGP Senior unsecured notes 2,741.6 2,452.6 — 2,452.6 — Term Loan Facility 1,500.0 1,500.0 — 1,500.0 — Partnership’s Senior unsecured notes 5,034.4 4,711.3 — 4,711.3 — Securitization Facility 800.0 800.0 — 800.0 — (1) The fair value of derivative contracts in this table is presented on a different basis than the Consolidated Balance Sheets presentation as disclosed in Note 14 – Derivative Instruments and Hedging Activities. The above fair values reflect the total value of each derivative contract taken as a whole, whereas the Consolidated Balance Sheets presentation is based on the individual maturity dates of estimated future settlements. As such, an individual contract could have both an asset and liability position when segregated into its current and long-term portions for Consolidated Balance Sheets classification purposes . Additional Information Regarding Level 3 Fair Value Measurements Included on Our Consolidated Balance Sheets We have historically reported certain of our swaps and option contracts at fair value using Level 3 inputs due to such derivatives not having observable market prices or implied volatilities for substantially the full term of the derivative asset or liability. For valuations that include both observable and unobservable inputs, if the unobservable input was determined to be significant to the overall inputs, the entire valuation was categorized in Level 3. This included derivatives valued using indicative price quotations whose contract length extends into unobservable periods. The fair value of these swaps was determined using a discounted cash flow valuation technique based on a commodity forward curve. For these derivatives, the primary input to the valuation model was the commodity forward curve, which was based on observable or public data sources and extrapolated when observable prices were not available. The significant unobservable inputs used in the fair value measurements of our Level 3 derivatives were the forward natural gas liquids pricing curves, for which a significant portion of the derivative’s term is beyond available forward pricing. As of December 31, 2023 and December 31, 2022 , we had no derivative contracts categorized as Level 3. Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis Nonfinancial assets and liabilities, such as long-lived assets, are measured at fair value on a nonrecurring basis at acquisition or whenever impairment indicators are present. During the year ended December 31, 2021, we recorded a non-cash pre-tax impairment of $ 452.3 million. The impairment charge is primarily associated with the partial impairment of certain gas processing facilities and gathering systems associated with our Central operations in the Gathering and Processing segment. For disclosures related to valuation techniques, see Note 4 – Acquisitions and Divestitures and Note 5 – Property, Plant and Equipment and Intangible Assets. The techniques described above may produce a fair value calculation that may not be indicative or reflective of future fair values. Furthermore, while we believe our valuation techniques are appropriate and consistent with other market participants, the use of different techniques or assumptions to determine fair value of certain financial and nonfinancial assets and liabilities could result in a different fair value measurement at the reporting date.

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2023
Related Party Transactions [Abstract]
Related Party Transactions	Not e 16 — Related Party Transactions Transactions with Unconsolidated Affiliates The following table summarizes transactions with unconsolidated affiliates: GCF T2 Joint Ventures (1) Cayenne GCX (2) Little Missouri 4 Total 2023: Revenues $ — $ — $ — $ — $ 7.1 $ 7.1 Product purchases and fuel — — ( 6.4 ) — — ( 6.4 ) Operating expenses ( 4.4 ) — ( 0.3 ) — ( 2.0 ) ( 6.7 ) General and administrative expenses — — — — ( 0.9 ) ( 0.9 ) 2022: Revenues $ — $ 1.2 $ — $ — $ 8.5 $ 9.7 Product purchases and fuel — — ( 4.7 ) ( 25.0 ) — ( 29.7 ) Operating expenses ( 1.7 ) ( 0.7 ) ( 0.3 ) — ( 2.6 ) ( 5.3 ) General and administrative expenses — — — — ( 0.9 ) ( 0.9 ) 2021: Revenues $ — $ 4.4 $ — $ — $ 10.6 $ 15.0 Product purchases and fuel — — ( 4.8 ) ( 66.5 ) — ( 71.3 ) Operating expenses ( 1.1 ) ( 2.3 ) ( 0.2 ) — ( 2.5 ) ( 6.1 ) General and administrative expenses — — — — ( 0.8 ) ( 0.8 ) (1) Following the closing of the South Texas Acquisition in April 2022, the T2 Joint Ventures are 100 % owned and consolidated by Targa. (2) Following the closing of the GCX Sale in May 2022, Targa no longer has an ownership interest in GCX. Relationship with Targa Resources Partners LP We provide general and administrative and other services to the Partnership, associated with the Partnership’s existing assets and assets acquired from third parties. The Partnership Agreement between the Partnership and us, as general partner of the Partnership, governs the reimbursement of costs incurred on behalf of the Partnership. The employees supporting the Partnership’s operations are our employees. The Partnership reimburses us for the payment of certain operating expenses, including compensation and benefits of operating personnel assigned to the Partnership’s assets, and for the provision of various general and administrative services for the benefit of the Partnership. We perform centralized corporate functions for the Partnership, such as legal, accounting, treasury, insurance, risk management, health, safety and environmental, information technology, human resources, credit, payroll, internal audit, taxes, engineering and marketing.

Commitments

Commitments	12 Months Ended
	Dec. 31, 2023
Leases [Abstract]
Commitments	Note 17 — Commitments Future non-cancelable commitments related to certain contractual obligations are presented below for each of the next five fiscal years and in aggregate thereafter: In Aggregate 2024 2025 2026 2027 2028 Thereafter Land sites and rights of way (1) $ 297.4 $ 8.5 $ 8.6 $ 10.3 $ 11.7 $ 17.3 $ 241.0 (1) Land site lease and rights of way provides for surface and underground access for gathering, processing and distribution assets that are located on property not owned by us. These agreements expire at various dates, with varying terms, some of which are perpetual. Total expenses incurred under the above non-cancelable commitments were: 2023 2022 2021 Land sites and rights of way $ 9.0 $ 5.8 $ 5.9

Contingencies

Contingencies	12 Months Ended
	Dec. 31, 2023
Loss Contingency [Abstract]
Contingencies	Note 18 – Contingencies Legal Proceedings We and the Partnership are parties to various legal, administrative and regulatory proceedings that have arisen in the ordinary course of our business. We and the Partnership are also parties to various proceedings with governmental environmental agencies, including, but not limited to the U.S. Environmental Protection Agency, Texas Commission on Environmental Quality, Oklahoma Department of Environmental Quality, New Mexico Environment Department, Louisiana Department of Environmental Quality and North Dakota Department of Environmental Quality, which assert monetary sanctions for alleged violations of environmental regulations, including air emissions, discharges into the environment and reporting deficiencies, related to events that have arisen at certain of our facilities in the ordinary course of our business. On December 26, 2018 , Vitol filed a lawsuit in the 80th District Court of Harris County (the “District Court”), Texas against Targa Channelview LLC, then a subsidiary of the Company (“Targa Channelview”), seeking recovery of $ 129.0 million in payments made to Targa Channelview, additional monetary damages, attorneys’ fees and costs. Vitol alleges that Targa Channelview breached the Splitter Agreement, which provided for Targa Channelview to construct a crude oil and condensate splitter (the “Splitter”) adjacent to a barge dock owned by Targa Channelview to provide services contemplated by the Splitter Agreement. In January 2018, Vitol acquired Noble Americas Corp. and on December 23, 2018, Vitol voluntarily elected to terminate the Splitter Agreement claiming that Targa Channelview failed to timely achieve start-up of the Splitter. Vitol’s lawsuit also alleges Targa Channelview made a series of misrepresentations about the capability of the barge dock that would service crude oil and condensate volumes to be processed by the Splitter and Splitter products. Vitol sought return of $ 129.0 million in payments made to Targa Channelview prior to the start-up of the Splitter, as well as additional damages. On the same date that Vitol filed its lawsuit, Targa Channelview filed a lawsuit against Vitol seeking a judicial determination that Vitol’s sole and exclusive remedy was Vitol’s voluntarily termination of the Splitter Agreement and, as a result, Vitol was not entitled to the return of any prior payments under the Splitter Agreement or other damages as alleged. Targa also seeks recovery of its attorneys’ fees and costs in the lawsuit. On October 15, 2020 , the District Court awarded Vitol $ 129.0 million (plus interest) following a bench trial. In addition, the District Court awarded Vitol $ 10.5 million in damages for losses and demurrage on crude oil that Vitol purchased for start-up efforts. The Company appealed the award in the Fourteenth Court of Appeals in Houston, Texas. In October 2020, we sold Targa Channelview but, under the agreements governing the sale, we retained the liabilities associated with the Vitol proceedings. On September 13, 2022, the Fourteenth Court of Appeals upheld the trial court’s judgment in part with regard to the return of Vitol’s prior payments, but modified the judgment to delete Vitol’s ability to recover any damages related to losses or demurrage on crude oil. We filed a petition for review with the Supreme Court of Texas which was denied on October 20, 2023, but we are seeking rehearing and the appeal remains pending. The cumulative amount of interest on the award through December 31, 2023, if accrued, would have been approximately $ 55.5 million. On July 24, 2023, we received a Notice of Violation from the New Mexico Environment Department, Air Quality Bureau, relating to alleged air permit violations between August 1, 2021 and June 30, 2022 by Lucid Energy Delaware, LLC, an entity we subsequently acquired in July 2022 in the Delaware Basin Acquisition and whose assets are now integrated into Targa Northern Delaware LLC, a wholly-owned subsidiary of the Company. We have been engaging with the New Mexico Environment Department to resolve this matter. Although this matter is ongoing and management cannot predict its ultimate outcome, the resolution of this matter may result in a fine or penalty in excess of $ 0.3 million. We do not expect that any expenditures related to this matter will be material to our consolidated financial statements. On October 26, 2023 , we received a final judgment in a lawsuit alleging a breach of contract related to the major winter storm in February 2021. The damages awarded against us are approximately $ 6.9 million, not including pre-judgment interest. Both parties are appealing the judgment. We are also a defendant in two other breach of contract cases related to force majeure events arising during the major winter storm in February 2021. We believe that the likelihood of a partial loss could be reasonably possible, and, while it is not possible to predict the ultimate outcome of these cases on an individual or consolidated basis, we estimate that the total range of potential loss resulting from all of these cases could be between $ 0 and $ 10.0 million in the aggregate. We intend to continue to vigorously defend these cases.

Revenue

Revenue	12 Months Ended
	Dec. 31, 2023
Revenue from Contract with Customer [Abstract]
Revenue	Note 19 – Revenue Fixed consideration allocated to remaining performance obligations The following table presents the estimated minimum revenue related to unsatisfied performance obligations at the end of the reporting period, and is comprised of fixed consideration primarily attributable to contracts with minimum volume commitments, for which a guaranteed amount of revenue can be calculated. These contracts are comprised primarily of gathering and processing, fractionation, export, terminaling and storage agreements, with remaining contract terms ranging from 1 to 16 years . 2024 2025 2026 and after Fixed consideration to be recognized as of December 31, 2023 $ 497.2 $ 419.8 $ 2,383.3 Based on the optional exemptions that we elected to apply, the amounts presented in the table above exclude remaining performance obligations for (i) variable consideration for which the allocation exception is met and (ii) contracts with an original expected duration of one year or less. For additional information on our revenue recognition policy, see Note 3 – Significant Accounting Policies, and for disclosures related to disaggregated revenue, see Note 23 – Segment Information.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2023
Income Tax Disclosure [Abstract]
Income Taxes	Note 20 – Inco me Taxes Components of the federal and state income tax provisions are as follows: 2023 2022 2021 Current expense (benefit) $ 13.6 $ 6.7 $ 2.7 Deferred expense (benefit) 349.6 125.1 12.1 Total income tax expense (benefit) $ 363.2 $ 131.8 $ 14.8 Our deferred income tax assets and liabilities as of December 31, 2023 and 2022 consist of recognition differences related to certain types of costs as follows: 2023 2022 Deferred tax assets: Net operating loss $ 1,282.9 $ 1,568.5 Disallowed business interest expense carryforward 79.3 10.3 Deferred tax assets before valuation allowance 1,362.2 1,578.8 Valuation allowance ( 7.1 ) ( 36.9 ) Deferred tax assets 1,355.1 1,541.9 Deferred tax liabilities: Investments (1) ( 1,867.9 ) ( 1,842.0 ) Property, plant, and equipment ( 3.0 ) ( 4.2 ) Other ( 20.0 ) ( 23.4 ) Deferred tax liabilities ( 1,890.9 ) ( 1,869.6 ) Net deferred tax asset (liability) $ ( 535.8 ) $ ( 327.7 ) Net deferred tax asset (liability) Federal $ ( 507.0 ) $ ( 290.5 ) State ( 28.8 ) ( 37.2 ) Long-term deferred tax liability, net $ ( 535.8 ) $ ( 327.7 ) (1) Our deferred tax liability attributable to investments reflects the differences between the book and tax carrying values of our investment in the Partnership. We are subject to tax in the U.S. and various state jurisdictions and we are subject to periodic audits and reviews by taxing authorities. As of December 31, 2023, IRS examinations are currently in process for the 2019, 2020 and 2021 taxable years of certain wholly-owned and consolidated subsidiaries that are treated as partnerships for U.S. federal income tax purposes. We are responding to information requests from the IRS with respect to these audits. We are not aware of any potential audit findings that would give rise to adjustments to taxable income and do not anticipate material changes related to these audits. Federal statutes of limitations for returns filed in 2020 (for calendar year 2019) have expired, except for the 2019 returns under examination that have a statute extension to April 2025. For Texas, the statute of limitations has expired for 2019 returns (for calendar year 2018). Similarly, the statute of limitations expired on substantially all 2019 state income tax returns that were filed prior to October 15, 2020. However, tax authorities could review and adjust carryover attributes (e.g., NOLs) generated in a closed tax year if utilized in an open tax year. During the preparation of the Company’s 2021 consolidated financial statements, the Company identified errors related to its 2020 state tax provision. The Company does not believe these errors are material to its previously issued historical consolidated financial statements for any of the periods impacted and accordingly, has not adjusted the historical financial statements. In 2021, the Company recorded an additional $ 23.3 million of income tax expense in the Consolidated Statements of Operations and corresponding increase to its deferred tax liabilities in the Consolidated Balance Sheets. As of December 31, 2023, we have total U.S. federal NOL carryforwards of $ 5.5 billion, $ 857.4 million of which will expire in 2037 . The remaining $ 4.7 billion NOL will not expire, but is limited to offsetting 80 % of taxable income per year. As of December 31, 2023 , our tax effected valuation allowance was $ 7.1 million, a decrease of $ 29.8 million from December 31, 2022 . Of this valuation allowance, $ 6.4 million is federal and the remaining $ 0.7 million is state. Set forth below is the reconciliation between our Income tax provision (benefit) computed at the United States statutory rate on income before income taxes and the income tax provision in our Consolidated Statements of Operations for the periods indicated: Income tax reconciliation: 2023 2022 2021 Income (loss) before income taxes $ 1,942.5 $ 1,663.2 $ 436.9 Less: Net income attributable to noncontrolling interest ( 233.4 ) ( 335.9 ) ( 350.9 ) Income attributable to Targa Resources Corp. before income taxes 1,709.1 1,327.3 86.0 Federal statutory income tax rate 21 % 21 % 21 % Provision for federal income taxes 358.9 278.7 18.1 Valuation allowance ( 29.8 ) ( 177.5 ) ( 46.2 ) State income taxes, net of federal tax benefit 37.8 33.6 ( 5.4 ) State tax provision error correction — — 23.3 Return-to-provision ( 5.7 ) ( 0.6 ) ( 1.3 ) Change in income tax rate 11.5 ( 1.7 ) 21.0 Permanent adjustments 6.2 5.6 4.1 Stock compensation shortfall/(windfall) ( 15.8 ) ( 6.3 ) 1.4 Other, net 0.1 — ( 0.2 ) Income tax provision (benefit) $ 363.2 $ 131.8 $ 14.8 We have not identified any uncertain tax positions. We believe that our income tax filing positions and deductions will be sustained on audit and do not anticipate any adjustments that will result in a material adverse effect on our financial condition, results of operations or cash flow. Therefore, no reserves for uncertain income tax positions have been recorded. On August 16, 2022, President Biden signed into law the Inflation Reduction Act of 2022 (the “IRA”) which, among other things, introduced a corporate alternative minimum tax (the “CAMT”), imposed a 1 % excise tax on stock buybacks and tax incentives to promote clean energy. Under the CAMT, a 15 % minimum tax will be imposed on certain financial statement income of “applicable corporations.” The IRA treats a corporation as an applicable corporation in any taxable year in which the “average annual adjusted financial statement income” of such corporation for the three taxable year period ending prior to such taxable year exceeds $ 1 billion. The U.S. Department of the Treasury and the IRS have issued guidance on the application of the CAMT which may be relied upon until final regulations are released. Based on our interpretation of the IRA, the CAMT and related guidance and several operational, economic, accounting and regulatory assumptions, we do not anticipate qualifying as an “applicable corporation” in the near term, but we are likely to become an applicable corporation in a subsequent tax year. If we become an applicable corporation and our CAMT liability is greater than our regular U.S. federal income tax liability for any particular tax year, the CAMT liability would effectively accelerate our future U.S. federal income tax obligations, reducing our cash available for distribution in that year, but provide an offsetting credit against our regular U.S. federal income tax liability for the future. As a result, our current expectation is that the impact of the CAMT is limited to timing differences in future tax years. Given the complexities of the IRA and the CAMT, we will continue to monitor and evaluate the potential future impact to our financial statements.

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	12 Months Ended
	Dec. 31, 2023
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information	Note 21 - S upplemental Cash Flow Information Year Ended December 31, 2023 2022 2021 Cash: Interest paid, net of capitalized interest (1) $ 618.6 $ 401.3 $ 356.0 Income taxes (received) paid, net 8.5 1.6 1.3 Non-cash investing activities: Change in deadstock commodity inventory $ ( 13.7 ) $ ( 3.8 ) $ ( 15.0 ) Impact of capital expenditure accruals on property, plant and equipment, net 58.2 60.1 53.0 Transfers from materials and supplies inventory to property, plant and equipment — — 2.4 Change in ARO liability and property, plant and equipment due to revised cash flow estimate and additions 4.9 0.8 ( 0.2 ) Non-cash financing activities: Changes in accrued distributions to noncontrolling interests $ 8.9 $ ( 26.1 ) $ ( 50.9 ) Reduction of owner's equity related to accrued dividends on unvested equity awards under share compensation arrangements 3.9 7.1 3.1 Non-cash distributions to noncontrolling interests (2) — 64.2 — Lease liabilities arising from recognition of right-of-use assets: Operating lease $ 53.1 $ 9.7 $ 20.1 Finance lease (3) 104.8 220.7 24.7 (1) Interest capitalized on major projects was $ 41.1 million, $ 16.3 million and $ 4.1 million for the years ended December 31, 2023, 2022 and 2021 . (2) Represents the transfer of an undivided interest in certain gas gathering and processing facilities to a joint owner upon Targa ’ s recovery of a specified payout amount for our initial full funding of the facilities. (3) The December 31, 2022 amount includes $ 171.2 million related to compressor leases from the Delaware Basin Acquisition that were subsequently amended and extended.

Compensation Plans

Compensation Plans	12 Months Ended
	Dec. 31, 2023
Share-Based Payment Arrangement [Abstract]
Compensation Plans	Note 22 – Co mpensation Plans 2010 Targa Resources Corp. Stock Incentive Plan In December 2010, we adopted the Targa Resources Corp. 2010 Stock Incentive Plan (the “2010 TRGP Plan”) for employees, consultants and non-employee directors of the Company. In May 2017, the 2010 TRGP Plan was amended and restated. In August 2023, the 2010 TRGP Plan was amended and restated for a second time. Total authorized shares of common stock under the plan is 15,000,000 , comprised of 5,000,000 shares originally available and an additional 10,000,000 shares that became available in May 2017. The 2010 TRGP Plan allows for the grant of (i) incentive stock options qualified as such under U.S. federal income tax laws (“Incentive Options”), (ii) stock options that do not qualify as Incentive Options (“Non-statutory Options,” and together with Incentive Options, “Options”), (iii) stock appreciation rights granted in conjunction with Options or Phantom Stock Awards, (iv) restricted stock awards, (v) phantom stock awards, (vi) bonus stock awards, (vii) performance unit awards, or (viii) any combination of such awards. Unless otherwise specified, the compensation costs for the awards listed below were recognized as expenses over related vesting periods based on the grant-date fair values, reduced by forfeitures incurred. Restricted Stock Awards - Restricted stock entitles the recipient to cash dividends. Dividends on unvested restricted stock will be accrued when declared and recorded as short-term or long-term liabilities, dependent on the time remaining until payment of the dividends, and paid in cash when the award vests. Upon issuance, the restricted stock awards will be included in the outstanding shares of our common stock. The Compensation Committee of the Targa board of directors (the “Compensation Committee”) awarded our common stock to our outside directors. In 2023, 2022 and 2021, we issued 23,518 , 31,117 and 67,591 shares of director grants with weighted average grant-date fair values of $ 74.13 , $ 56.32 and $ 30.33 , respectively. Restricted Stock Units Awards – RSUs are similar to restricted stock, except that shares of common stock are not issued until the RSUs vest. The vesting periods generally vary from one to six years. In March 2023, the Compensation Committee amended the Restricted Stock Units Grant Agreements that govern the RSUs that vest no later than three years following the RSUs’ grant date. The amendment resulted in quarterly cash dividend payments to RSU holders beginning with the common stock dividend paid in May 2023. In 2023, 2022 and 2021, we issued 587,326 , 943,352 and 848,630 shares of RSUs with weighted average grant-date fair values of $ 78.69 , $ 63.87 and $ 37.94 . Restricted Stock Units in Lieu of Bonus – In 2020 and 2019, we granted 81,336 and 95,687 shares of RSUs in lieu of cash bonuses for certain of our executives at the weighted average grant-date fair value of $ 41.39 and $ 42.83 . The 2020 and 2019 grants vested in 2021 and 2022, respectively. The following table summarizes the restricted stock and RSUs under the 2010 TRGP Plan in shares and in dollars for the year indicated. Number Weighted Average Outstanding at December 31, 2022 3,228,418 $ 42.60 Granted 610,844 78.52 Forfeited ( 95,643 ) 61.92 Vested ( 1,435,823 ) 32.05 Outstanding at December 31, 2023 2,307,796 57.84 Performance Share Units During 2023, 2022 and 2021 , we granted 140,020 , 173,011 and 319,320 performance share units (“PSUs”) to executive management for the 2023, 2022 and 2021 compensation cycle that will vest/have vested in January 2026 , January 2025 and January 2024 . The PSUs granted under the 2010 TRGP Plan are three-year equity-settled awards linked to the performance of shares of our common stock. The awards also include dividend equivalent rights (“DERs”) that are based on the notional dividends accumulated during the vesting period. The vesting of the PSUs is dependent on the satisfaction of a combination of certain service-related conditions and the Company’s total shareholder return (“TSR”) relative to the TSR of the members of a specified comparator group of publicly-traded midstream companies (the “LTIP Peer Group”) measured over designated periods. For the PSUs granted in 2021, 2022 and 2023, the TSR performance factor is determined by the Compensation Committee based on relative TSR over a cumulative three-year performance period. The Compensation Committee determines a guideline performance percentage for the performance period and the percentage may then be decreased or increased by the Compensation Committee at its discretion. The grantee will become vested in a number of PSUs equal to the target number awarded multiplied by the TSR performance factor, and vested PSUs will be settled by the issuance of Company common stock. The value of dividend equivalent rights will be paid in cash when the awards vest. Compensation cost for equity-settled PSUs was recognized as an expense over the performance period based on fair value at the grant date. The compensation cost will be reduced if forfeitures occur. Fair value was calculated using a simulated share price that incorporates peer ranking. DERs associated with equity-settled PSUs were accrued over the performance period as a reduction of owners’ equity. We evaluated the grant date fair value using a Monte Carlo simulation model and historical volatility assumption with an expected term of three years . The expected volatilities were 38 %, 80 % and 80 % for PSUs granted in 2023, 2022 and 2021. The following table summarizes the PSUs under the 2010 TRGP Plan in shares and in dollars for the years indicated. Number Weighted Average Outstanding at December 31, 2022 769,917 $ 72.81 Granted 140,020 128.71 Forfeited ( 22,272 ) 117.52 Vested ( 291,365 ) 69.70 Outstanding at December 31, 2023 596,300 85.78 Stock Compensation Expenses Stock compensation expense under our plans totaled $ 62.4 million, $ 57.5 million and $ 59.2 million for the years ended December 31, 2023, 2022 and 2021. As of December 31, 2023, we have $ 87.5 million of unrecognized compensation expense associated with share-based awards and an approximate remaining weighted average vesting periods of 2.3 years related to our various compensation plans. The fair values of share-based awards vested in 2023, 2022 and 2021 were $ 96.8 million, $ 93.0 million and $ 73.8 million. Cash dividends paid for the vested awards were $ 8.3 million, $ 9.6 million and $ 8.7 million for 2023, 2022 and 2021. In relation to our equity compensation plans, we recognized $ 17.0 million and $ 6.7 million in windfall tax benefits for the years ended December 31, 2023 and 2022, respectively. We recognized $ 1.6 million of tax deficiencies for the year ended December 31, 2021. Subsequent Events In January 2024, the Compensation Committee made the following awards under the 2010 TRGP Plan. • 20,414 shares of restricted stock to our outside directors that will vest in January 2025 . • 128,316 shares of RSUs to executive management for the 2024 compensation cycle that will vest in January 2027 . • 128,316 shares of PSUs to executive management for the 2024 compensation cycle that will vest in January 2027 . In January 2024, 23,518 shares of director grants vested with no shares withheld to satisfy tax withholding obligations. In January 2024, 320,549 shares of RSUs vested with 127,443 shares withheld to satisfy tax withholding obligations. In January 2024, 765,478 shares of 2021 PSUs vested with 296,600 shares withheld to satisfy tax withholding obligations. Targa 401(k) Plan We have a 401(k) plan whereby we match 100 % of up to 5 % of an employee’s contribution (subject to certain limitations in the plan). We also contribute an amount equal to 3 % of each employee’s eligible compensation to the plan as a retirement contribution and may make additional contributions at our sole discretion. All Targa contributions are made 100 % in cash. We made contributions to the 401(k) plan totaling $ 32.3 million, $ 26.6 million and $ 21.8 million during 2023, 2022 and 2021 .

Segment Information

Segment Information	12 Months Ended
	Dec. 31, 2023
Segment Reporting [Abstract]
Segment Information	Note 23 — Segment Information We operate in two primary segments: (i) Gathering and Processing, and (ii) Logistics and Transportation (also referred to as the Downstream Business). Our reportable segments include operating segments that have been aggregated based on the nature of the products and services provided. Our Gathering and Processing segment includes assets used in the gathering and/or purchase and sale of natural gas produced from oil and gas wells, removing impurities and processing this raw natural gas into merchantable natural gas by extracting NGLs; and assets used for the gathering and terminaling and/or purchase and sale of crude oil. The Gathering and Processing segment’s assets are located in the Permian Basin of West Texas and Southeast New Mexico (including the Midland, Central and Delaware Basins); the Eagle Ford Shale in South Texas; the Barnett Shale in North Texas; the Anadarko, Ardmore, and Arkoma Basins in Oklahoma (including the SCOOP and STACK) and South Central Kansas; the Williston Basin in North Dakota (including the Bakken and Three Forks plays); and the onshore and near offshore regions of the Louisiana Gulf Coast and the Gulf of Mexico. Our Logistics and Transportation segment includes the activities and assets necessary to convert mixed NGLs into NGL products and also includes other assets and value-added services such as transporting, storing, fractionating, terminaling, and marketing of NGLs and NGL products, including services to LPG exporters and certain natural gas supply and marketing activities in support of our other businesses. The Logistics and Transportation segment also includes Grand Prix, which connects our gathering and processing positions in the Permian Basin, Southern Oklahoma and North Texas with our Downstream facilities in Mont Belvieu, Texas. The associated assets are generally connected to and supplied in part by our Gathering and Processing segment and, except for pipelines and smaller terminals, are located predominantly in Mont Belvieu and Galena Park, Texas, and in Lake Charles, Louisiana. Other contains the unrealized mark-to-market gains/losses related to derivative contracts that were not designated as cash flow hedges. Elimination of inter-segment transactions are reflected in the corporate and eliminations column. Reportable segment information is shown in the following tables: Year Ended December 31, 2023 Gathering and Processing Logistics and Transportation Other Corporate Total Revenues Sales of commodities $ 1,076.1 $ 12,610.5 $ 275.5 $ — $ 13,962.1 Fees from midstream services 1,366.5 731.7 — — 2,098.2 2,442.6 13,342.2 275.5 — 16,060.3 Intersegment revenues Sales of commodities 4,786.3 267.9 — ( 5,054.2 ) — Fees from midstream services 2.6 45.7 — ( 48.3 ) — 4,788.9 313.6 — ( 5,102.5 ) — Revenues $ 7,231.5 $ 13,655.8 $ 275.5 $ ( 5,102.5 ) $ 16,060.3 Operating margin (1) $ 2,082.2 $ 1,948.7 $ 275.5 Other financial information: Total assets (2) $ 12,685.2 $ 7,777.8 $ 4.2 $ 204.6 $ 20,671.8 Goodwill $ 45.2 $ — $ — $ — $ 45.2 Capital expenditures $ 1,514.7 $ 910.0 $ — $ 18.9 $ 2,443.6 Year Ended December 31, 2022 Gathering and Processing Logistics and Transportation Other Corporate Total Revenues Sales of commodities $ 919.7 $ 18,448.7 $ ( 302.4 ) $ — $ 19,066.0 Fees from midstream services 1,157.3 706.5 — — 1,863.8 2,077.0 19,155.2 ( 302.4 ) — 20,929.8 Intersegment revenues Sales of commodities 9,169.4 541.7 — ( 9,711.1 ) — Fees from midstream services 0.6 45.2 — ( 45.8 ) — 9,170.0 586.9 — ( 9,756.9 ) — Revenues $ 11,247.0 $ 19,742.1 $ ( 302.4 ) $ ( 9,756.9 ) $ 20,929.8 Operating margin (1) $ 1,981.0 $ 1,456.3 $ ( 302.4 ) Other financial information: Total assets (2) $ 12,133.6 $ 7,175.7 $ — $ 250.7 $ 19,560.0 Goodwill $ 45.2 $ — $ — $ — $ 45.2 Capital expenditures $ 918.1 $ 453.0 $ — $ 23.3 $ 1,394.4 Year Ended December 31, 2021 Gathering and Processing Logistics and Transportation Other Corporate Total Revenues Sales of commodities $ 606.8 $ 15,111.6 $ ( 115.9 ) $ — $ 15,602.5 Fees from midstream services 747.3 600.0 — — 1,347.3 1,354.1 15,711.6 ( 115.9 ) — 16,949.8 Intersegment revenues Sales of commodities 6,067.9 409.5 — ( 6,477.4 ) — Fees from midstream services 3.5 38.6 — ( 42.1 ) — 6,071.4 448.1 — ( 6,519.5 ) — Revenues $ 7,425.5 $ 16,159.7 $ ( 115.9 ) $ ( 6,519.5 ) $ 16,949.8 Operating margin (1) $ 1,325.3 $ 1,264.3 $ ( 115.9 ) Other financial information: Total assets (2) $ 7,998.1 $ 7,041.9 $ 14.0 $ 154.2 $ 15,208.2 Goodwill $ 45.2 $ — $ — $ — $ 45.2 Capital expenditures $ 471.7 $ 78.1 $ — $ 10.7 $ 560.5 (1) Operating margin is calculated by subtracting Product purchases and fuel and Operating expenses from Revenues. (2) Assets in the Corporate and Eliminations column primarily include tax-related assets, cash, prepaids and debt issuance costs for our revolving credit facilities. The following table shows our consolidated revenues disaggregated by product and service for the periods presented: Year Ended December 31, 2023 2022 2021 Sales of commodities: Revenue recognized from contracts with customers: Natural gas $ 2,421.3 $ 5,470.2 $ 3,523.9 NGL 10,580.2 13,785.2 12,210.8 Condensate and crude oil 519.5 565.3 358.4 13,521.0 19,820.7 16,093.1 Non-customer revenue: Derivative activities - Hedge 153.4 ( 373.0 ) ( 417.3 ) Derivative activities - Non-hedge (1) 287.7 ( 381.7 ) ( 73.3 ) 441.1 ( 754.7 ) ( 490.6 ) Total sales of commodities 13,962.1 19,066.0 15,602.5 Fees from midstream services: Revenue recognized from contracts with customers: Gathering and processing 1,342.8 1,137.2 730.3 NGL transportation, fractionation and services 261.1 285.1 190.6 Storage, terminaling and export 440.7 372.2 379.7 Other 53.6 69.3 46.7 Total fees from midstream services 2,098.2 1,863.8 1,347.3 Total revenues $ 16,060.3 $ 20,929.8 $ 16,949.8 (1) Represents derivative activities that are not designated as hedging instruments under ASC 815. The following table shows a reconciliation of reportable segment Operating margin to Income (loss) before income taxes for the periods presented: Year Ended December 31, 2023 2022 2021 Reconciliation of reportable segment operating Gathering and Processing operating margin $ 2,082.2 $ 1,981.0 $ 1,325.3 Logistics and Transportation operating margin 1,948.7 1,456.3 1,264.3 Other operating margin 275.5 ( 302.4 ) ( 115.9 ) Depreciation and amortization expense ( 1,329.6 ) ( 1,096.0 ) ( 870.6 ) General and administrative expense ( 348.7 ) ( 309.7 ) ( 273.2 ) Other operating income (expense) ( 1.5 ) ( 0.2 ) ( 12.4 ) Impairment of long-lived assets — — ( 452.3 ) Interest expense, net ( 687.8 ) ( 446.1 ) ( 387.9 ) Equity earnings (loss) 9.0 9.1 ( 23.9 ) Gain (loss) from financing activities ( 2.1 ) ( 49.6 ) ( 16.6 ) Gain (loss) from sale of equity method investment — 435.9 — Other, net ( 3.2 ) ( 15.1 ) 0.1 Income (loss) before income taxes $ 1,942.5 $ 1,663.2 $ 436.9

Significant Accounting Polici_2

Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2023
Accounting Policies [Abstract]
Consolidation Policy	Consolidation Policy Our consolidated financial statements include the accounts of all entities that we control and our proportionate interest in the accounts of certain gas gathering and processing facilities in which we own an undivided interest and are responsible for our proportionate share of the costs and expenses of the facilities. Third party ownership interests in our controlled subsidiaries are presented as noncontrolling interests within the equity section of our Consolidated Balance Sheets, except in the case of undivided interest ownership. In our Consolidated Statements of Operations and Consolidated Statements of Comprehensive Income (Loss), noncontrolling interests reflect the attribution of results to third-party investors. All intercompany balances and transactions have been eliminated in consolidation. As of December 31, 2023, our consolidated joint ventures include the following: Gathering and Processing Segment • 60 % ownership interest in Centrahoma Processing LLC; • 55 % ownership interest in Targa Badlands LLC; • 72.8 % undivided interest in the assets of Targa Pipeline Mid-Continent WestTex LLC; and • 76.8 % ownership interest in Venice Energy Services Company, LLC. Logistics and Transportation Segment • 88 % ownership interest in Cedar Bayou Fractionators, L.P.; and • 80 % ownership interest in Targa Train 7 LLC. We apply the equity method of accounting to investments over which we exercise significant influence over the operating and financial policies of our investee, but do not exercise control. We evaluate our equity investments for impairment when evidence indicates the carrying amount of our investment is no longer recoverable. Evidence of a loss in value might include, but would not necessarily be limited to, absence of an ability to recover the carrying amount of the investment or inability of the equity method investee to sustain an earnings capacity that would justify the carrying amount of the investment. When the estimated fair value of an equity investment is less than its carrying value and the loss in value is determined to be other than temporary, we recognize the excess of the carrying value over the estimated fair value as a non-cash pre-tax impairment loss within Equity earnings (loss) in our Consolidated Statements of Operations. As of December 31, 2023, our investments in unconsolidated affiliates include the following: Gathering and Processing Segment • 50 % ownership interest in Little Missouri 4 LLC (“Little Missouri 4”). Logistics and Transportation Segment • 50 % ownership interest in Cayenne Pipeline, LLC (“Cayenne”); and • 38.8 % ownership interest in Gulf Coast Fractionators (“GCF”).
Use of Estimates	Use of Estimates The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the amounts reported in these financial statements and accompanying notes. Estimates and judgments are based on information available at the time such estimates and judgments are made. Changes in facts and circumstances may result in revised estimates and actual results could differ materially from those estimates. Estimates and judgments are used in, among other things, (i) estimating unbilled revenues, product purchases and operating and general and administrative cost accruals, (ii) developing fair value assumptions, including estimates of future cash flows and discount rates, (iii) analyzing long-lived assets for possible impairment, (iv) estimating the useful lives of assets and (v) estimating contingencies, guarantees and indemnifications.
Cash and Cash Equivalents	Cash and Cash Equivalents Cash and cash equivalents include all cash on hand, demand deposits, and short-term, highly liquid investments that are readily convertible into cash, and have original maturities of three months or less.
Allowance for Credit Losses	Allowanc e for Credit Losses Estimated losses on accounts receivable are provided through an allowance for credit losses. We estimate the allowance for credit losses through various procedures, including extensive review of our trade receivable balances by counterparty, assessing economic events and conditions, our historical experience with counterparties, the counterparty’s financial condition and the amount and age of past due accounts. We continuously evaluate our ability to collect amounts owed to us. Receivables are considered past due if full payment is not received by the contractual due date. Our evaluation procedures also include performing account reconciliations, dispute resolution and payment confirmation. As the financial condition of any counterparty changes, circumstances develop or additional information becomes available, adjustments to our allowance may be required.
Inventories	Inventories Our inventories consist primarily of NGL product inventories, which are valued at the lower of cost or net realizable value, using the average cost method. Most NGL product inventories turn over monthly, but some inventory, primarily propane, is acquired and held during the year to meet anticipated heating season requirements of our customers. Commodity inventories that are not physically or contractually available for sale under normal operations (“deadstock”) are included in Property, plant and equipment.
Product Exchanges	Product Exchanges Exchanges of NGL products are executed to satisfy timing and logistical needs of the exchange parties. Volumes received and delivered under exchange agreements are recorded as inventory. If the locations of receipt and delivery are in different markets, an exchange differential may be billed or owed. The exchange differential is recorded as either accounts receivable or accrued liabilities.
Gas Processing Imbalances	Gas Processing Imbalances Quantities of natural gas and/or NGLs over-delivered or under-delivered, related to certain gas plant operational balancing agreements, are recorded monthly as inventory or as a payable using the weighted average price at the time the imbalance was created. Inventory imbalances receivable are valued at the lower of cost or net realizable value using the average cost method; inventory imbalances payable are valued at replacement cost. These imbalances are settled either by current cash-out settlements or by adjusting future receipts or deliveries of natural gas or NGLs.
Derivative Instruments	Derivative Instruments We utilize derivative instruments to manage the volatility of our cash flows due to fluctuating energy commodity prices. For balance sheet classification purposes, we analyze the fair values of the derivative instruments on a contract by contract basis and report the related fair values and any related collateral by counterparty on a gross basis. Cash flows from derivative instruments designated as hedges are recognized in the same financial statement line item as the cash flows from the respective item being hedged. We formally document all relationships between hedging instruments and hedged items, as well as its risk management objectives and strategy for undertaking the hedge. This documentation includes the specific identification of the hedging instrument and the hedged item, the nature of the risk being hedged and the manner in which the hedging instrument’s effectiveness will be assessed. At the inception of the hedge and on an ongoing basis, we assess whether the derivatives used in hedging transactions are highly effective in achieving the offset of changes in cash flows attributable to the hedged risk. We record all derivative instruments at fair value with the exception of those that we apply the normal purchases and normal sales election. The table below summarizes the accounting treatment for our derivative instruments, and the impact on our consolidated financial statements: Recognition and Measurement Derivative Treatment Balance Sheet Income Statement Normal Purchases and Normal Sales Fair value not recorded Earnings recognized when volumes are physically delivered or received Mark-to-Market Recorded at fair value Change in fair value recognized currently in earnings Cash Flow Hedge Recorded at fair value with changes in fair value deferred in Accumulated Other Comprehensive Income (“AOCI”) The gain/loss on the derivative instrument is reclassified out of AOCI into earnings when the forecasted transaction occurs We will discontinue hedge accounting on a prospective basis when a hedge instrument is terminated, ceases to be highly effective or the forecasted transaction is no longer probable to occur. Gains and losses deferred in AOCI related to cash flow hedges for which hedge accounting has been discontinued remain deferred until the forecasted transaction occurs. If it is probable that a hedged forecasted transaction will not occur, deferred gains or losses on the hedging instrument are reclassified to earnings immediately.
Property, Plant and Equipment	Property, Plant and Equipment Property, plant and equipment is recorded at acquisition cost less accumulated depreciation. Depreciation is computed using the straight-line method over the estimated useful lives of the assets. The determination of the useful lives of property, plant and equipment requires us to make various assumptions, including our expected use of the asset and the supply of, and demand for, hydrocarbons in the markets served, normal wear and tear of the facilities, and the extent and frequency of maintenance programs. Upon disposition or retirement of property, plant and equipment, any gain or loss is recorded to operations. Expenditures for routine maintenance and repairs are expensed as incurred. Expenditures to refurbish an asset that increases its existing service potential or prevents environmental contamination are capitalized and depreciated over the remaining useful life of the asset or major asset component. Certain costs directly related to the construction of assets, including internal labor costs, interest and engineering costs, are capitalized.
Impairment of Long-Lived Assets	Impairment of Long-Lived Assets We evaluate long-lived assets, including intangible assets, for impairment when events or changes in circumstances indicate our carrying amount of an asset may not be recoverable, including changes to our estimates that could have an impact on our assessment of asset recoverability. Asset recoverability is measured by comparing the carrying value of the asset or asset group with its expected future pre-tax undiscounted cash flows. Individual assets are grouped at the lowest level for which the related identifiable cash flows are largely independent of the cash flows of other assets and liabilities. These cash flow estimates require us to make judgments and assumptions related to operating and cash flow results, economic obsolescence, the business climate, contractual, legal and other factors. If the carrying amount exceeds the expected future undiscounted cash flows, we recognize a non-cash pre-tax impairment loss equal to the excess of net book value over fair value as determined by quoted market prices in active markets or present value techniques if quotes are unavailable. The estimated cash flows used to assess recoverability of our long-lived assets and measure fair value of our asset groups are derived from current business plans, which are developed using near-term price and volume projections reflective of the current environment and management's projections for long-term average prices and volumes. In addition to near and long-term price assumptions, other key assumptions include volume projections, operating costs, timing of incurring such costs, and the use of an appropriate terminal value and discount rate. Any changes we make to these projections and assumptions could result in significant revisions to our evaluation of recoverability of our long-lived assets and the recognition of additional impairments. We believe our estimates and models used to determine fair value are similar to what a market participant would use.
Goodwill	Goodwill Goodwill is a residual intangible asset that results when the cost of an acquisition exceeds the fair value of the net identifiable assets of the acquired business. Goodwill is not subject to amortization but is tested for impairment at least annually. This test requires us to attribute goodwill to an appropriate reporting unit, which is an operating segment or one level below an operating segment (also known as a component). We evaluate goodwill for impairment on November 30 of each year, or whenever impairment indicators are present. Prior to us conducting the goodwill impairment test, we complete a review of the carrying values of our long-lived assets, including property, plant and equipment and other intangible assets. If it is determined that the carrying values are not recoverable, we reduce the carrying values of the long-lived assets pursuant to our policy on property, plant and equipment. As part of our goodwill impairment test, we may first assess qualitative factors to determine if the quantitative goodwill impairment test is necessary. If we choose to bypass this qualitative assessment or determine that a goodwill impairment test is required, our annual goodwill impairment test is performed by comparing the fair value of a reporting unit with its carrying amount (including attributed goodwill). We recognize an impairment loss in our Consolidated Statements of Operations and a corresponding reduction of goodwill on our Consolidated Balance Sheets for the amount by which the carrying amount exceeds the reporting unit’s fair value. The goodwill impairment loss will not exceed the total amount of goodwill allocated to that reporting unit. Additionally, when measuring goodwill, we consider income tax effects from any tax-deductible goodwill on the carrying amount of the reporting unit, if applicable.
Intangible Assets	Intangible Assets Our intangible assets include producer dedications under long-term contracts and customer relationships associated with business and asset acquisitions. The fair value of these acquired intangible assets was determined at the date of acquisition based on the present value of estimated future cash flows. We amortize the costs of our assets in a manner that closely resembles the expected benefit pattern of the intangible assets or on a straight-line basis, where such pattern is not readily determinable, over the periods in which we benefit from services provided to customers.
Asset Retirement Obligations	Asset Retirement Obligations Asset retirement obligations (“AROs”) are legal obligations associated with the retirement of tangible long-lived assets that result from their acquisition, construction, development and/or normal operation. We record a liability and increase the basis in the underlying asset for the present value of each expected ARO when there is a legal obligation to settle under existing or enacted law, statute, written or oral contract or by legal construction. Our obligations are estimated based on discounted cash flow (“DCF”) estimates. Over time, the ARO liability is accreted to its present value as a period cost and the capitalized amount is depreciated over the asset’s respective useful life. At least annually, we review the projected timing and amount of AROs and reflect revisions as an increase or decrease in the carrying amount of the liability and the basis in the underlying asset. Upon settlement, we will recognize any difference between the recorded amount and the actual settlement cost as a gain or loss.
Debt Issuance Costs	Debt Issuance Costs Costs incurred in connection with the issuance of long-term debt and any original issue discount or premium are deferred and charged to interest expense over the term of the related debt. Debt issuance costs related to revolving credit facilities and the term loan facility are amortized on a straight-line basis and those related to long-term debt are amortized using the effective-interest method. Debt issuance costs related to revolving credit facilities are presented as other long-term assets, and debt issuance costs related to long-term debt obligations with scheduled maturities are reflected as a deduction to the carrying amount of long-term debt on the Consolidated Balance Sheets. Gains or losses on debt repurchases, redemptions and debt extinguishments include any associated unamortized debt issuance costs.
Accounts Receivable Securitization Facility	Accounts Receivable Securitization Facility Proceeds from the sale or contribution of certain receivables under the Partnership’s accounts receivable securitization facility (the “Securitization Facility”) are treated as collateralized borrowings in our financial statements. Proceeds and repayments under the Securitization Facility are reflected as cash flows from financing activities in our Consolidated Statements of Cash Flows.
Commercial Paper Program	Commercial Paper Program Under the terms of the unsecured commercial paper note program (the “Commercial Paper Program”), we may issue, from time to time, unsecured commercial paper notes with varying maturities of less than one year. Amounts available under the Commercial Paper Program may be issued, repaid, and re-issued from time to time, with the maximum aggregate face or principal amount outstanding at any one time not to exceed $ 2.75 billion. We maintain a minimum available borrowing capacity under the $ 2.75 billion TRGP senior revolving credit facility (the “TRGP Revolver”) equal to the aggregate amount outstanding under the Commercial Paper Program as support. The Commercial Paper Program is guaranteed by each subsidiary that guarantees the TRGP Revolver. The outstanding borrowings of the commercial paper program are classified as noncurrent because we intend to refinance the borrowings on a long-term basis through the TRGP Revolver. We confirm, on a quarterly basis, that there is sufficient liquidity under the TRGP Revolver to refinance outstanding borrowings of the Commercial Paper Program and such liquidity is not overcommitted for other anticipated uses. As the outstanding borrowings of the Commercial Paper Program are included as part of long-term debt (i.e., classified as noncurrent), we report Commercial Paper Program borrowings and repayments gross on the statement of cash flows (consistent with the presentation of cash flows associated with the TRGP Revolver).
Debt Modification and Extinguishment	Debt Modification and Extinguishment When similar debt instruments are issued and redeemed in the same period, we evaluate whether the issuance of the new instrument should be accounted for as a modification of the existing debt or as an extinguishment of the existing debt and issuance of new debt. We account for these debt transactions as modifications unless they are considered substantially different debt instruments, in which case we account for them as debt extinguishments and new issuances. Transactions involving the issuance of a new debt instrument to one lender and the concurrent satisfaction of an existing debt instrument with another unrelated lender are always accounted for as an extinguishment of the existing debt and issuance of new debt. Debt instruments are considered substantially different if the present value of the cash flows under the terms of the new debt instrument is at least 10 percent different from the present value of the remaining cash flows under the terms of the existing debt instrument. We consider changes in principal amounts, interest rates, and maturity dates of the existing and new instruments when evaluating the change in cash flows between the instruments. Transactions accounted for as modifications do no t result in a gain or loss. We calculate a new effective interest rate based on the revised cash flows. Fees paid to existing lenders are capitalized and amortized while expenses paid to third parties are expensed. Transactions accounted for as extinguishments result in derecognition of the extinguished debt and recording the new debt at fair value. A gain or loss is recognized for the difference between the carrying value of the extinguished debt and the fair value of the new debt. New fees paid to existing lenders are expensed while fees paid to third parties are capitalized and amortized as debt issuance costs.
Environmental Liabilities and Other Loss Contingencies	Environmental Liabilities and Other Loss Contingencies We accrue a liability for loss contingencies, including environmental remediation costs arising from claims, assessments, litigation, fines, penalties and other sources, when the loss is probable and reasonably estimable.
Income Taxes	Income Taxes We file many income tax returns with the U.S. Department of the Treasury, as well as numerous states. We are required to estimate our income taxes in each of the jurisdictions in which we operate. This process involves estimating our actual current tax payable and related tax expense, together with assessing temporary differences resulting from differing treatment of certain items, such as depreciation, for tax and accounting purposes. These differences can result in deferred tax assets and liabilities, which are reported on a net basis by jurisdiction within our Consolidated Balance Sheets. We report these timing differences based on statutory tax rates applicable to the scheduled timing difference reversal periods. We assess the likelihood that we will recover our deferred tax assets from future taxable income. We establish a valuation allowance if we believe that it is more likely than not (a likelihood of more than 50 percent) that some portion or all of the deferred tax assets will not be realized. Any change in the valuation allowance would impact our income tax provision and net income in the period in which such a determination is made. We consider all available evidence to determine whether, based on the weight of the evidence, we need a valuation allowance. Evidence used includes information about our current financial position and our results of operations for the current and preceding years, as well as all currently available information about future years, including our anticipated future performance, the reversal of deferred tax liabilities and tax planning strategies.
Dividends	Dividends Preferred and common dividends declared are recorded as a reduction of retained earnings to the extent that retained earnings was available at the close of the prior quarter, with any excess recorded as a reduction of additional paid-in capital.
Comprehensive Income	Comprehensive Income Comprehensive income includes net income and other comprehensive income (“OCI”), which includes changes in the fair value of derivative instruments that are designated as cash flow hedges
Revenue Recognition	Revenue Recognition Our operating revenues are primarily derived from the following activities: • sales of natural gas, NGLs, condensate and crude oil; • services related to compressing, gathering, treating, and processing of natural gas; and • services related to NGL fractionation, terminaling and storage, transportation and treating. We have multiple types of contracts with commercial counterparties and many of these contracts contain embedded fees with settlement provisions that deduct these fees from the sales price paid by Targa in exchange for commodities. The commercial relationship of the counterparty in such contracts is inherently one of a supplier, rather than a customer, and therefore, such contracts are excluded from the provisions of the revenue recognition guidance in Topic 606, Revenue from Contracts with Customers . Any cash inflows or fees that are realized on these supply type contracts are reported as a reduction of Product purchases and fuel. Our revenues, therefore, are measured based on consideration specified in a contract with parties designated as customers. We recognize revenue when we satisfy a performance obligation by transferring control over a commodity or service to a customer. Sales and other taxes we collect, that are both imposed on and concurrent with revenue-producing activities, are excluded from revenues. We generally report sales revenues on a gross basis in our Consolidated Statements of Operations, as we typically act as the principal in the transactions where we receive and control commodities. However, buy-sell transactions that involve purchases and sales of inventory with the same counterparty, which are legally contingent or in contemplation of one another, as well as other instances where we do not control the commodities, but rather are acting as an agent to the supplier, are reported as a single revenue transaction on a combined net basis. Our commodity sales contracts typically contain multiple performance obligations, whereby each distinct unit of commodity to be transferred to the customer is a separate performance obligation. Under such contracts, revenue is recognized at the point in time each unit is transferred to the customer because the customer is able to direct the use of, and obtain substantially all of the remaining benefits from, the commodity at that time. In certain instances, it may be determinable that the customer receives and consumes the benefits of each unit as it is transferred. Under such contracts, we have a single performance obligation comprised of a series of distinct units of commodity; and in such instance, revenue is recognized over time using the units delivered output method, as each distinct unit is transferred to the customer. Our commodity sales contracts are typically priced at a market index, but may also be set at a fixed price. When our sales are priced at a market index, we apply the allocation exception for variable consideration and allocate the market price to each distinct unit when it is transferred to the customer. The fixed price in our commodity sales contracts generally represents the standalone selling price, and therefore, when each distinct unit is transferred to the customer, we recognize revenue at the fixed price. Our service contracts typically contain a single performance obligation. The underlying activities performed by us are considered inputs to an integrated service and not separable because such activities in combination are required to successfully transfer the single overall service that the customer has contracted for and expects to receive. Therefore, the underlying activities in such contracts are not considered to be distinct services. However, in certain instances, the customer may contract for additional distinct services and therefore additional performance obligations may exist. In such instances, the transaction price is allocated to the multiple performance obligations based on their relative standalone selling prices. The performance obligation(s) in our service contracts is a series of distinct days of the applicable service over the life of the contract (fundamentally a stand-ready service), whereby we recognize revenue over time using an output method of progress based on the passage of time (i.e., each day of service). This output method is appropriate because it directly relates to the value of service transferred to the customer to date, relative to the remaining days of service promised under the contract. The transaction price for our service contracts is typically comprised of variable consideration, which is primarily dependent on the volume and composition of the commodities delivered and serviced. The variable consideration is generally commensurate with our efforts to perform the service and the terms of the variable payments relate specifically to our efforts to satisfy each day of distinct service. Therefore, the variable consideration is typically not estimated at contract inception, but rather the allocation exception for variable consideration is applied, whereby the variable consideration is allocated to each day of service and recognized as revenue when each day of service is provided. When we are entitled to noncash consideration in the form of commodities, the variability related to the form of consideration (market price) and reasons other than form (volume and composition) are interrelated to the service, and therefore, we measure the noncash consideration at the point in time when the volume, mix and market price related to the commodities retained in-kind are known. This results in the recognition of revenue based on the market price of the commodity when the service is performed. In addition, if the transaction price includes a fixed component (i.e., a fixed capacity reservation fee), the fixed component is recognized ratably on a straight-line basis over the contract term, as each day of service has elapsed, which is consistent with the output method of progress selected for the performance obligation. Our customers are typically billed on a monthly basis, or earlier, if final delivery and sale of commodities is made prior to month-end, and payment is typically due within 10 to 30 days . As a practical matter, we define the unit of account for revenue recognition purposes based on the passage of time ranging from one month to one quarter, rather than each day. This is because the financial reporting outcome is the same regardless of whether each day or month/quarter is treated as the distinct service in the series. That is, at the end of each month or quarter, the variability associated with the amount of consideration for which we are entitled to, is resolved, and can be included in that month or quarter’s revenue. We have certain long-term contractual arrangements under which we have received consideration, but for which all conditions for revenue recognition have not been met. These arrangements result in deferred revenue, which will be recognized over the periods that performance will be provided. We have certain contracts that contain provisions in which customers provide contributions in aid of construction in exchange for Targa constructing assets to fulfill the services in the contract. In general, these arrangements result in deferred revenue, which will be recognized over the contract term. Contract Assets We classify our contract assets as receivables because we generally have an unconditional right to payment for the commodities sold or services performed at the end of the reporting period. We enter into various contractual arrangements that result in the transfer of assets for no upfront compensation or cash payments, resulting in more favorable long-term contractual terms. The fair value of the assets transferred is reflected as long-term contract assets. These deferred amounts are amortized over the term of the related contract into the appropriate revenue or cost of sales accounts.
Share-Based Compensation	Share-Based Compensation We award share-based compensation to employees and non-employee directors in the form of restricted stock, restricted stock units and performance share units. Compensation expense on our equity-classified awards is recorded at grant-date fair value. Compensation expense is recognized in general and administrative expense over the requisite service period of each award, and forfeitures are recognized as they occur. We may purchase a portion of the shares issued to satisfy employees’ tax withholding obligations on vested awards. These shares are recorded in treasury stock, at cost, and cash paid is classified as a financing activity in our Consolidated Statements of Cash Flows. All excess tax benefits and tax deficiencies related to share-based compensation are recognized as income tax benefit or expense in our Consolidated Statements of Operations, with the tax effects of exercised or vested awards treated as discrete items in the reporting period which they occur. Excess tax benefits are classified as an operating activity.
Earnings per Share	Earnings per Share We calculate basic earnings (loss) per common share (“EPS”) using the two-class method, which is an earnings allocation formula that determines net income (loss) per share for each class of common stock and participating security according to dividends declared and participation rights in undistributed earnings. Our participating securities consist of unvested restricted stock units that vest no later than three years following grant date as well as certain four-year retention awards that participate in nonforfeitable dividends with the common equity owners. EPS is net income (loss) attributable to common shareholders less earnings allocated to participating securities divided by the sum of the weighted-average number of common shares outstanding. Earnings are allocated to common stock and participating securities based on the amount of dividends paid in the current period plus an allocation of the undistributed earnings to the extent that each security participates in earnings. Diluted EPS includes any dilutive effect of preferred stock, unvested restricted stock, restricted stock units and performance share units. The dilutive effect is calculated through the application of (i) the if-converted method for convertible preferred stock, (ii) the treasury stock method for unvested stock awards and (iii) two-class method. During a period of net loss or negative undistributed earnings, the two-class method is not applicable.
Leases	Leases We recognize the following for all leases (with the exception of short-term leases) at the commencement date: • A lease liability, which is a lessee’s obligation to make lease payments arising from a lease. • A right-of-use asset, which is an asset that represents the lessee’s right to use, or control the use of, a specified asset for the lease term. We determine if an arrangement is or contains a lease at inception. Leases with an initial term of twelve months or less are considered short-term leases, which are excluded from the balance sheet. Right-of-use assets and lease liabilities are recognized at the commencement date based on the present value of future lease payments over the lease term. The right-of-use asset also includes any lease prepayments and excludes lease incentives. As most of the Company’s leases do not provide an implicit interest rate, we use our incremental borrowing rate as the discount rate to compute the present value of our lease liability. The discount rate applied is determined based on information available on the date of adoption for all leases existing as of that date, and on the date of lease commencement for all subsequent leases. Our lease arrangements may include variable lease payments based on an index or market rate, or may be based on performance. For variable lease payments based on an index or market rate, we estimate and apply a rate based on information available at the commencement date. Variable lease payments based on performance are excluded from the calculation of the right-of-use asset and lease liability, and are recognized in our Consolidated Statements of Operations when the contingency underlying such variable lease payments is resolved. Our lease terms may include options to extend or terminate the lease. Such options are included in the measurement of our right-of-use asset and liability, provided we determine that we are reasonably certain to exercise the option.
Recent Accounting Pronouncements	Recent Accounting Pronouncements Recently Adopted Accounting Pronouncements Supplier Finance Programs In September 2022, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2022-04, Liabilities—Supplier Finance Programs (Subtopic 405-50). Amendments in this update require annual and interim disclosure of the key terms of outstanding supplier finance programs and a rollforward of the related obligations. These amendments do not affect the recognition, measurement or financial statement presentation of the supplier finance program obligations. These amendments are effective for fiscal years beginning after December 15, 2022, except for the rollforward requirements, which are effective for fiscal years beginning after December 15, 2023. We maintain a supply chain finance program that allows participating suppliers to request early payment from a third-party financial institution of invoices that we confirm as valid. Under this program, we make payments in full to the third-party financial institution for the prior month’s outstanding balance within 15 days. The outstanding balance at the end of each reporting period is included in Accounts payable on our Consolidated Balance Sheets. We adopted the amendments on January 1, 2023, with no material impact on our consolidated financial statements. Recently issued accounting pronouncements not yet adopted Improvements to Reportable Segment Disclosures In November 2023, the FASB issued ASU 2023-07, Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures. The amendments in this update require, among other items, that public entities disclose, on an annual and interim basis, significant segment expenses that are regularly provided to the chief operating decision maker (“CODM”) and included within each reported measure of segment profit or loss. Additionally, the amendments require annual disclosure of the title and position of the CODM and how that individual uses the reported measure(s) of segment profit or loss in assessing segment performance and how to allocate resources. These amendments are effective for fiscal years beginning after December 15, 2023, and for interim periods within fiscal years beginning after December 15, 2024, with early adoption permitted. The disclosures required in the amendments apply retrospectively to all prior periods presented in the financial statements. We are evaluating the effect of the amendments on our consolidated financial statements and expect to disclose the required information for fiscal years beginning in the Annual Report on Form 10-K for the year ended December 31, 2024 and for interim periods beginning in the Quarterly Report on Form 10-Q for the quarter ended March 31, 2025. Improvements to Income Tax Disclosures In December 2023, the FASB issued ASU 2023-09, Income Taxes (Topic 740): Improvements to Income Tax Disclosures. The amendments in this update require, among other items, that public entities disclose, on an annual and interim basis, (i) specific categories of income taxes in the rate reconciliation, and (ii) a disaggregation of income taxes paid by federal, state, and foreign taxes. These amendments are effective for fiscal years beginning after December 15, 2024, with early adoption permitted. The amendments are required to be applied prospectively with retrospective application permitted. We are evaluating the effect of the amendments on our consolidated financial statements and expect to disclose the required information beginning in the Annual Report on Form 10-K for the year ended December 31, 2025.

Acquisitions and Divestitures (

Acquisitions and Divestitures (Tables)	12 Months Ended
	Dec. 31, 2023
Business Combinations [Abstract]
Summary of Preliminary Fair Values Assigned to Assets Acquired and Liabilities Assumed	The following table summarizes the purchase price allocation based on the final fair values assigned to assets acquired and liabilities assumed (in millions): Cash and cash equivalents $ 9.9 Trade receivables, net of allowances (1) 211.0 Other current assets 3.5 Property, plant and equipment, net 1,669.0 Intangible assets, net 1,882.0 Other long-term assets 57.3 Current liabilities ( 236.7 ) Other long-term liabilities ( 100.7 ) Purchase price $ 3,495.3 (1) The fair value of the assets acquired included trade receivables of $ 211.0 million. The gross amount due under contract was $ 213.4 million, of which $ 2.4 million was expected to be uncollectible. Trade receivables, net of allowances, excluded $ 18.5 million that was due from Targa. We reflected this settlement of a preexisting relationship as a reduction of the purchase price in accordance with ASC 805.
Schedule of Unaudited Pro Forma Financial Information	The following unaudited pro forma summary presents the consolidated results of operations for the years ended December 31, 2022 and 2021 as if the Delaware Basin Acquisition had occurred on January 1, 2021. The unaudited pro forma financial information is presented for informational purposes only and is not necessarily indicative of our results of operations that would have occurred had the transaction been consummated at the beginning of the period presented, nor is it necessarily indicative of future results. Year Ended December 31, 2022 2021 Revenues $ 21,268.9 $ 17,464.7 Net income (loss) 1,477.4 215.7

Property, Plant and Equipment_2

Property, Plant and Equipment and Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2023
Property Plant And Equipment And Intangible Assets [Abstract]
Property Plant and Equipment and Intangible Assets	Property, Plant and Equipment and Intangible Assets December 31, 2023 December 31, 2022 Estimated Useful Lives (In Years) Gathering systems $ 10,858.3 $ 10,403.1 5 to 20 Processing and fractionation facilities 8,285.5 7,421.2 5 to 25 Terminaling and storage facilities 1,403.9 1,341.6 5 to 25 Transportation assets 3,294.0 2,919.3 10 to 50 Other property, plant and equipment 430.5 387.6 3 to 50 Land 185.0 163.3 — Construction in progress 1,456.1 1,011.0 — Finance lease right-of-use assets 351.9 266.1 5 to 14 Property, plant and equipment 26,265.2 23,913.2 Accumulated depreciation, amortization and impairment ( 10,458.8 ) ( 9,698.6 ) Property, plant and equipment, net $ 15,806.4 $ 14,214.6 Intangible assets 4,378.0 4,379.7 10 to 20 Accumulated amortization and impairment ( 2,027.4 ) ( 1,645.1 ) Intangible assets, net $ 2,350.6 $ 2,734.6
Schedule of Changes in Intangible Assets	The changes in our intangible assets are as follows: December 31, 2023 December 31, 2022 Balance at beginning of period $ 2,734.6 $ 1,094.8 Additions from Delaware Basin Acquisition — 1,882.0 Amortization ( 384.0 ) ( 242.2 ) Balance at end of period $ 2,350.6 $ 2,734.6

Goodwill (Tables)

Goodwill (Tables)	12 Months Ended
	Dec. 31, 2023
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule of Goodwill	December 31, 2023 December 31, 2022 Permian Midland $ 23.2 $ 23.2 Permian Delaware 22.0 22.0 Goodwill $ 45.2 $ 45.2

Investments in Unconsolidated_2

Investments in Unconsolidated Affiliates (Tables)	12 Months Ended
	Dec. 31, 2023
Equity Method Investments and Joint Ventures [Abstract]
Activity Related to Partnership's Investments and Combined Financial Information in Unconsolidated Affiliates	The following table shows the activity related to our investments in unconsolidated affiliates: Balance at December 31, 2020 Equity Earnings (Loss) Cash Distributions Disposition/ Contributions Balance at December 31, 2021 GCX $ 435.2 $ 63.4 $ ( 78.1 ) $ — $ 0.5 $ 421.0 Little Missouri 4 104.7 10.9 ( 17.5 ) — — 98.1 T2 Eagle Ford 79.8 ( 57.0 ) ( 1.0 ) — 0.1 21.9 T2 LaSalle 39.6 ( 35.0 ) ( 0.4 ) — — 4.2 GCF (1) 38.5 ( 8.6 ) ( 1.1 ) — — 28.8 Cayenne 16.2 2.4 ( 6.1 ) — — 12.5 Total $ 714.0 $ ( 23.9 ) $ ( 104.2 ) $ — $ 0.6 $ 586.5 Balance at December 31, 2021 Equity Earnings (Loss) Cash Distributions Disposition/ Contributions Balance at December 31, 2022 GCX $ 421.0 $ 5.7 $ ( 14.3 ) $ ( 412.4 ) $ — $ — Little Missouri 4 98.1 5.5 ( 12.9 ) — — 90.7 GCF (1) 28.8 ( 3.2 ) — — 1.5 27.1 T2 Eagle Ford (2) 21.9 ( 0.6 ) ( 0.8 ) ( 20.5 ) — — T2 LaSalle (2) 4.2 ( 0.3 ) — ( 3.9 ) — — Cayenne 12.5 2.0 ( 1.0 ) — — 13.5 Total $ 586.5 $ 9.1 $ ( 29.0 ) $ ( 436.8 ) $ 1.5 $ 131.3 Balance at December 31, 2022 Equity Earnings (Loss) Cash Distributions Disposition/ Contributions Balance at December 31, 2023 Little Missouri 4 $ 90.7 $ 7.7 $ ( 11.3 ) $ — $ — $ 87.1 GCF (1) 27.1 ( 4.1 ) ( 2.0 ) — 24.6 45.6 Cayenne 13.5 5.4 ( 5.3 ) — — 13.6 Total $ 131.3 $ 9.0 $ ( 18.6 ) $ — $ 24.6 $ 146.3 (1) In January 2021, the GCF facility was temporarily idled and Targa assumed operatorship in the first half of 2021. In January 2023, we reached an agreement with our partners to reactivate the GCF facility. The facility is expected to be operational in the second quarter of 2024. (2) Following the closing of the South Texas Acquisition in April 2022, the T2 Joint Ventures are 100 % owned and consolidated by Targa.

Debt Obligations (Tables)

Debt Obligations (Tables)	12 Months Ended
	Dec. 31, 2023
Debt Disclosure [Abstract]
Schedule of Outstanding Debt	December 31, 2023 December 31, 2022 Current: Partnership accounts receivable securitization facility, due August 2024 (1) $ 575.0 $ 800.0 Finance lease liabilities 45.7 34.3 Current debt obligations 620.7 834.3 Long-term: Term loan facility, variable rate, due July 2025 500.0 1,500.0 TRGP senior revolving credit facility, variable rate, due February 2027 (2) 175.0 1,298.7 Senior unsecured notes issued by TRGP: 5.200 % fixed rate, due July 2027 750.0 750.0 6.150 % fixed rate, due March 2029 1,000.0 — 4.200 % fixed rate, due February 2033 750.0 750.0 6.125 % fixed rate, due March 2033 900.0 — 6.500 % fixed rate, due March 2034 1,000.0 — 4.950 % fixed rate, due April 2052 750.0 750.0 6.250 % fixed rate, due July 2052 500.0 500.0 6.500 % fixed rate, due February 2053 850.0 — Unamortized discount ( 29.5 ) ( 8.4 ) Senior unsecured notes issued by the Partnership: (3) 6.500 % fixed rate, due July 2027 705.2 705.2 5.000 % fixed rate, due January 2028 700.3 700.3 6.875 % fixed rate, due January 2029 679.3 679.3 5.500 % fixed rate, due March 2030 949.6 949.6 4.875 % fixed rate, due February 2031 1,000.0 1,000.0 4.000 % fixed rate, due January 2032 1,000.0 1,000.0 12,179.9 10,574.7 Debt issuance costs, net of amortization ( 90.8 ) ( 65.6 ) Finance lease liabilities 244.1 193.0 Long-term debt 12,333.2 10,702.1 Total debt obligations $ 12,953.9 $ 11,536.4 Irrevocable standby letters of credit: (2) Letters of credit outstanding under the TRGP senior revolving credit facility $ 22.3 $ 33.2 (1) As of December 31, 2023, the Partnership had $ 575.0 million of qualifying receivables under its $ 600.0 million accounts receivable securitization facility (the “Securitization Facility”), resulting in $ 25.0 million of availability. (2) We maintain an unsecured commercial paper note program (the “Commercial Paper Program”), the borrowings of which are supported through maintaining a minimum available borrowing capacity under the TRGP Revolver equal to the aggregate amount outstanding under the Commercial Paper Program. As of December 31, 2023 , the TRGP Revolver had no borrowings outstanding and the Commercial Paper Program had $ 175.0 million borrowings outstanding, resulting in approximately $ 2.6 billion of available liquidity, after accounting for outstanding letters of credit. (3) As of February 2022, we guarantee all of the Partnership’s outstanding senior unsecured notes.
Range of Interest Rates and Weighted Average Interest Rate Incurred on Variable Rate Debt Obligations	The following table shows the range of interest rates and weighted average interest rate incurred on our variable-rate debt obligations during the year ended December 31, 2023: Range of Interest Rates Incurred Weighted Average Interest Rate Incurred TRGP Revolver and Commercial Paper Program 5.2 % - 6.2 % 5.9 % Securitization Facility 5.2 % - 6.3 % 5.8 % Term Loan Facility 5.8 % - 6.8 % 6.5 %

Other Long-term Liabilities (Ta

Other Long-term Liabilities (Tables)	12 Months Ended
	Dec. 31, 2023
Other Liabilities, Noncurrent [Abstract]
Schedule of Other Long-term Liabilities	Other long-term liabilities are comprised of the following obligations: December 31, 2023 December 31, 2022 Deferred revenue $ 248.8 $ 198.8 Asset retirement obligations 103.0 97.9 Operating lease liabilities 56.5 28.6 Other liabilities 6.8 15.9 Total other long-term liabilities $ 415.1 $ 341.2
Components of deferred revenue	The following table shows the components of deferred revenue: December 31, 2023 December 31, 2022 Splitter agreement $ 129.0 $ 129.0 Gas contract amendment 29.8 32.3 Contributions in aid of construction (1) 86.4 31.7 Other 3.6 5.8 Total deferred revenue $ 248.8 $ 198.8 (1) Increase in contributions in aid of construction was due to additions of deferred revenue in West Texas and Badlands.
Changes in Deferred revenue	The following table shows the changes in deferred revenue: 2023 2022 Balance at beginning of period $ 198.8 $ 171.8 Additions 67.4 34.5 Revenue recognized ( 17.4 ) ( 7.5 ) Balance at end of period $ 248.8 $ 198.8
Changes in Aggregate Asset Retirement Obligations	The changes in our ARO are as follows: 2023 2022 Beginning of period $ 97.9 $ 72.1 Additions (1) — 20.2 Accretion expense 5.9 4.8 Change in cash flow estimate 4.9 0.8 Retirements ( 5.7 ) — End of period $ 103.0 $ 97.9 (1) Amount reflects additions of ARO in 2022 related to the Delaware Basin Acquisition.

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2023
Leases [Abstract]
Summary of Balances of Right of Use Assets and Liabilities of Finance Leases and Operating Leases	The balances of right-of-use assets and liabilities of finance leases and operating leases, and their locations on our Consolidated Balance Sheets are as follows: December 31, Balance Sheet Location 2023 2022 Right-of-use assets Operating leases, gross Other long-term assets $ 101.1 $ 57.3 Finance leases, gross (1) Property, plant and equipment 351.9 266.1 Lease liabilities Current: Operating leases Accrued liabilities $ 21.8 $ 14.4 Finance leases (1) Current debt obligations 45.7 34.3 Non-current: Operating leases Other long-term liabilities $ 56.5 $ 28.6 Finance leases (1) Long-term debt 244.1 193.0 (1) The December 31, 2022 balance includes $ 171.2 million of assets and $ 167.0 million of liabilities related to compressor leases from the Delaware Basin Acquisition that were subsequently amended and extended.
Summary of Components of Lease Expense	Operating lease costs and short-term lease costs are included in Operating expenses or General and administrative expense in our Consolidated Statements of Operations, depending on the nature of the leases. Finance lease costs are included in Depreciation and amortization expense and Interest expense, net in our Consolidated Statements of Operations. The components of lease expense were as follows: Year Ended December 31, 2023 2022 2021 Lease cost Operating lease cost $ 18.3 $ 17.7 $ 12.2 Short-term lease cost 56.7 35.0 20.4 Variable lease cost 26.0 17.9 5.7 Finance lease cost Amortization of right-of-use assets 48.2 20.3 13.3 Interest expense 14.0 3.5 1.1 Total lease cost $ 163.2 $ 94.4 $ 52.7
Summary of Other Supplemental Information Related to Leases	Other supplemental information related to our leases are as follows: Year Ended December 31, 2023 2022 2021 Cash paid for amounts included in the measurement of lease liabilities Operating cash flows for operating leases $ 21.4 $ 18.8 $ 14.1 Operating cash flows for finance leases 13.9 2.7 1.0 Financing cash flows for finance leases 42.9 19.7 12.5
Summary of Maturities of Lease Liabilities Under Non-cancellable Leases	The following table presents the maturities of our lease liabilities under non-cancellable leases as of December 31, 2023: Operating Leases Finance Leases 2024 $ 25.5 $ 57.5 2025 16.8 56.5 2026 11.2 55.0 2027 10.3 48.9 2028 10.1 41.4 Thereafter 14.4 72.8 Total undiscounted cash flows 88.3 332.1 Less imputed interest ( 10.0 ) ( 42.3 ) Total lease liabilities $ 78.3 $ 289.8

Common Stock and Related Matt_2

Common Stock and Related Matters (Tables)	12 Months Ended
	Dec. 31, 2023
Class of Stock Disclosures [Abstract]
Dividends Declared and/or Paid	The following table details the dividends declared and/or paid by us to common shareholders for the years ended December 31, 2023, 2022 and 2021: Three Months Ended Date Paid or Total Common Amount of Common Dividends on Dividends Declared per Share of Common Stock (In millions, except per share amounts) 2023 December 31, 2023 February 15, 2024 $ 112.8 $ 111.6 $ 1.2 $ 0.50000 September 30, 2023 November 15, 2023 113.0 111.5 1.5 0.50000 June 30, 2023 August 15, 2023 113.6 111.8 1.8 0.50000 March 31, 2023 May 15, 2023 114.7 113.0 1.7 0.50000 2022 December 31, 2022 February 15, 2023 $ 80.5 $ 79.3 $ 1.2 $ 0.35000 September 30, 2022 November 15, 2022 80.5 79.2 1.3 0.35000 June 30, 2022 August 15, 2022 80.7 79.3 1.4 0.35000 March 31, 2022 May 16, 2022 81.2 79.8 1.4 0.35000 2021 December 31, 2021 February 15, 2022 $ 81.4 $ 80.1 $ 1.3 $ 0.35000 September 30, 2021 November 15, 2021 23.3 22.9 0.4 0.10000 June 30, 2021 August 16, 2021 23.3 22.9 0.4 0.10000 March 31, 2021 May 14, 2021 23.3 22.9 0.4 0.10000

Earnings per Common Share (Tabl

Earnings per Common Share (Tables)	12 Months Ended
	Dec. 31, 2023
Earnings Per Share [Abstract]
Reconciliation of Net Income and Weighted Average Shares Outstanding Used in Computing Basic and Diluted Net Income Per Common Share	The following table sets forth a reconciliation of net income and weighted average shares outstanding used in computing basic and diluted net income per common share: Year Ended December 31, 2023 2022 2021 (In millions, except per share amounts) Net income (loss) attributable to Targa Resources Corp. $ 1,345.9 $ 1,195.5 $ 71.2 Less: Premium on repurchase of noncontrolling interests, net of tax (1) 510.1 53.2 — Less: Dividends on Series A Preferred Stock (2) — 30.0 87.3 Less: Deemed dividends on Series A Preferred (3) — 215.5 — Net income (loss) attributable to common shareholders 835.8 896.8 ( 16.1 ) Less: Participating share-based earnings (4) 7.6 — — Net income (loss) allocated to common shareholders for basic earnings per share $ 828.2 $ 896.8 $ ( 16.1 ) Weighted average shares outstanding - basic 224.6 227.3 228.6 Dilutive effect of unvested stock awards (5) 1.4 3.8 — Weighted average shares outstanding - diluted 226.0 231.1 228.6 Net income (loss) available per common share - basic $ 3.69 $ 3.95 $ ( 0.07 ) Net income (loss) available per common share - diluted $ 3.66 $ 3.88 $ ( 0.07 ) (1) Represents premium paid on the Grand Prix Transaction, Carnero Acquisition and the DevCo JV Repurchase. See Note 4 – Acquisitions and Divestitures . (2) Includes $ 8.2 million attributable to the dividends paid upon the full redemption of Series A Preferred in 2022. (3) Includes $ 215.5 million attributable to the full redemption of Series A Preferred in 2022. See Note 11 – Preferred Stock for further discussion. (4) Represents the distributed and undistributed earnings of the Company attributable to the participating securities. The dilutive effect of the reallocation of participating securities to diluted net income attributable to common shareholders was immaterial. (5) For the year ended December 31, 2021, all unvested restricted stock awards and Series A Preferred were antidilutive because a net loss existed in the period.
Summary of Potential Common Stock Equivalents Excluded from Determination of Diluted Earnings Per Share	The following potential common stock equivalents are excluded from the determination of diluted earnings per share because the inclusion of such shares would have been anti-dilutive (in millions on a weighted-average basis): Year Ended December 31, 2023 2022 2021 Unvested restricted stock awards 1.5 — 3.3 Series A Preferred (1) — 14.9 44.3

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2023
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Notional Volume of Commodity Hedges	At December 31, 2023, the notional volumes of our commodity derivative contracts were: Commodity Instrument Unit 2024 2025 2026 2027 Natural Gas Swaps MMBtu/d 107,242 58,179 14,297 — Natural Gas Basis Swaps MMBtu/d 478,374 256,658 122,500 35,000 NGL Swaps Bbl/d 31,893 21,354 5,589 — NGL Futures Bbl/d 14,511 4,767 — — Condensate Swaps Bbl/d 4,531 3,447 1,092 —
Fair Values of Derivative Instruments	The following schedules reflect the fair value of our derivative instruments and their location on our Consolidated Balance Sheets as well as pro forma reporting assuming that we reported derivatives subject to master netting agreements on a net basis: Fair Value as of December 31, 2023 Fair Value as of December 31, 2022 Balance Sheet Derivative Derivative Derivative Derivative Location Assets Liabilities Assets Liabilities Derivatives designated as hedging instruments Commodity contracts Current $ 103.5 $ ( 16.4 ) $ 158.7 $ ( 93.8 ) Long-term 29.0 ( 3.0 ) 24.2 ( 30.9 ) Total derivatives designated as hedging instruments $ 132.5 $ ( 19.4 ) $ 182.9 $ ( 124.7 ) Derivatives not designated as hedging instruments Commodity contracts Current $ 8.4 $ ( 37.6 ) $ 21.2 $ ( 226.3 ) Long-term 4.3 ( 13.8 ) 0.3 ( 109.2 ) Total derivatives not designated as hedging instruments $ 12.7 $ ( 51.4 ) $ 21.5 $ ( 335.5 ) Total current position $ 111.9 $ ( 54.0 ) $ 179.9 $ ( 320.1 ) Total long-term position 33.3 ( 16.8 ) 24.5 ( 140.1 ) Total derivatives $ 145.2 $ ( 70.8 ) $ 204.4 $ ( 460.2 )
Pro Forma Impact of Derivatives Net in Consolidated Balance Sheet	The pro forma impact of reporting derivatives on our Consolidated Balance Sheets on a net basis is as follows: Gross Presentation Pro Forma Net Presentation December 31, 2023 Asset Liability Collateral Asset Liability Current Position Counterparties with offsetting positions or collateral $ 111.7 $ ( 54.0 ) $ 3.6 $ 69.2 $ ( 7.9 ) Counterparties without offsetting positions - assets 0.2 — — 0.2 — Counterparties without offsetting positions - liabilities — — — — — 111.9 ( 54.0 ) 3.6 69.4 ( 7.9 ) Long-Term Position Counterparties with offsetting positions or collateral 31.7 ( 16.8 ) ( 0.1 ) 17.0 ( 2.2 ) Counterparties without offsetting positions - assets 1.6 — — 1.6 — Counterparties without offsetting positions - liabilities — — — — — 33.3 ( 16.8 ) ( 0.1 ) 18.6 ( 2.2 ) Total Derivatives Counterparties with offsetting positions or collateral 143.4 ( 70.8 ) 3.5 86.2 ( 10.1 ) Counterparties without offsetting positions - assets 1.8 — — 1.8 — Counterparties without offsetting positions - liabilities — — — — — $ 145.2 $ ( 70.8 ) $ 3.5 $ 88.0 $ ( 10.1 ) Gross Presentation Pro Forma Net Presentation December 31, 2022 Asset Liability Collateral Asset Liability Current Position Counterparties with offsetting positions or collateral $ 162.2 $ ( 316.7 ) $ 12.2 $ 27.2 $ ( 169.5 ) Counterparties without offsetting positions - assets 17.7 — — 17.7 — Counterparties without offsetting positions - liabilities — ( 3.4 ) — — ( 3.4 ) 179.9 ( 320.1 ) 12.2 44.9 ( 172.9 ) Long-Term Position Counterparties with offsetting positions or collateral 24.5 ( 137.4 ) 22.4 7.3 ( 97.8 ) Counterparties without offsetting positions - assets — — — — — Counterparties without offsetting positions - liabilities — ( 2.7 ) — — ( 2.7 ) 24.5 ( 140.1 ) 22.4 7.3 ( 100.5 ) Total Derivatives Counterparties with offsetting positions or collateral 186.7 ( 454.1 ) 34.6 34.5 ( 267.3 ) Counterparties without offsetting positions - assets 17.7 — — 17.7 — Counterparties without offsetting positions - liabilities — ( 6.1 ) — — ( 6.1 ) $ 204.4 $ ( 460.2 ) $ 34.6 $ 52.2 $ ( 273.4 )
Amounts Recorded in Other Comprehensive Income and Amounts Reclassified from OCI to Revenue	The following tables reflect amounts recorded in OCI and amounts reclassified from OCI to revenue for the periods indicated: Derivatives in Cash Flow Gain (Loss) Recognized in OCI on Derivatives (Effective Portion) Hedging Relationships 2023 2022 2021 Commodity contracts $ 193.4 $ ( 5.6 ) $ ( 534.6 ) Gain (Loss) Reclassified from OCI into Income (Effective Portion) Location of Gain (Loss) 2023 2022 2021 Revenues $ 153.4 $ ( 373.0 ) $ ( 417.3 )
Gain (Loss) Recognized in Income on Derivatives	The use of mark-to-market accounting for financial assets and liabilities (“financial instruments”) can cause non-cash earnings volatility due to changes in the underlying commodity price indices. For the year ended December 31, 2023, the unrealized mark-to-market gains are primarily attributable to favorable movements in natural gas forward basis prices, as compared to our positions. Derivatives Not Designated Location of Gain (Loss) Recognized in Gain (Loss) Recognized in Income on Derivatives as Hedging Instruments Income on Derivatives 2023 2022 2021 Commodity contracts Revenue $ 287.7 $ ( 381.7 ) $ ( 73.3 )

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2023
Fair Value Disclosures [Abstract]
Breakdown by Fair Value Hierarchy Category for Financial Instruments Included in Consolidated Balance Sheets	The following table shows a breakdown by fair value hierarchy category for (i) financial instruments measurements included on our Consolidated Balance Sheets at fair value and (ii) supplemental fair value disclosures for other financial instruments: December 31, 2023 Carrying Fair Value Value Total Level 1 Level 2 Level 3 Financial Instruments Recorded on Our Assets from commodity derivative contracts (1) $ 144.6 $ 144.6 $ — $ 144.6 $ — Liabilities from commodity derivative contracts (1) 70.2 70.2 — 70.2 Financial Instruments Recorded on Our Cash and cash equivalents 141.7 141.7 — — — TRGP Revolver and Commercial Paper Program 175.0 175.0 — 175.0 — TRGP Senior unsecured notes 6,470.5 6,598.7 — 6,598.7 — Term Loan Facility 500.0 500.0 — 500.0 — Partnership’s Senior unsecured notes 5,034.4 4,945.1 — 4,945.1 — Securitization Facility 575.0 575.0 — 575.0 — December 31, 2022 Carrying Fair Value Value Total Level 1 Level 2 Level 3 Financial Instruments Recorded on Our Assets from commodity derivative contracts (1) $ 201.6 $ 201.6 $ — $ 201.6 $ — Liabilities from commodity derivative contracts (1) 457.4 457.4 — 457.4 — Financial Instruments Recorded on Our Cash and cash equivalents 219.0 219.0 — — — TRGP Revolver and Commercial Paper Program 1,298.7 1,298.7 — 1,298.7 — TRGP Senior unsecured notes 2,741.6 2,452.6 — 2,452.6 — Term Loan Facility 1,500.0 1,500.0 — 1,500.0 — Partnership’s Senior unsecured notes 5,034.4 4,711.3 — 4,711.3 — Securitization Facility 800.0 800.0 — 800.0 — (1) The fair value of derivative contracts in this table is presented on a different basis than the Consolidated Balance Sheets presentation as disclosed in Note 14 – Derivative Instruments and Hedging Activities. The above fair values reflect the total value of each derivative contract taken as a whole, whereas the Consolidated Balance Sheets presentation is based on the individual maturity dates of estimated future settlements. As such, an individual contract could have both an asset and liability position when segregated into its current and long-term portions for Consolidated Balance Sheets classification purposes .

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2023
Related Party Transactions [Abstract]
Summary of Transactions with Unconsolidated Affiliates	The following table summarizes transactions with unconsolidated affiliates: GCF T2 Joint Ventures (1) Cayenne GCX (2) Little Missouri 4 Total 2023: Revenues $ — $ — $ — $ — $ 7.1 $ 7.1 Product purchases and fuel — — ( 6.4 ) — — ( 6.4 ) Operating expenses ( 4.4 ) — ( 0.3 ) — ( 2.0 ) ( 6.7 ) General and administrative expenses — — — — ( 0.9 ) ( 0.9 ) 2022: Revenues $ — $ 1.2 $ — $ — $ 8.5 $ 9.7 Product purchases and fuel — — ( 4.7 ) ( 25.0 ) — ( 29.7 ) Operating expenses ( 1.7 ) ( 0.7 ) ( 0.3 ) — ( 2.6 ) ( 5.3 ) General and administrative expenses — — — — ( 0.9 ) ( 0.9 ) 2021: Revenues $ — $ 4.4 $ — $ — $ 10.6 $ 15.0 Product purchases and fuel — — ( 4.8 ) ( 66.5 ) — ( 71.3 ) Operating expenses ( 1.1 ) ( 2.3 ) ( 0.2 ) — ( 2.5 ) ( 6.1 ) General and administrative expenses — — — — ( 0.8 ) ( 0.8 ) (1) Following the closing of the South Texas Acquisition in April 2022, the T2 Joint Ventures are 100 % owned and consolidated by Targa. (2) Following the closing of the GCX Sale in May 2022, Targa no longer has an ownership interest in GCX.

Commitments (Tables)

Commitments (Tables)	12 Months Ended
	Dec. 31, 2023
Leases [Abstract]
Total Expenses on Non-Cancelable Commitments	Total expenses incurred under the above non-cancelable commitments were: 2023 2022 2021 Land sites and rights of way $ 9.0 $ 5.8 $ 5.9
Schedule of Contractual Maturities of Outstanding Debt Obligations	Future non-cancelable commitments related to certain contractual obligations are presented below for each of the next five fiscal years and in aggregate thereafter: In Aggregate 2024 2025 2026 2027 2028 Thereafter Land sites and rights of way (1) $ 297.4 $ 8.5 $ 8.6 $ 10.3 $ 11.7 $ 17.3 $ 241.0 (1) Land site lease and rights of way provides for surface and underground access for gathering, processing and distribution assets that are located on property not owned by us. These agreements expire at various dates, with varying terms, some of which are perpetual.

Revenue (Tables)

Revenue (Tables)	12 Months Ended
	Dec. 31, 2023
Revenue from Contract with Customer [Abstract]
Summary of Estimated Minimum Revenue Expected to be Recognized in Future Related to Unsatisfied Performance Obligations	The following table presents the estimated minimum revenue related to unsatisfied performance obligations at the end of the reporting period, and is comprised of fixed consideration primarily attributable to contracts with minimum volume commitments, for which a guaranteed amount of revenue can be calculated. These contracts are comprised primarily of gathering and processing, fractionation, export, terminaling and storage agreements, with remaining contract terms ranging from 1 to 16 years . 2024 2025 2026 and after Fixed consideration to be recognized as of December 31, 2023 $ 497.2 $ 419.8 $ 2,383.3

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2023
Income Tax Disclosure [Abstract]
Components of Federal and State Income Tax Provisions	Components of the federal and state income tax provisions are as follows: 2023 2022 2021 Current expense (benefit) $ 13.6 $ 6.7 $ 2.7 Deferred expense (benefit) 349.6 125.1 12.1 Total income tax expense (benefit) $ 363.2 $ 131.8 $ 14.8
Deferred Tax Assets and Liabilities	Our deferred income tax assets and liabilities as of December 31, 2023 and 2022 consist of recognition differences related to certain types of costs as follows: 2023 2022 Deferred tax assets: Net operating loss $ 1,282.9 $ 1,568.5 Disallowed business interest expense carryforward 79.3 10.3 Deferred tax assets before valuation allowance 1,362.2 1,578.8 Valuation allowance ( 7.1 ) ( 36.9 ) Deferred tax assets 1,355.1 1,541.9 Deferred tax liabilities: Investments (1) ( 1,867.9 ) ( 1,842.0 ) Property, plant, and equipment ( 3.0 ) ( 4.2 ) Other ( 20.0 ) ( 23.4 ) Deferred tax liabilities ( 1,890.9 ) ( 1,869.6 ) Net deferred tax asset (liability) $ ( 535.8 ) $ ( 327.7 ) Net deferred tax asset (liability) Federal $ ( 507.0 ) $ ( 290.5 ) State ( 28.8 ) ( 37.2 ) Long-term deferred tax liability, net $ ( 535.8 ) $ ( 327.7 ) (1) Our deferred tax liability attributable to investments reflects the differences between the book and tax carrying values of our investment in the Partnership.
Reconciliation of Income Tax Provision (Benefit)	Set forth below is the reconciliation between our Income tax provision (benefit) computed at the United States statutory rate on income before income taxes and the income tax provision in our Consolidated Statements of Operations for the periods indicated: Income tax reconciliation: 2023 2022 2021 Income (loss) before income taxes $ 1,942.5 $ 1,663.2 $ 436.9 Less: Net income attributable to noncontrolling interest ( 233.4 ) ( 335.9 ) ( 350.9 ) Income attributable to Targa Resources Corp. before income taxes 1,709.1 1,327.3 86.0 Federal statutory income tax rate 21 % 21 % 21 % Provision for federal income taxes 358.9 278.7 18.1 Valuation allowance ( 29.8 ) ( 177.5 ) ( 46.2 ) State income taxes, net of federal tax benefit 37.8 33.6 ( 5.4 ) State tax provision error correction — — 23.3 Return-to-provision ( 5.7 ) ( 0.6 ) ( 1.3 ) Change in income tax rate 11.5 ( 1.7 ) 21.0 Permanent adjustments 6.2 5.6 4.1 Stock compensation shortfall/(windfall) ( 15.8 ) ( 6.3 ) 1.4 Other, net 0.1 — ( 0.2 ) Income tax provision (benefit) $ 363.2 $ 131.8 $ 14.8

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2023
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information	Year Ended December 31, 2023 2022 2021 Cash: Interest paid, net of capitalized interest (1) $ 618.6 $ 401.3 $ 356.0 Income taxes (received) paid, net 8.5 1.6 1.3 Non-cash investing activities: Change in deadstock commodity inventory $ ( 13.7 ) $ ( 3.8 ) $ ( 15.0 ) Impact of capital expenditure accruals on property, plant and equipment, net 58.2 60.1 53.0 Transfers from materials and supplies inventory to property, plant and equipment — — 2.4 Change in ARO liability and property, plant and equipment due to revised cash flow estimate and additions 4.9 0.8 ( 0.2 ) Non-cash financing activities: Changes in accrued distributions to noncontrolling interests $ 8.9 $ ( 26.1 ) $ ( 50.9 ) Reduction of owner's equity related to accrued dividends on unvested equity awards under share compensation arrangements 3.9 7.1 3.1 Non-cash distributions to noncontrolling interests (2) — 64.2 — Lease liabilities arising from recognition of right-of-use assets: Operating lease $ 53.1 $ 9.7 $ 20.1 Finance lease (3) 104.8 220.7 24.7 (1) Interest capitalized on major projects was $ 41.1 million, $ 16.3 million and $ 4.1 million for the years ended December 31, 2023, 2022 and 2021 . (2) Represents the transfer of an undivided interest in certain gas gathering and processing facilities to a joint owner upon Targa ’ s recovery of a specified payout amount for our initial full funding of the facilities. (3) The December 31, 2022 amount includes $ 171.2 million related to compressor leases from the Delaware Basin Acquisition that were subsequently amended and extended.

Compensation Plans (Tables)

Compensation Plans (Tables)	12 Months Ended
	Dec. 31, 2023
Restricted Stock Units (RSUs) [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Summary of Restricted Stock Awards	The following table summarizes the restricted stock and RSUs under the 2010 TRGP Plan in shares and in dollars for the year indicated. Number Weighted Average Outstanding at December 31, 2022 3,228,418 $ 42.60 Granted 610,844 78.52 Forfeited ( 95,643 ) 61.92 Vested ( 1,435,823 ) 32.05 Outstanding at December 31, 2023 2,307,796 57.84
PSUs [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Summary of Performance Share Units	The following table summarizes the PSUs under the 2010 TRGP Plan in shares and in dollars for the years indicated. Number Weighted Average Outstanding at December 31, 2022 769,917 $ 72.81 Granted 140,020 128.71 Forfeited ( 22,272 ) 117.52 Vested ( 291,365 ) 69.70 Outstanding at December 31, 2023 596,300 85.78

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2023
Segment Reporting [Abstract]
Reportable Segment Information	Reportable segment information is shown in the following tables: Year Ended December 31, 2023 Gathering and Processing Logistics and Transportation Other Corporate Total Revenues Sales of commodities $ 1,076.1 $ 12,610.5 $ 275.5 $ — $ 13,962.1 Fees from midstream services 1,366.5 731.7 — — 2,098.2 2,442.6 13,342.2 275.5 — 16,060.3 Intersegment revenues Sales of commodities 4,786.3 267.9 — ( 5,054.2 ) — Fees from midstream services 2.6 45.7 — ( 48.3 ) — 4,788.9 313.6 — ( 5,102.5 ) — Revenues $ 7,231.5 $ 13,655.8 $ 275.5 $ ( 5,102.5 ) $ 16,060.3 Operating margin (1) $ 2,082.2 $ 1,948.7 $ 275.5 Other financial information: Total assets (2) $ 12,685.2 $ 7,777.8 $ 4.2 $ 204.6 $ 20,671.8 Goodwill $ 45.2 $ — $ — $ — $ 45.2 Capital expenditures $ 1,514.7 $ 910.0 $ — $ 18.9 $ 2,443.6 Year Ended December 31, 2022 Gathering and Processing Logistics and Transportation Other Corporate Total Revenues Sales of commodities $ 919.7 $ 18,448.7 $ ( 302.4 ) $ — $ 19,066.0 Fees from midstream services 1,157.3 706.5 — — 1,863.8 2,077.0 19,155.2 ( 302.4 ) — 20,929.8 Intersegment revenues Sales of commodities 9,169.4 541.7 — ( 9,711.1 ) — Fees from midstream services 0.6 45.2 — ( 45.8 ) — 9,170.0 586.9 — ( 9,756.9 ) — Revenues $ 11,247.0 $ 19,742.1 $ ( 302.4 ) $ ( 9,756.9 ) $ 20,929.8 Operating margin (1) $ 1,981.0 $ 1,456.3 $ ( 302.4 ) Other financial information: Total assets (2) $ 12,133.6 $ 7,175.7 $ — $ 250.7 $ 19,560.0 Goodwill $ 45.2 $ — $ — $ — $ 45.2 Capital expenditures $ 918.1 $ 453.0 $ — $ 23.3 $ 1,394.4 Year Ended December 31, 2021 Gathering and Processing Logistics and Transportation Other Corporate Total Revenues Sales of commodities $ 606.8 $ 15,111.6 $ ( 115.9 ) $ — $ 15,602.5 Fees from midstream services 747.3 600.0 — — 1,347.3 1,354.1 15,711.6 ( 115.9 ) — 16,949.8 Intersegment revenues Sales of commodities 6,067.9 409.5 — ( 6,477.4 ) — Fees from midstream services 3.5 38.6 — ( 42.1 ) — 6,071.4 448.1 — ( 6,519.5 ) — Revenues $ 7,425.5 $ 16,159.7 $ ( 115.9 ) $ ( 6,519.5 ) $ 16,949.8 Operating margin (1) $ 1,325.3 $ 1,264.3 $ ( 115.9 ) Other financial information: Total assets (2) $ 7,998.1 $ 7,041.9 $ 14.0 $ 154.2 $ 15,208.2 Goodwill $ 45.2 $ — $ — $ — $ 45.2 Capital expenditures $ 471.7 $ 78.1 $ — $ 10.7 $ 560.5 (1) Operating margin is calculated by subtracting Product purchases and fuel and Operating expenses from Revenues. (2) Assets in the Corporate and Eliminations column primarily include tax-related assets, cash, prepaids and debt issuance costs for our revolving credit facilities.
Revenues Disaggregated by Product and Service	The following table shows our consolidated revenues disaggregated by product and service for the periods presented: Year Ended December 31, 2023 2022 2021 Sales of commodities: Revenue recognized from contracts with customers: Natural gas $ 2,421.3 $ 5,470.2 $ 3,523.9 NGL 10,580.2 13,785.2 12,210.8 Condensate and crude oil 519.5 565.3 358.4 13,521.0 19,820.7 16,093.1 Non-customer revenue: Derivative activities - Hedge 153.4 ( 373.0 ) ( 417.3 ) Derivative activities - Non-hedge (1) 287.7 ( 381.7 ) ( 73.3 ) 441.1 ( 754.7 ) ( 490.6 ) Total sales of commodities 13,962.1 19,066.0 15,602.5 Fees from midstream services: Revenue recognized from contracts with customers: Gathering and processing 1,342.8 1,137.2 730.3 NGL transportation, fractionation and services 261.1 285.1 190.6 Storage, terminaling and export 440.7 372.2 379.7 Other 53.6 69.3 46.7 Total fees from midstream services 2,098.2 1,863.8 1,347.3 Total revenues $ 16,060.3 $ 20,929.8 $ 16,949.8 (1) Represents derivative activities that are not designated as hedging instruments under ASC 815.
Reconciliation of Reportable Segment Operating Margin to Income (Loss) Before Income Taxes	The following table shows a reconciliation of reportable segment Operating margin to Income (loss) before income taxes for the periods presented: Year Ended December 31, 2023 2022 2021 Reconciliation of reportable segment operating Gathering and Processing operating margin $ 2,082.2 $ 1,981.0 $ 1,325.3 Logistics and Transportation operating margin 1,948.7 1,456.3 1,264.3 Other operating margin 275.5 ( 302.4 ) ( 115.9 ) Depreciation and amortization expense ( 1,329.6 ) ( 1,096.0 ) ( 870.6 ) General and administrative expense ( 348.7 ) ( 309.7 ) ( 273.2 ) Other operating income (expense) ( 1.5 ) ( 0.2 ) ( 12.4 ) Impairment of long-lived assets — — ( 452.3 ) Interest expense, net ( 687.8 ) ( 446.1 ) ( 387.9 ) Equity earnings (loss) 9.0 9.1 ( 23.9 ) Gain (loss) from financing activities ( 2.1 ) ( 49.6 ) ( 16.6 ) Gain (loss) from sale of equity method investment — 435.9 — Other, net ( 3.2 ) ( 15.1 ) 0.1 Income (loss) before income taxes $ 1,942.5 $ 1,663.2 $ 436.9

Significant Accounting Polici_3

Significant Accounting Policies (Details) - USD ($)	1 Months Ended	12 Months Ended
	Feb. 28, 2021	Dec. 31, 2023	Jul. 31, 2022
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Agreement description		Debt instruments are considered substantially different if the present value of the cash flows under the terms of the new debt instrument is at least 10 percent different from the present value of the remaining cash flows under the terms of the existing debt instrument. We consider changes in principal amounts, interest rates, and maturity dates of the existing and new instruments when evaluating the change in cash flows between the instruments.
Gain or loss on modification	$ (14,900,000)	$ 0
Upfront compensation		0
Cash payments related to transfer of assets		$ 0
Unvested Restricted Stock Units [Member]
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Unvested restricted stock, term		Our participating securities consist of unvested restricted stock units that vest no later than three years following grant date as well as certain four-year retention awards that participate in nonforfeitable dividends with the common equity owners.
Commercial Paper Program [Member]
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Agreement description		Under the terms of the Commercial Paper Program, we may issue, from time to time, unsecured commercial paper notes with varying maturities of less than one year.
Amount outstanding		$ 2,750,000,000	$ 2,750,000,000
Commercial Paper Program [Member] | Unsecured Commercial Paper Notes [Member]
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Agreement description		Under the terms of the unsecured commercial paper note program (the “Commercial Paper Program”), we may issue, from time to time, unsecured commercial paper notes with varying maturities of less than one year.
WestTex LLC [Member]
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Ownership interest		72.80%
Logistics and Transportation [Member] | Cedar Bayou Fractionators LP [Member]
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Ownership interest		88%
Logistics and Transportation [Member] | Train Seven [Member] | Targa Resources Partners Lp [Member]
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Ownership interest		80%
Logistics and Transportation [Member] | Cayenne Pipeline Limited Liability Company [Member] | Targa Resources Partners Lp [Member]
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Ownership interest		50%
Logistics and Transportation [Member] | Gulf Coast Fractionators [Member] | Targa Resources Partners Lp [Member]
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Ownership interest		38.80%
Gathering and Processing [Member] | Centrahoma Processing LLC [Member]
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Ownership interest		60%
Gathering and Processing [Member] | Targa Badland [Member]
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Ownership interest		55%
Gathering and Processing [Member] | Venice Energy Services [Member]
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Ownership interest		76.80%
Gathering and Processing [Member] | Cayenne Pipeline Limited Liability Company [Member] | Targa Resources Partners Lp [Member]
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Ownership interest		50%
Minimum [Member]
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Payment of commodities due period		10 days
Minimum [Member] | Unvested Restricted Stock Units [Member]
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Vesting period		3 years
Maximum [Member]
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Payment of commodities due period		30 days

Acquisitions and Divestitures -

Acquisitions and Divestitures - Additional Information Acquisitions (Details) $ in Millions, Bcf in Billions

1 Months Ended

3 Months Ended

5 Months Ended

12 Months Ended

Feb. 06, 2018 JointVenture

Dec. 31, 2023 USD ($)

Jan. 31, 2023 USD ($)

Jul. 31, 2022 USD ($) Miles Bcf

May 31, 2022 USD ($)

Apr. 30, 2022 USD ($) JointVenture

Jan. 31, 2022 USD ($)

Dec. 31, 2022 USD ($)

Dec. 31, 2022 USD ($)

Dec. 31, 2023 USD ($)

Dec. 31, 2022 USD ($)

Feb. 28, 2022

Business Acquisition [Line Items]

Repurchase of interest

$ 1,118.9

$ 926.3

Premium on repurchase of noncontrolling interests, net of tax

[1]

510.1

53.2

Debt issuance cost

$ 90.8

$ 65.6

$ 65.6

$ 90.8

65.6

Weighted average amortization period, intangible assets

11 years 4 months 24 days

South Texas Acquisition

Business Acquisition [Line Items]

Business acquisition, purchase price

$ 201.9

Business acquisition, purchase price closing adjustment

1.5

Number of operated joint ventures | JointVenture

2

Acquisition-related costs

$ 1.8

Amount of liabilities assumed

1.8

Purchase of interest in joint venture

28.1

Cost to property, plant and equipment

169.7

Cost to current assets and liabilities, net

3.9

Cost to other non-current assets

$ 5.3

Delaware Basin Acquisition

Business Acquisition [Line Items]

Business acquisition, purchase price

$ 3,500

Final net working capital adjustment payment received

$ 11.4

Acquisition-related costs

$ 14.4

Cost to property, plant and equipment

1,669

Cost to other non-current assets

57.3

Debt issuance cost

$ 1,500

Distance of natural gas pipelines | Miles

1,050

Natural gas processing capacity in service or under construction | Bcf

1.4

Estimated average useful life of property, plant and equipment

20 years

Weighted average amortization period, intangible assets

14 years

Finite-lived intangible assets acquired, discount rate

19%

Customer attrition rate

5%

Revenue attributable to the assets acquired from the date of acquisition

374.1

Revenue attributable to the assets acquired from the date of acquisition

$ 7.9

Debt instrument drawn amount

$ 800

Debt issuance costs

16.9

Delaware Basin Acquisition | Revolving Credit Facility [Member]

Business Acquisition [Line Items]

Debt instrument drawn amount

2,750

Delaware Basin Acquisition | 5.200% Senior Notes Due 2027 [Member]

Business Acquisition [Line Items]

Aggregate principal amount issued

$ 750

Interest rate on fixed rate debt

5.20%

Delaware Basin Acquisition | 6.250% Senior Notes Due 2052 [Member]

Business Acquisition [Line Items]

Aggregate principal amount issued

$ 500

Interest rate on fixed rate debt

6.25%

6.25%

6.25%

6.25%

Carnero G&P LLC [Member]

Business Acquisition [Line Items]

Ownership interest

50%

50%

Premium on repurchase of noncontrolling interests, net of tax

$ 20.1

Business acquisition, purchase price

$ 27

Blackstone Energy Partners

Business Acquisition [Line Items]

Ownership interest

25%

Ownership interest in assets

100%

Premium on repurchase of noncontrolling interests, net of tax

$ 489.4

Business acquisition, purchase price

1,050

Business acquisition, purchase price closing adjustment

$ 41.9

DevCo JV Repurchase [Member]

Business Acquisition [Line Items]

Repurchase of interest

$ 926.3

Premium on repurchase of noncontrolling interests, net of tax

$ 53.2

DevCo JV Repurchase [Member] | Grand Prix Joint Venture [Member]

Business Acquisition [Line Items]

Ownership interest

75%

Train 6 [Member] | DevCo JV Repurchase [Member]

Business Acquisition [Line Items]

Ownership interest in assets

100%

GCX DevCo JV [Member]

Business Acquisition [Line Items]

Ownership interest

25%

Repurchase of interest

$ 857

GCX DevCo JV [Member] | DevCo JV Repurchase [Member]

Business Acquisition [Line Items]

Ownership interest

25%

Train 6 DevCo JV [Member] | Train 6 [Member] | Mont Belvieu, Texas [Member]

Business Acquisition [Line Items]

Ownership interest in assets

110%

Stonepeak Infrastructure Partners [Member] | GCX DevCo JV [Member]

Business Acquisition [Line Items]

Number of development joint ventures | JointVenture

3

[1] Represents premium paid on the Grand Prix Transaction, Carnero Acquisition and the DevCo JV Repurchase. See Note 4 – Acquisitions and Divestitures

Acquisitions and Divestitures_2

Acquisitions and Divestitures - Summary of Preliminary Fair Values Assigned to Assets Acquired and Liabilities Assumed (Details) - Delaware Basin Acquisition [Member] $ in Millions	Jul. 31, 2022 USD ($)
Business Acquisition [Line Items]
Cash and cash equivalents	$ 9.9
Trade receivables, net of allowances	211	[1]
Other current assets	3.5
Property, plant and equipment, net	1,669
Intangible assets, net	1,882
Other long-term assets	57.3
Current liabilities	(236.7)
Other long-term liabilities	(100.7)
Purchase price	$ 3,495.3
[1] The fair value of the assets acquired included trade receivables of $ 211.0 million. The gross amount due under contract was $ 213.4 million, of which $ 2.4 million was expected to be uncollectible. Trade receivables, net of allowances, excluded $ 18.5 million that was due from Targa. We reflected this settlement of a preexisting relationship as a reduction of the purchase price in accordance with ASC 805.

Acquisitions and Divestitures_3

Acquisitions and Divestitures - Summary of Preliminary Fair Values Assigned to Assets Acquired and Liabilities Assumed (Parenthetical) (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022	Jul. 31, 2022
Business Acquisition [Line Items]
Trade receivables, net of allowances	$ 1,471	$ 1,408.4
Delaware Basin Acquisition [Member]
Business Acquisition [Line Items]
Fair value of the assets acquired includes trade receivables			$ 211
Gross amount due under contract			213.4
Expected to be uncollectible			2.4
Trade receivables, net of allowances			$ 18.5

Acquisitions and Divestitures_4

Acquisitions and Divestitures - Schedule of Unaudited Pro Forma Financial Information (Details) - Delaware Basin Acquisition [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Business Acquisition [Line Items]
Revenues	$ 21,268.9	$ 17,464.7
Net income (loss)	$ 1,477.4	$ 215.7

Acquisitions and Divestitures_5

Acquisitions and Divestitures - Additional Information Divestitures (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	May 31, 2022	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Assets And Liabilities Held For Sale [Line Items]
Gain (loss) on sale or disposal of assets		$ 5.3	$ 9.6	$ (2)
Proceeds from sale of assets		$ 4.7	23	$ 12.2
Gain (loss) from sale of equity-method investment			435.9
GCX DevCo JV [Member]
Assets And Liabilities Held For Sale [Line Items]
Subsidiary ownership interest sale percentage	25%
Repurchase of interest	$ 857
Gain (loss) from sale of equity-method investment			$ 435.9

Property, Plant and Equipment_3

Property, Plant and Equipment and Intangible Assets - Property, Plant and Equipment and Intangible Assets (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 26,265.2	$ 23,913.2
Accumulated depreciation, amortization and impairment	(10,458.8)	(9,698.6)
Property, plant and equipment, net	15,806.4	14,214.6
Intangible assets	4,378	4,379.7
Accumulated amortization and impairment	(2,027.4)	(1,645.1)
Intangible assets, net	$ 2,350.6	2,734.6	$ 1,094.8
Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	10 years
Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	20 years
Gathering Systems [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 10,858.3	10,403.1
Gathering Systems [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	5 years
Gathering Systems [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	20 years
Processing and Fractionation Facilities [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 8,285.5	7,421.2
Processing and Fractionation Facilities [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	5 years
Processing and Fractionation Facilities [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	25 years
Terminaling and Storage Facilities [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 1,403.9	1,341.6
Terminaling and Storage Facilities [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	5 years
Terminaling and Storage Facilities [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	25 years
Transportation Assets [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 3,294	2,919.3
Transportation Assets [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	10 years
Transportation Assets [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	50 years
Other Property, Plant and Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 430.5	387.6
Other Property, Plant and Equipment [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	3 years
Other Property, Plant and Equipment [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	50 years
Land [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 185	163.3
Construction in Progress [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	1,456.1	1,011
Finance Lease Right-of-Use Assets [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 351.9	$ 266.1
Finance Lease Right-of-Use Assets [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	5 years
Finance Lease Right-of-Use Assets [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	14 years

Property, Plant and Equipment_4

Property, Plant and Equipment and Intangible Assets - Additional Information (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Property, Plant and Equipment [Line Items]
Depreciation expense		$ 945.6	$ 853.8	$ 739.6
Non-cash pre-tax impairments	$ 452.3			$ 452.3
Impairment of Oil and Gas Properties	$ 295.7
Weighted average discount rate percentage	9.50%			9.50%
Estimated amortization expense for intangible assets [Abstract]
Amortization		384	$ 242.2	$ 131
2024		373.2
2025		326
2026		279.8
2027		252.2
2028		$ 234
Weighted average amortization period, intangible assets		11 years 4 months 24 days
Customer Relationships [Member]
Property, Plant and Equipment [Line Items]
Impairment of Intangible	$ 156.6
Impairment, Intangible Asset, Finite-Lived, Statement of Income or Comprehensive Income [Extensible Enumeration]	Non-cash pre-tax impairments

Property, Plant and Equipment_5

Property, Plant and Equipment and Intangible Assets - Schedule of Changes in Intangible Assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Finite-Lived Intangible Assets [Roll Forward]
Balance at beginning of period	$ 2,734.6	$ 1,094.8
Additions from Delaware Basin Acquisition		1,882
Amortization	(384)	(242.2)	$ (131)
Balance at end of period	$ 2,350.6	$ 2,734.6	$ 1,094.8

Goodwill - Additional Informati

Goodwill - Additional Information (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Goodwill [Line Items]
Goodwill	$ 45.2	$ 45.2
Other Long-term Assets [Member]
Goodwill [Line Items]
Goodwill	$ 45.2

Goodwill - Schedule of Goodwill

Goodwill - Schedule of Goodwill (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Goodwill [Line Items]
Goodwill	$ 45.2	$ 45.2
Permian Midland [Member]
Goodwill [Line Items]
Goodwill	23.2	23.2
Permian Delaware [Member]
Goodwill [Line Items]
Goodwill	$ 22	$ 22

Investments in Unconsolidated_3

Investments in Unconsolidated Affiliates - Additional Information (Details) $ in Millions	3 Months Ended	12 Months Ended
	Dec. 31, 2021 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2023	Apr. 30, 2022 JointVenture	Feb. 28, 2022
Schedule Of Equity Method Investments [Line Items]
Gain (loss) from sale of equity-method investment		$ 435.9
GCX DevCo JV [Member]
Schedule Of Equity Method Investments [Line Items]
Ownership interest					25%
Gain (loss) from sale of equity-method investment		$ 435.9
T2 La Salle
Schedule Of Equity Method Investments [Line Items]
Non-cash pre-tax impairment losses	$ 29.9
T2 Eagle Ford [Member]
Schedule Of Equity Method Investments [Line Items]
Non-cash pre-tax impairment losses	$ 47.3
South Texas Acquisition
Schedule Of Equity Method Investments [Line Items]
Number of operated joint ventures | JointVenture				2
Targa Resources Partners LP [Member] | Gulf Coast Fractionators LP [Member] | Logistics and Transportation [Member]
Schedule Of Equity Method Investments [Line Items]
Ownership interest			38.80%
Targa Resources Partners LP [Member] | Cayenne Joint Venture [Member] | Logistics and Transportation [Member]
Schedule Of Equity Method Investments [Line Items]
Ownership interest			50%
Targa Resources Partners LP [Member] | Cayenne Joint Venture [Member] | Gathering and Processing [Member]
Schedule Of Equity Method Investments [Line Items]
Ownership interest			50%
Targa Resources Partners LP [Member] | Little Missouri 4 [Member] | Gathering and Processing [Member]
Schedule Of Equity Method Investments [Line Items]
Ownership interest			50%
Targa Resources Partners LP [Member] | South Texas Acquisition
Schedule Of Equity Method Investments [Line Items]
Number of operated joint ventures | JointVenture				2
Targa Resources Partners LP [Member] | South Texas Acquisition | T2 Joint Ventures [Member]
Schedule Of Equity Method Investments [Line Items]
Ownership interest				100%
Targa Resources Partners LP [Member] | South Texas Acquisition | T2 La Salle
Schedule Of Equity Method Investments [Line Items]
Ownership interest				75%
Targa Resources Partners LP [Member] | South Texas Acquisition | T2 Eagle Ford [Member]
Schedule Of Equity Method Investments [Line Items]
Ownership interest				50%

Investments in Unconsolidated_4

Investments in Unconsolidated Affiliates - Activity Related to Partnership's Investments in Unconsolidated Affiliates (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2023	Dec. 31, 2022		Dec. 31, 2021
Schedule Of Equity Method Investments [Line Items]
Balance at beginning of period		$ 131.3
Equity earnings (loss)		9	$ 9.1		$ (23.9)
Balance at end of period		146.3	131.3
Targa Resources Partners LP [Member]
Schedule Of Equity Method Investments [Line Items]
Balance at beginning of period		131.3	586.5		714
Equity earnings (loss)		9	9.1		(23.9)
Cash Distributions		(18.6)	(29)		(104.2)
Disposition/ Consolidation			(436.8)
Contributions		24.6	1.5		0.6
Balance at end of period		146.3	131.3		586.5
Targa Resources Partners LP [Member] | GCX [Member]
Schedule Of Equity Method Investments [Line Items]
Balance at beginning of period			421		435.2
Equity earnings (loss)			5.7		63.4
Cash Distributions			(14.3)		(78.1)
Disposition/ Consolidation			(412.4)
Contributions					0.5
Balance at end of period					421
Targa Resources Partners LP [Member] | Little Missouri 4 [Member]
Schedule Of Equity Method Investments [Line Items]
Balance at beginning of period		90.7	98.1		104.7
Equity earnings (loss)		7.7	5.5		10.9
Cash Distributions		(11.3)	(12.9)		(17.5)
Balance at end of period		87.1	90.7		98.1
Targa Resources Partners LP [Member] | T2 Eagle Ford
Schedule Of Equity Method Investments [Line Items]
Balance at beginning of period			21.9	[1]	79.8
Equity earnings (loss)			(0.6)	[1]	(57)
Cash Distributions			(0.8)	[1]	(1)
Disposition/ Consolidation	[1]		(20.5)
Contributions					0.1
Balance at end of period	[1]				21.9
Targa Resources Partners LP [Member] | T2 La Salle
Schedule Of Equity Method Investments [Line Items]
Balance at beginning of period			4.2	[1]	39.6
Equity earnings (loss)			(0.3)	[1]	(35)
Cash Distributions					(0.4)
Disposition/ Consolidation	[1]		(3.9)
Balance at end of period	[1]				4.2
Targa Resources Partners LP [Member] | Gulf Coast Fractionators LP [Member]
Schedule Of Equity Method Investments [Line Items]
Balance at beginning of period	[2]	27.1	28.8		38.5
Equity earnings (loss)	[2]	(4.1)	(3.2)		(8.6)
Cash Distributions	[2]	(2)			(1.1)
Contributions	[2]	24.6	1.5
Balance at end of period	[2]	45.6	27.1		28.8
Targa Resources Partners LP [Member] | Cayenne Joint Venture [Member]
Schedule Of Equity Method Investments [Line Items]
Balance at beginning of period		13.5	12.5		16.2
Equity earnings (loss)		5.4	2		2.4
Cash Distributions		(5.3)	(1)		(6.1)
Balance at end of period		$ 13.6	$ 13.5		$ 12.5
[1] Following the closing of the South Texas Acquisition in April 2022, the T2 Joint Ventures are 100 % owned and consolidated by Targa. In January 2021, the GCF facility was temporarily idled and Targa assumed operatorship in the first half of 2021. In January 2023, we reached an agreement with our partners to reactivate the GCF facility. The facility is expected to be operational in the second quarter of 2024.

Investments in Unconsolidated_5

Investments in Unconsolidated Affiliates - Activity Related to Partnership's Investments in Unconsolidated Affiliates (Parenthetical) (Details)	Apr. 30, 2022
Targa Resources Partners LP [Member] | South Texas Acquisition | T2 Joint Ventures [Member]
Schedule Of Equity Method Investments [Line Items]
Ownership interest	100%

Debt Obligations - Summary Of D

Debt Obligations - Summary Of Debt Obligations (Details) - USD ($) $ in Millions		Dec. 31, 2023	Dec. 31, 2022
Current Obligations of the Partnership [Abstract]
Partnership accounts receivable securitization facility, due August 2024	[1]	$ 575	$ 800
Finance lease liabilities	[2]	45.7	34.3
Current debt obligations		620.7	834.3
Long-term [Abstract]
Long-term debt including Unamortized premium(discount) and Debt issuance costs		12,179.9	10,574.7
Debt issuance costs, net of amortization		(90.8)	(65.6)
Finance lease liabilities	[2]	244.1	193
Long-term debt		12,333.2	10,702.1
Total debt obligations		12,953.9	11,536.4
Senior Unsecured Notes [Member]
Long-term [Abstract]
Unamortized discount		(29.5)	(8.4)
Senior Unsecured Notes [Member] | Senior Unsecured 5.200% Fixed Rate, due July 2027 [Member]
Long-term [Abstract]
Long-term debt		750	750
Senior Unsecured Notes [Member] | Senior Unsecured 6.150% Fixed Rate, due March 2029 [Member]
Long-term [Abstract]
Long-term debt		1,000	0
Senior Unsecured Notes [Member] | Senior Unsecured 4.200% Notes due February 2033 [Member]
Long-term [Abstract]
Long-term debt		750	750
Senior Unsecured Notes [Member] | Senior Unsecured 6.125% Fixed Rate, due March 2033 [Member]
Long-term [Abstract]
Long-term debt		900	0
Senior Unsecured Notes [Member] | Senior Unsecured 6.500% Fixed Rate, due March 2034 [Member]
Long-term [Abstract]
Long-term debt		1,000	0
Senior Unsecured Notes [Member] | Senior Unsecured 4.950% Notes due April 2052 [Member]
Long-term [Abstract]
Long-term debt		750	750
Senior Unsecured Notes [Member] | Senior Unsecured 6.250% fixed rate, due July 2052 [Member]
Long-term [Abstract]
Long-term debt		500	500
Senior Unsecured Notes [Member] | Senior Unsecured 6.500% Fixed Rate, due February 2053 [Member]
Long-term [Abstract]
Long-term debt		850	0
Senior Unsecured Notes [Member] | Senior Unsecured 6.500% Fixed Rate, due July 2027 [Member] | Targa Resources Partners LP [Member]
Long-term [Abstract]
Long-term debt	[3]	705.2	705.2
Senior Unsecured Notes [Member] | Senior Unsecured 5.000% Notes due January 2028 [Member] | Targa Resources Partners LP [Member]
Long-term [Abstract]
Long-term debt	[3]	700.3	700.3
Senior Unsecured Notes [Member] | Senior Unsecured of 6.875% Senior Notes due January 2029 [Member] | Targa Resources Partners LP [Member]
Long-term [Abstract]
Long-term debt	[3]	679.3	679.3
Senior Unsecured Notes [Member] | Senior Unsecured of 5.500% Senior Notes due March 2030 [Member] | Targa Resources Partners LP [Member]
Long-term [Abstract]
Long-term debt	[3]	949.6	949.6
Senior Unsecured Notes [Member] | Senior Unsecured of 4.875% Senior Notes due February 2031 [Member] | Targa Resources Partners LP [Member]
Long-term [Abstract]
Long-term debt	[3]	1,000	1,000
Senior Unsecured Notes [Member] | Senior Unsecured of 4.000% Senior Notes due January 2032 [Member] | Targa Resources Partners LP [Member]
Long-term [Abstract]
Long-term debt	[3]	1,000	1,000
Revolving Credit Facility [Member] | TRGP Senior Revolving Credit Facility due February 2027 [Member]
Long-term [Abstract]
Long-term debt	[4]	175	1,298.7
Revolving Credit Facility [Member] | TRGP Senior Revolving Credit Facility due February 2027 [Member] | Targa Resources Partners LP [Member]
Long-term [Abstract]
Letters of credit outstanding	[4]	22.3	33.2
Term Loan Facility, Variable Rate, due July 2025
Long-term [Abstract]
Long-term debt		$ 500	$ 1,500
[1] As of December 31, 2023, the Partnership had $ 575.0 million of qualifying receivables under its $ 600.0 million accounts receivable securitization facility (the “Securitization Facility”), resulting in $ 25.0 million of availability. The December 31, 2022 balance includes $ 171.2 million of assets and $ 167.0 million of liabilities related to compressor leases from the Delaware Basin Acquisition that were subsequently amended and extended. As of February 2022, we guarantee all of the Partnership’s outstanding senior unsecured notes. We maintain an unsecured commercial paper note program (the “Commercial Paper Program”), the borrowings of which are supported through maintaining a minimum available borrowing capacity under the TRGP Revolver equal to the aggregate amount outstanding under the Commercial Paper Program. As of December 31, 2023 , the TRGP Revolver had no borrowings outstanding and the Commercial Paper Program had $ 175.0 million borrowings outstanding, resulting

Debt Obligations - Summary Of_2

Debt Obligations - Summary Of Debt Obligations (Parenthetical) (Details) - USD ($)		12 Months Ended
		Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Nov. 30, 2023	Aug. 30, 2023	Aug. 29, 2023	Jan. 31, 2023	Apr. 30, 2022	Feb. 28, 2021
Debt Instrument [Line Items]
Proceeds from borrowings under accounts receivable securitization facility		$ 143,100,000	$ 1,230,000,000	$ 630,000,000
Partnership accounts receivable securitization facility, due August 2024	[1]	$ 575,000,000	$ 800,000,000
Senior Unsecured 6.150% Fixed Rate, due March 2029 [Member]
Debt Instrument [Line Items]
Interest rate on fixed rate debt					6.15%
Senior Unsecured 6.500% Fixed Rate, due March 2034 [Member]
Debt Instrument [Line Items]
Interest rate on fixed rate debt					6.50%
Accounts Receivable Securitization Facility [Member]
Debt Instrument [Line Items]
Maturity date		Aug. 29, 2024
Proceeds from borrowings under accounts receivable securitization facility		$ 575,000,000
Partnership accounts receivable securitization facility, due August 2024		600,000,000
Remaining liquidity needs		25,000,000				$ 600,000,000	$ 800,000,000
Maximum borrowing capacity		$ 600,000,000
Revolving Credit Facility [Member] | TRGP Senior Revolving Credit Facility due February 2027 [Member]
Debt Instrument [Line Items]
Maturity date		Feb. 28, 2027	Feb. 28, 2027
Remaining liquidity needs		$ 0
Revolving Credit Facility [Member] | Commercial Paper Program [Member]
Debt Instrument [Line Items]
Remaining liquidity needs		175,000,000
Revolving Credit Facility [Member] | Letters of Credit [Member]
Debt Instrument [Line Items]
Remaining liquidity needs		$ 2,600,000,000
Term Loan Facility, Variable Rate, due July 2025
Debt Instrument [Line Items]
Maturity date		Jul. 31, 2025	Jul. 31, 2025
Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Interest rate on fixed rate debt									4.20%	5.125%
Senior Unsecured Notes [Member] | Senior Unsecured 5.200% Fixed Rate, due July 2027 [Member]
Debt Instrument [Line Items]
Maturity date		Jul. 31, 2027	Jul. 31, 2027
Interest rate on fixed rate debt		5.20%	5.20%
Senior Unsecured Notes [Member] | Senior Unsecured 6.150% Fixed Rate, due March 2029 [Member]
Debt Instrument [Line Items]
Maturity date		Mar. 31, 2029	Mar. 31, 2029
Interest rate on fixed rate debt		6.15%	6.15%		6.15%
Senior Unsecured Notes [Member] | Senior Unsecured 4.200% Notes due February 2033 [Member]
Debt Instrument [Line Items]
Maturity date		Feb. 28, 2033	Feb. 28, 2033
Interest rate on fixed rate debt		4.20%	4.20%						4.20%
Senior Unsecured Notes [Member] | Senior Unsecured 6.125% Fixed Rate, due March 2033 [Member]
Debt Instrument [Line Items]
Maturity date		Mar. 31, 2033	Mar. 31, 2033
Interest rate on fixed rate debt		6.125%	6.125%					6.125%
Senior Unsecured Notes [Member] | Senior Unsecured 6.500% Fixed Rate, due March 2034 [Member]
Debt Instrument [Line Items]
Maturity date		Mar. 31, 2034	Mar. 31, 2034
Interest rate on fixed rate debt		6.50%	6.50%		6.50%
Senior Unsecured Notes [Member] | Senior Unsecured 4.950% Notes due April 2052 [Member]
Debt Instrument [Line Items]
Maturity date		Apr. 30, 2052	Apr. 30, 2052
Interest rate on fixed rate debt		4.95%	4.95%						4.95%
Senior Unsecured Notes [Member] | Senior Unsecured 6.250% fixed rate, due July 2052 [Member]
Debt Instrument [Line Items]
Maturity date		Jul. 31, 2052	Jul. 31, 2052
Interest rate on fixed rate debt		6.25%	6.25%
Senior Unsecured Notes [Member] | Senior Unsecured 6.500% Fixed Rate, due February 2053 [Member]
Debt Instrument [Line Items]
Maturity date		Feb. 28, 2053	Feb. 28, 2053
Interest rate on fixed rate debt		6.50%	6.50%					6.50%
Senior Unsecured Notes [Member] | Senior Unsecured 5.875% Notes due April 2026 [Member]
Debt Instrument [Line Items]
Interest rate on fixed rate debt									5.875%
Targa Resources Partners LP [Member] | Accounts Receivable Securitization Facility [Member] | Accounts Receivable Securitization Facility, due August 2024 [Member]
Debt Instrument [Line Items]
Maturity date		Aug. 31, 2024	Aug. 31, 2024
Targa Resources Partners LP [Member] | Senior Unsecured Notes [Member] | Senior Unsecured 6.500% Fixed Rate, due July 2027 [Member]
Debt Instrument [Line Items]
Maturity date		Jul. 31, 2027	Jul. 31, 2027
Interest rate on fixed rate debt		6.50%	6.50%
Targa Resources Partners LP [Member] | Senior Unsecured Notes [Member] | Senior Unsecured 5.000% Notes due January 2028 [Member]
Debt Instrument [Line Items]
Maturity date		Jan. 31, 2028	Jan. 31, 2028
Interest rate on fixed rate debt		5%	5%
Targa Resources Partners LP [Member] | Senior Unsecured Notes [Member] | Senior Unsecured of 6.875% Senior Notes due January 2029 [Member]
Debt Instrument [Line Items]
Maturity date		Jan. 31, 2029	Jan. 31, 2029
Interest rate on fixed rate debt		6.875%	6.875%
Targa Resources Partners LP [Member] | Senior Unsecured Notes [Member] | Senior Unsecured of 5.500% Senior Notes due March 2030 [Member]
Debt Instrument [Line Items]
Maturity date		Mar. 31, 2030	Mar. 31, 2030
Interest rate on fixed rate debt		5.50%	5.50%
Targa Resources Partners LP [Member] | Senior Unsecured Notes [Member] | Senior Unsecured of 4.875% Senior Notes due February 2031 [Member]
Debt Instrument [Line Items]
Maturity date		Feb. 28, 2031	Feb. 28, 2031
Interest rate on fixed rate debt		4.875%	4.875%
Targa Resources Partners LP [Member] | Senior Unsecured Notes [Member] | Senior Unsecured of 4.000% Senior Notes due January 2032 [Member]
Debt Instrument [Line Items]
Maturity date		Jan. 31, 2032	Jan. 31, 2032
Interest rate on fixed rate debt		4%	4%
[1] As of December 31, 2023, the Partnership had $ 575.0 million of qualifying receivables under its $ 600.0 million accounts receivable securitization facility (the “Securitization Facility”), resulting in $ 25.0 million of availability.

Debt Obligations - Range of Int

Debt Obligations - Range of Interest Rates and Weighted Average Interest Rate Incurred on Variable Rate Debt Obligations (Details)	Dec. 31, 2023
TRGP Revolver and Commercial Paper Program [Member]
Debt Instrument [Line Items]
Weighted average interest rate incurred	5.90%
Targa Resources Partners LP [Member] | Term Loan Facility [Member]
Debt Instrument [Line Items]
Weighted average interest rate incurred	6.50%
Targa Resources Partners LP [Member] | Securitization Facility [Member]
Debt Instrument [Line Items]
Weighted average interest rate incurred	5.80%
Minimum [Member] | TRGP Revolver and Commercial Paper Program [Member]
Debt Instrument [Line Items]
Range of interest rates incurred	5.20%
Minimum [Member] | Targa Resources Partners LP [Member] | Term Loan Facility [Member]
Debt Instrument [Line Items]
Range of interest rates incurred	5.80%
Minimum [Member] | Targa Resources Partners LP [Member] | Securitization Facility [Member]
Debt Instrument [Line Items]
Range of interest rates incurred	5.20%
Maximum [Member] | TRGP Revolver and Commercial Paper Program [Member]
Debt Instrument [Line Items]
Range of interest rates incurred	6.20%
Maximum [Member] | Targa Resources Partners LP [Member] | Term Loan Facility [Member]
Debt Instrument [Line Items]
Range of interest rates incurred	6.80%
Maximum [Member] | Targa Resources Partners LP [Member] | Securitization Facility [Member]
Debt Instrument [Line Items]
Range of interest rates incurred	6.30%

Debt Obligations - Partnership'

Debt Obligations - Partnership's Accounts Receivable Securitization Facility - Additional Information (Details) - Accounts Receivable Securitization Facility [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Aug. 30, 2023	Aug. 29, 2023
Debt Instrument [Line Items]
Maximum borrowing capacity	$ 600
Termination date	Aug. 29, 2024
Remaining liquidity needs	$ 25	$ 600	$ 800

Debt Obligations - TRGP Credit

Debt Obligations - TRGP Credit Agreement - Additional Information (Details) - New TRP Revolver [Member] - USD ($)	1 Months Ended	12 Months Ended
	Feb. 28, 2022	Dec. 31, 2023
Debt Instrument [Line Items]
Line of credit facility, current borrowing capacity	$ 2,750,000,000
Maximum borrowing capacity	500,000,000
Remaining borrowing capacity	$ 100,000,000
Maturity date	Feb. 17, 2027
Basis spread on variable rate		0%
Federal Funds Rate [Member]
Debt Instrument [Line Items]
Basis spread on variable rate		0.50%
Term SOFR [Member]
Debt Instrument [Line Items]
Basis spread on variable rate		1%
Term SOFR [Member] | SOFR Adjustment For Term SOFR Loans [Member]
Debt Instrument [Line Items]
Basis spread on variable rate		0.10%
Minimum [Member]
Debt Instrument [Line Items]
Leverage ratio before collateral release date		1
Minimum [Member] | Debt Rating [Member]
Debt Instrument [Line Items]
Commitment fee percentage		0.125%
Minimum [Member] | Term SOFR [Member] | Non-Credit-Enhanced Senior Unsecured Long-Term Debt Ratings [Member]
Debt Instrument [Line Items]
Basis spread on variable rate		1.125%
Minimum [Member] | Base Rate [Member] | Non-Credit-Enhanced Senior Unsecured Long-Term Debt Ratings [Member]
Debt Instrument [Line Items]
Basis spread on variable rate		0.125%
Maximum [Member]
Debt Instrument [Line Items]
Leverage ratio before collateral release date		5.50
Maximum [Member] | Debt Rating [Member]
Debt Instrument [Line Items]
Commitment fee percentage		0.35%
Maximum [Member] | Term SOFR [Member] | Non-Credit-Enhanced Senior Unsecured Long-Term Debt Ratings [Member]
Debt Instrument [Line Items]
Basis spread on variable rate		1.75%
Maximum [Member] | Base Rate [Member] | Non-Credit-Enhanced Senior Unsecured Long-Term Debt Ratings [Member]
Debt Instrument [Line Items]
Basis spread on variable rate		0.75%

Debt Obligations - Term Loan Fa

Debt Obligations - Term Loan Facility - Additional Information (Details) - Term Loan Facility [Member] - USD ($) $ in Billions	1 Months Ended	12 Months Ended
	Jul. 31, 2022	Dec. 31, 2023
Debt Instrument [Line Items]
Term loan facility, term	3 years
Maturity date	Jul. 31, 2025
Interest rate, description		The Term Loan Facility bears interest at the Company’s option at: (a) the Base Rate (as defined in the Term Loan Facility), which is the highest of the (i) federal funds rate plus 0.5%, (ii) Mizuho’s prime rate, and (iii) the Term SOFR (as defined in the Term Loan Facility) rate plus 1.0% (subject in each case to a floor of 0.0%), plus an applicable margin ranging from 0.125% to 0.75% dependent on the Company’s non-credit-enhanced senior unsecured long-term debt ratings (or, if no such debt is outstanding at such time, then the corporate, issuer or similar rating with respect to the Company that has been most recently announced) (the “Debt Rating”), or (b) Term SOFR plus 0.10% plus an applicable margin ranging from 1.125% to 1.75% dependent on the Debt Rating
Basis spread on variable rate	0%
Minimum [Member]
Debt Instrument [Line Items]
Leverage ratio before collateral release date	1
Maximum [Member]
Debt Instrument [Line Items]
Leverage ratio before collateral release date	5.5
Non Credit Enhanced Senior Unsecured Long Term Debt Ratings [Member] | Minimum [Member]
Debt Instrument [Line Items]
Basis spread on variable rate	1.125%
Non Credit Enhanced Senior Unsecured Long Term Debt Ratings [Member] | Maximum [Member]
Debt Instrument [Line Items]
Basis spread on variable rate	1.75%
Federal Funds Rate [Member]
Debt Instrument [Line Items]
Basis spread on variable rate	0.50%
Term SOFR Rate [Member]
Debt Instrument [Line Items]
Basis spread on variable rate	1%
Term SOFR Rate [Member] | Non Credit Enhanced Senior Unsecured Long Term Debt Ratings [Member]
Debt Instrument [Line Items]
Basis spread on variable rate	0.10%
Base Rate [Member] | Non Credit Enhanced Senior Unsecured Long Term Debt Ratings [Member] | Minimum [Member]
Debt Instrument [Line Items]
Basis spread on variable rate	0.125%
Base Rate [Member] | Non Credit Enhanced Senior Unsecured Long Term Debt Ratings [Member] | Maximum [Member]
Debt Instrument [Line Items]
Basis spread on variable rate	0.75%
Unsecured Debt [Member]
Debt Instrument [Line Items]
Aggregate principal amount issued	$ 1.5

Debt Obligations - Commercial P

Debt Obligations - Commercial Paper Program - Additional Information (Details)) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Jul. 31, 2022
Debt Instrument [Line Items]
Debt Instrument, Description	Debt instruments are considered substantially different if the present value of the cash flows under the terms of the new debt instrument is at least 10 percent different from the present value of the remaining cash flows under the terms of the existing debt instrument. We consider changes in principal amounts, interest rates, and maturity dates of the existing and new instruments when evaluating the change in cash flows between the instruments.
Commercial Paper Program [Member]
Debt Instrument [Line Items]
Amount outstanding	$ 2,750	$ 2,750
Debt Instrument, Description	Under the terms of the Commercial Paper Program, we may issue, from time to time, unsecured commercial paper notes with varying maturities of less than one year.

Debt Obligations - Partnershi_2

Debt Obligations - Partnership's Senior Unsecured Notes - Additional Information (Details) - Senior Unsecured Notes [Member]	12 Months Ended
	Dec. 31, 2023
Debt Instrument [Line Items]
Maximum percentage of aggregate principal amount of debt redeemable by the Partnership with equity offerings	35%
Redemption condition, minimum percentage of aggregate principal amount outstanding immediately after occurrence of redemption	65%
Redemption condition, maximum number of days from date of closing of equity offerings	180 days

Debt Obligations - Senior Unsec

Debt Obligations - Senior Unsecured Notes Issuances - Additional Information (Details) - USD ($) $ in Millions	1 Months Ended						12 Months Ended
	Nov. 30, 2023	Jan. 31, 2023	Jul. 31, 2022	Apr. 30, 2022	Feb. 28, 2022	Feb. 28, 2021	Dec. 31, 2023	Dec. 31, 2022
Senior Unsecured Notes Due2027 [Member]
Debt Instrument [Line Items]
Maturity date					Mar. 31, 2022
Term Loan Facility [Member]
Debt Instrument [Line Items]
Maturity date			Jul. 31, 2025
Repayment of borrowings	$ 1,000
Senior Unsecured 6.150% Fixed Rate, due March 2029 [Member]
Debt Instrument [Line Items]
Interest rate on fixed rate debt	6.15%
Senior Unsecured 6.500% Fixed Rate, due March 2034 [Member]
Debt Instrument [Line Items]
Interest rate on fixed rate debt	6.50%
Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Interest rate on fixed rate debt				4.20%		5.125%
Net proceeds from private placement of notes	$ 2,000	$ 1,700
Senior Unsecured Notes [Member] | Senior Unsecured Notes Due February2033 [Member]
Debt Instrument [Line Items]
Aggregate principal amount issued				$ 750
Interest rate on fixed rate debt				4.20%			4.20%	4.20%
Maturity date							Feb. 28, 2033	Feb. 28, 2033
Senior Unsecured Notes [Member] | Senior Unsecured Notes Due April2052 [Member]
Debt Instrument [Line Items]
Aggregate principal amount issued				$ 750
Interest rate on fixed rate debt				4.95%			4.95%	4.95%
Maturity date							Apr. 30, 2052	Apr. 30, 2052
Net proceeds from private placement of notes				$ 1,500
Senior Unsecured Notes [Member] | Senior Unsecured Notes Due April2026 [Member]
Debt Instrument [Line Items]
Interest rate on fixed rate debt				5.875%
Senior Unsecured Notes [Member] | Senior Unsecured Notes Due2027 [Member]
Debt Instrument [Line Items]
Interest rate on fixed rate debt			5.20%
Senior Unsecured Notes [Member] | Senior Unsecured Notes Due2052 [Member]
Debt Instrument [Line Items]
Interest rate on fixed rate debt			6.25%
Net proceeds from private placement of notes			$ 1,200
Senior Unsecured Notes [Member] | Senior Unsecured of 4% Senior Notes due 2032 [Member]
Debt Instrument [Line Items]
Aggregate principal amount issued						$ 1,000
Interest rate on fixed rate debt						4%
Net proceeds from private placement of notes						$ 991
Senior Unsecured Notes [Member] | Senior Unsecured 5.125% Notes due 2025 [Member]
Debt Instrument [Line Items]
Interest rate on fixed rate debt						5.125%
Senior Unsecured Notes [Member] | Senior Unsecured 6.125% Fixed Rate, due March 2033 [Member]
Debt Instrument [Line Items]
Aggregate principal amount issued		$ 900
Interest rate on fixed rate debt		6.125%					6.125%	6.125%
Maturity date							Mar. 31, 2033	Mar. 31, 2033
Senior Unsecured Notes [Member] | Senior Unsecured 6.500% Fixed Rate, due February 2053 [Member]
Debt Instrument [Line Items]
Aggregate principal amount issued		$ 850
Interest rate on fixed rate debt		6.50%					6.50%	6.50%
Maturity date							Feb. 28, 2053	Feb. 28, 2053
Senior Unsecured Notes [Member] | Term Loan Facility [Member]
Debt Instrument [Line Items]
Aggregate principal amount issued			$ 1,500
Senior Unsecured Notes [Member] | Senior Unsecured 6.150% Fixed Rate, due March 2029 [Member]
Debt Instrument [Line Items]
Aggregate principal amount issued	$ 1,000
Interest rate on fixed rate debt	6.15%						6.15%	6.15%
Maturity date							Mar. 31, 2029	Mar. 31, 2029
Senior Unsecured Notes [Member] | Senior Unsecured 6.500% Fixed Rate, due March 2034 [Member]
Debt Instrument [Line Items]
Aggregate principal amount issued	$ 1,000
Interest rate on fixed rate debt	6.50%						6.50%	6.50%
Maturity date							Mar. 31, 2034	Mar. 31, 2034

Debt Obligations - Debt Repurch

Debt Obligations - Debt Repurchases & Extinguishments - Additional Information (Details) - USD ($)	1 Months Ended						12 Months Ended
	Nov. 30, 2023	Jan. 31, 2023	Jul. 31, 2022	Feb. 28, 2022	Apr. 30, 2021	Feb. 28, 2021	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Apr. 30, 2022
Debt Instrument [Line Items]
Write-off debt issuance cost						$ 2,400,000
Gain (loss) from financing activities							$ (2,100,000)	$ (49,600,000)	$ (16,600,000)
Gain (loss) due to debt extinguishments						(14,900,000)	0
Premium Paid						$ 12,500,000
Senior Unsecured 5.250% Notes due May 2023 [Member]
Debt Instrument [Line Items]
Gain (loss) due to debt extinguishments				$ 800,000
Senior Notes due 2027 [Member]
Debt Instrument [Line Items]
Write-off debt issuance cost							4,500,000
Gain (loss) due to debt extinguishments							(33,800,000)
Premium Paid							$ 29,300,000
Maturity date				Mar. 31, 2022
TRGP Revolver [Member]
Debt Instrument [Line Items]
Gain (loss) due to debt extinguishments				$ 15,000,000
Senior Unsecured 4.250% Notes due November 2023 [Member]
Debt Instrument [Line Items]
Interest rate on fixed rate debt					4.25%
Gain (loss) due to debt extinguishments					$ (1,900,000)
Maturity date					May 31, 2021
Senior Unsecured 6.150% Fixed Rate, due March 2029 [Member]
Debt Instrument [Line Items]
Interest rate on fixed rate debt	6.15%
Senior Unsecured 6.500% Fixed Rate, due March 2034 [Member]
Debt Instrument [Line Items]
Interest rate on fixed rate debt	6.50%
Term Loan Facility [Member]
Debt Instrument [Line Items]
Gain (loss) due to debt extinguishments	$ 2,100,000
Maturity date			Jul. 31, 2025
Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Interest rate on fixed rate debt						5.125%				4.20%
Net proceeds from private placement of notes	$ 2,000,000,000	$ 1,700,000,000
Senior Unsecured Notes [Member] | Senior Notes due 2027 [Member]
Debt Instrument [Line Items]
Interest rate on fixed rate debt			5.20%
Senior Unsecured Notes [Member] | Senior Unsecured Notes Due February2033 [Member]
Debt Instrument [Line Items]
Interest rate on fixed rate debt							4.20%	4.20%		4.20%
Maturity date							Feb. 28, 2033	Feb. 28, 2033
Aggregate principal amount issued										$ 750,000,000
Senior Unsecured Notes [Member] | Senior Unsecured 6.150% Fixed Rate, due March 2029 [Member]
Debt Instrument [Line Items]
Interest rate on fixed rate debt	6.15%						6.15%	6.15%
Maturity date							Mar. 31, 2029	Mar. 31, 2029
Aggregate principal amount issued	$ 1,000,000,000
Senior Unsecured Notes [Member] | Senior Unsecured 6.500% Fixed Rate, due March 2034 [Member]
Debt Instrument [Line Items]
Interest rate on fixed rate debt	6.50%						6.50%	6.50%
Maturity date							Mar. 31, 2034	Mar. 31, 2034
Aggregate principal amount issued	$ 1,000,000,000
Senior Unsecured Notes [Member] | Term Loan Facility [Member]
Debt Instrument [Line Items]
Aggregate principal amount issued			$ 1,500,000,000
Targa Resources Partners LP [Member] | Targa Pipeline Partners L P
Debt Instrument [Line Items]
Gain (loss) due to debt extinguishments						$ 200,000
Targa Resources Partners LP [Member] | Senior Notes due 2027 [Member] | Targa Pipeline Partners L P
Debt Instrument [Line Items]
Write-off debt issuance cost				$ 2,400,000
Interest rate on fixed rate debt				5.375%
Premium Paid				$ 12,600,000
Targa Resources Partners LP [Member] | Senior Unsecured 4.200% Notes due 2027 [Member]
Debt Instrument [Line Items]
Interest rate on fixed rate debt				4.20%
Targa Resources Partners LP [Member] | Senior Unsecured 4.950% Notes due 2027 [Member]
Debt Instrument [Line Items]
Interest rate on fixed rate debt				4.95%
Targa Resources Partners LP [Member] | Senior Unsecured 5.875% Notes due 2027 [Member]
Debt Instrument [Line Items]
Interest rate on fixed rate debt				5.875%
Targa Resources Partners LP [Member] | Senior Unsecured 5.875% Notes due August 2023 [Member] | Targa Pipeline Partners L P
Debt Instrument [Line Items]
Interest rate on fixed rate debt						5.875%
Targa Resources Partners LP [Member] | Senior Unsecured Notes [Member] | TPL 4.750% Senior Notes due 2021 [Member] | Targa Pipeline Partners L P
Debt Instrument [Line Items]
Interest rate on fixed rate debt						4.75%

Debt Obligations - Debt Repur_2

Debt Obligations - Debt Repurchases Summary (Details) $ in Millions	1 Months Ended
	Feb. 28, 2021 USD ($)
Debt Instrument [Line Items]
Write-off of debt issuance costs	$ (2.4)

Debt Obligations - Schedule of

Debt Obligations - Schedule of Contractual Maturities of Debt Obligations (Details) $ in Millions	Dec. 31, 2023 USD ($)
Contractual Obligation [Line Items]
Total	$ 12,784.4
2024	575
2025	500
2026	0
2027	1,630.2
2028	700.3
Thereafter	9,378.9
Securitization Facility | Targa Resources Partners LP [Member]
Contractual Obligation [Line Items]
Total	575
2024	575
2025	0
2026	0
2027	0
2028	0
Thereafter	0
Senior Unsecured Notes [Member] | Targa Resources Partners LP [Member]
Contractual Obligation [Line Items]
Total	5,034.4
2024	0
2025	0
2026	0
2027	705.2
2028	700.3
Thereafter	3,628.9
TRGP Revolver and Commercial Paper Program [Member] | Targa Resources Partners LP [Member]
Contractual Obligation [Line Items]
Total	175
2024	0
2025	0
2026	0
2027	175
2028	0
Thereafter	0
TRGP Senior Unsecured Notes [Member] | Targa Resources Partners LP [Member]
Contractual Obligation [Line Items]
Total	6,500
2024	0
2025	0
2026	0
2027	750
2028	0
Thereafter	5,750
Term Loan Facility [Member] | Targa Resources Partners LP [Member]
Contractual Obligation [Line Items]
Total	500
2024	0
2025	500
2026	0
2027	0
2028	0
Thereafter	$ 0

Debt Obligations - Subsequent E

Debt Obligations - Subsequent Event - Additional Information (Details) - Senior Unsecured Notes [Member] - USD ($) $ in Billions	1 Months Ended
	Nov. 30, 2023	Jan. 31, 2023	Apr. 30, 2022	Feb. 28, 2021
Debt Instrument [Line Items]
Interest rate on fixed rate debt			4.20%	5.125%
Net proceeds from senior notes	$ 2	$ 1.7

Other Long-term Liabilities - S

Other Long-term Liabilities - Schedule of Other Long-term Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Other Liabilities, Noncurrent [Abstract]
Deferred revenue	$ 248.8	$ 198.8	$ 171.8
Asset retirement obligations	103	97.9	$ 72.1
Operating lease liabilities	56.5	28.6
Other liabilities	6.8	15.9
Total other long-term liabilities	$ 415.1	$ 341.2

Other Long-term Liabilities - D

Other Long-term Liabilities - Deferred Revenue (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Deferred Revenue and Other [Abstract]
Deferred revenue	$ 248.8	$ 198.8	$ 171.8
Deferred revenue recognized related to gas gathering and processing agreement	17.4	$ 7.5	$ 3.9
Channelview Splitter [Member]
Deferred Revenue and Other [Abstract]
Deferred revenue	$ 129

Other Long-term Liabilities - C

Other Long-term Liabilities - Components of Deferred Revenue (Details) - USD ($) $ in Millions		Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Deferred Revenue Arrangement [Line Items]
Total deferred revenue		$ 248.8	$ 198.8	$ 171.8
Splitter Agreement [Member]
Deferred Revenue Arrangement [Line Items]
Total deferred revenue		129	129
Gas Contract Amendment [Member]
Deferred Revenue Arrangement [Line Items]
Total deferred revenue		29.8	32.3
Contributions in Aid of Construction [Member]
Deferred Revenue Arrangement [Line Items]
Total deferred revenue	[1]	86.4	31.7
Other
Deferred Revenue Arrangement [Line Items]
Total deferred revenue		$ 3.6	$ 5.8
[1] Increase in contributions in aid of construction was due to additions of deferred revenue in West Texas and Badlands.

Other Long-term Liabilities -_2

Other Long-term Liabilities - Changes in Deferred Revenue (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Other Liabilities, Noncurrent [Abstract]
Balance at beginning of period	$ 198.8	$ 171.8
Additions	67.4	34.5
Revenue recognized	(17.4)	(7.5)	$ (3.9)
Balance at end of period	$ 248.8	$ 198.8	$ 171.8

Other Long-term Liabilities -_3

Other Long-term Liabilities - Changes in Aggregate Asset Retirement Obligations (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning of period		$ 97.9	$ 72.1
Additions	[1]		20.2
Accretion expense		5.9	4.8	$ 4
Change in cash flow estimate		4.9	0.8
Retirements		(5.7)
End of period		$ 103	$ 97.9	$ 72.1
[1] Amount reflects additions of ARO in 2022 related to the Delaware Basin Acquisition.

Leases - Additional Information

Leases - Additional Information (Details)	Dec. 31, 2023
Lessee Lease Description [Line Items]
Weighted-average remaining lease terms for operating leases	5 years
Weighted-average remaining lease terms for finance leases	6 years
Weighted-average discount rates for operating leases	5%
Weighted-average discount rates for finance leases	5%
Minimum [Member]
Lessee Lease Description [Line Items]
Remaining lease terms	1 year
Maximum [Member]
Lessee Lease Description [Line Items]
Remaining lease terms	9 years
Options to extend lease term	20 years

Leases - Summary of Balances of

Leases - Summary of Balances of Right of Use Assets and Liabilities of Finance Leases and Operating Leases (Details) - USD ($) $ in Millions		Dec. 31, 2023	Dec. 31, 2022
Right-of-use assets
Operating leases, gross		$ 101.1	$ 57.3
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]		Other long-term assets	Other long-term assets
Finance leases, gross	[1]	$ 351.9	$ 266.1
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]		Property, plant and equipment, net	Property, plant and equipment, net
Current:
Operating leases		$ 21.8	$ 14.4
Operating Lease, Liability, Current, Statement of Financial Position [Extensible List]		Accrued liabilities	Accrued liabilities
Finance leases	[1]	$ 45.7	$ 34.3
Finance Lease, Liability, Current, Statement of Financial Position [Extensible List]		Liabilities, Current	Liabilities, Current
Non-current:
Operating leases		$ 56.5	$ 28.6
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]		Other long-term liabilities	Other long-term liabilities
Finance leases	[1]	$ 244.1	$ 193
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]		Long-term debt	Long-term debt
[1] The December 31, 2022 balance includes $ 171.2 million of assets and $ 167.0 million of liabilities related to compressor leases from the Delaware Basin Acquisition that were subsequently amended and extended.

Leases - Summary of Balances _2

Leases - Summary of Balances of Right of Use Assets and Liabilities of Finance Leases and Operating Leases (Parenthetical) (Details) - USD ($) $ in Millions		Dec. 31, 2023	Dec. 31, 2022
Lessee, Lease, Description [Line Items]
Finance Lease, Asset	[1]	$ 351.9	$ 266.1
Finance Lease, Liability		289.8
Compressor [Member] | Delaware Basin Acquisition
Lessee, Lease, Description [Line Items]
Finance Lease, Asset		171.2	$ 171.2
Finance Lease, Liability		$ 167
[1] The December 31, 2022 balance includes $ 171.2 million of assets and $ 167.0 million of liabilities related to compressor leases from the Delaware Basin Acquisition that were subsequently amended and extended.

Leases - Summary of Components

Leases - Summary of Components of Lease Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Lease cost
Operating lease cost	$ 18.3	$ 17.7	$ 12.2
Short-term lease cost	56.7	35	20.4
Variable lease cost	26	17.9	5.7
Finance lease cost
Amortization of right-of-use assets	48.2	20.3	13.3
Interest expense	14	3.5	1.1
Total lease cost	$ 163.2	$ 94.4	$ 52.7

Leases - Summary of Other Suppl

Leases - Summary of Other Supplemental Information Related to Leases (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows for operating leases	$ 21.4	$ 18.8	$ 14.1
Operating cash flows for finance leases	13.9	2.7	1
Financing cash flows for finance leases	$ 42.9	$ 19.7	$ 12.5

Leases - Summary of Maturities

Leases - Summary of Maturities of Lease Liabilities Under Non-cancellable Leases (Details) $ in Millions	Dec. 31, 2023 USD ($)
Leases [Abstract]
2024	$ 25.5
2025	16.8
2026	11.2
2027	10.3
2028	10.1
Thereafter	14.4
Total undiscounted cash flows	88.3
Less imputed interest	(10)
Total lease liabilities	$ 78.3
Operating Lease, Liability, Statement of Financial Position [Extensible List]	us-gaap:OtherLiabilities
2024	$ 57.5
2025	56.5
2026	55
2027	48.9
2028	41.4
Thereafter	72.8
Total undiscounted cash flows	332.1
Less imputed interest	(42.3)
Total lease liabilities	$ 289.8

Preferred Stock - Additional In

Preferred Stock - Additional Information (Details) - USD ($)		3 Months Ended	12 Months Ended
	May 03, 2022	Jun. 30, 2022	Dec. 31, 2023	Dec. 31, 2022		Dec. 31, 2021	Dec. 31, 2020
Class Of Stock [Line Items]
Preferred stock dividend paid				$ 51,800,000		$ 87,300,000
Deemed dividends on Series A Preferred Stock				$ 215,500,000
Preferred stock dividend per share						$ 23.75	$ 23.75
Repurchases of common stock (in shares)			4,870,559	3,412,354		756,478
Net carrying value of shares repurchased			$ 373,700,000	$ 224,800,000		$ 40,000,000
Series A Preferred Stock [Member]
Class Of Stock [Line Items]
Preferred stock, liquidation per share			$ 1,000	$ 1,000
Preferred stock, percentage of dividend			9.50%
Preferred stock dividend payment terms			fixed dividend payable quarterly 45 days after the end of each fiscal quarter
Preferred stock redemption premium percentage in sixth year			10%
Preferred stock redemption premium percentage in sixth year and thereafter			5%
Preferred stock, dividend	$ 8.87
Preferred stock, redemption date	May 03, 2022
Preferred stock, consideration paid	$ 973,400,000
Maximum number of common share would be issued upon conversion of preferred share			44,260,953
Deemed dividends on Series A Preferred Stock		$ 215,500,000		$ 215,500,000	[1]
Preferred Stock, redemption price	$ 1,050
Unpaid dividends	$ 8,200,000
Net carrying value of shares repurchased	$ 223,700,000
Series A Preferred Stock [Member] | Maximum [Member]
Class Of Stock [Line Items]
Incurrence of indebtedness other than stipulated fixed charge coverage			$ 2,750,000,000
[1] Includes $ 215.5 million attributable to the full redemption of Series A Preferred in 2022. See Note 11 – Preferred Stock for further discussion.

Common Stock and Related Matt_3

Common Stock and Related Matters - Additional Information (Details) - USD ($)	1 Months Ended	3 Months Ended	12 Months Ended
	Apr. 30, 2023	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	May 31, 2023	Oct. 31, 2020	Sep. 20, 2018	May 09, 2017
Securities Financing Transaction [Line Items]
Stock repurchase program, authorized amount						$ 1,000,000,000	$ 500,000,000
Repurchases of common stock (in shares)			4,870,559	3,412,354	756,478
Remaining share repurchase amount			$ 770,100,000
Weighted average price per share			$ 76.72	$ 65.87	$ 52.81
Repurchase of common shares, Value			$ 373,700,000	$ 224,800,000	$ 40,000,000
Common stock dividends, per share	$ 0.5		$ 1.85	$ 1.4	$ 0.4
Common stock annualized dividends, per share		$ 2
2017 ATM Program [Member]
Securities Financing Transaction [Line Items]
Amount of common stock authorized under equity distribution agreement									$ 750,000,000
Equity Distribution Agreement May 2017 [Member]
Securities Financing Transaction [Line Items]
Public offering of common shares (including underwriters' overallotment option)			0	0	0
Amount of common stock authorized under equity distribution agreement			$ 382,100,000
2018 ATM Program [Member]
Securities Financing Transaction [Line Items]
Amount of common stock authorized under equity distribution agreement								$ 750,000,000
Equity Distribution Agreement September 2018 [Member]
Securities Financing Transaction [Line Items]
Public offering of common shares (including underwriters' overallotment option)			0	0	0
Amount of common stock authorized under equity distribution agreement			$ 750,000,000

Common Stock and Related Matt_4

Common Stock and Related Matters - Dividends Declared And Or Paid (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended	3 Months Ended												12 Months Ended
	Apr. 30, 2023	Dec. 31, 2023	Sep. 30, 2023	Jun. 30, 2023	Mar. 31, 2023	Dec. 31, 2022	Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Dec. 31, 2021	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Dividends Payable [Line Items]
Dividends Declared per Share of Common Stock	$ 0.5													$ 1.85	$ 1.4	$ 0.4
Dividend Declared [Member]
Dividends Payable [Line Items]
Date Paid or To Be Paid		Feb. 15, 2024	Nov. 15, 2023	Aug. 15, 2023	May 15, 2023	Feb. 15, 2023	Nov. 15, 2022	Aug. 15, 2022	May 16, 2022	Feb. 15, 2022	Nov. 15, 2021	Aug. 16, 2021	May 14, 2021
Total Common Dividends Declared		$ 112.8	$ 113	$ 113.6	$ 114.7	$ 80.5	$ 80.5	$ 80.7	$ 81.2	$ 81.4	$ 23.3	$ 23.3	$ 23.3
Amount of Common Dividends Paid or To Be Paid		111.6	111.5	111.8	113	79.3	79.2	79.3	79.8	80.1	22.9	22.9	22.9
Dividends on Share-Based Awards		$ 1.2	$ 1.5	$ 1.8	$ 1.7	$ 1.2	$ 1.3	$ 1.4	$ 1.4	$ 1.3	$ 0.4	$ 0.4	$ 0.4
Dividends Declared per Share of Common Stock		$ 0.5	$ 0.5	$ 0.5	$ 0.5	$ 0.35	$ 0.35	$ 0.35	$ 0.35	$ 0.35	$ 0.1	$ 0.1	$ 0.1

Earnings per Common Share (Deta

Earnings per Common Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions		3 Months Ended	12 Months Ended
		Jun. 30, 2022	Dec. 31, 2023	Dec. 31, 2022		Dec. 31, 2021
Earnings Per Common Share [Line Items]
Net income (loss) attributable to Targa Resources Corp.			$ 1,345.9	$ 1,195.5		$ 71.2
Less: Premium on repurchase of noncontrolling interests, net of tax	[1]		510.1	53.2
Less: Deemed dividends on Series A Preferred				215.5
Net income (loss) attributable to common shareholders			835.8	896.8		(16.1)
Less: Participating share-based earnings	[2]		7.6
Net income (loss) allocated to common shareholders for basic earnings per share			$ 828.2	$ 896.8		$ (16.1)
Weighted average shares outstanding - basic			224.6	227.3		228.6
Dilutive effect of unvested stock awards	[3]		1.4	3.8
Weighted average shares outstanding - diluted (in shares)			226	231.1		228.6
Net income (loss) per common share - basic			$ 3.69	$ 3.95		$ (0.07)
Net income (loss) per common share - diluted			$ 3.66	$ 3.88		$ (0.07)
Series A Preferred Stock [Member]
Earnings Per Common Share [Line Items]
Less: Dividends on Series A Preferred Stock	[4]			$ 30		$ 87.3
Less: Deemed dividends on Series A Preferred		$ 215.5		$ 215.5	[5]
[1] Represents premium paid on the Grand Prix Transaction, Carnero Acquisition and the DevCo JV Repurchase. See Note 4 – Acquisitions and Divestitures Represents the distributed and undistributed earnings of the Company attributable to the participating securities. The dilutive effect of the reallocation of participating securities to diluted net income attributable to common shareholders was immaterial. For the year ended December 31, 2021, all unvested restricted stock awards and Series A Preferred were antidilutive because a net loss existed in the period. Includes $ 8.2 million attributable to the dividends paid upon the full redemption of Series A Preferred in 2022. Includes $ 215.5 million attributable to the full redemption of Series A Preferred in 2022. See Note 11 – Preferred Stock for further discussion.

Earnings per Common Share (Pare

Earnings per Common Share (Parenthetical) (Details) - Series A Preferred Stock [Member] $ in Millions	12 Months Ended
	Dec. 31, 2022 USD ($)
Earnings Per Common Share [Line Items]
Dividends paid upon partial repurchase of shares	$ 8.2
Deemed dividend on partial repurchase of shares	$ 215.5

Earnings per Common Share - Sum

Earnings per Common Share - Summary of Potential Common Stock Equivalents Excluded from Determination of Diluted Earnings Per Share (Details) - shares shares in Millions		12 Months Ended
		Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Unvested Restricted Stock Awards [Member]
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Anti-dilutive shares excluded from the determination of diluted earnings per share (in shares)		1.5		3.3
Series A Preferred Stock [Member]
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Anti-dilutive shares excluded from the determination of diluted earnings per share (in shares)	[1]		14.9	44.3
[1] The Series A Preferred had no mandatory redemption date, but was redeemable at our election for a 5 % premium to the liquidation preference subsequent to March 16, 2022 . In May 2022, we redeemed all of our issued and outstanding Series A Preferred at a redemption price of $ 1,050.00 per share, plus $ 8.87 per share, which is the amount of accrued and unpaid dividends from April 1, 2022 up to, but not including, the redemption date of May 3, 2022 . See Note 11 – Preferred Stock for further discussion.

Earnings per Common Share - S_2

Earnings per Common Share - Summary of Potential Common Stock Equivalents Excluded from Determination of Diluted Earnings Per Share (Parenthetical) (Details) - Series A Preferred Stock [Member] - $ / shares			12 Months Ended
	May 03, 2022	Mar. 17, 2022	Dec. 31, 2023
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Preferred stock redemption premium percentage		5%
Preferred stock liquidation preference date			Mar. 16, 2022
Temporary equity, redemption price per share	$ 1,050
Preferred stock dividends per share	$ 8.87
Temporary equity redemption date	May 03, 2022

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities - Notional Volumes Of The Partnership's Commodity Derivative Contracts (Details) - Targa Resources Partners LP [Member]	12 Months Ended
	Dec. 31, 2023 MMBTU bbl
Swaps [Member] | Year 2024 [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in MMBtu per day) | MMBTU	107,242
Swaps [Member] | Year 2024 [Member] | NGL [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in Bbl per day)	31,893
Swaps [Member] | Year 2025 [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in MMBtu per day) | MMBTU	58,179
Swaps [Member] | Year 2025 [Member] | NGL [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in Bbl per day)	21,354
Swaps [Member] | Year 2026 [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in MMBtu per day) | MMBTU	14,297
Swaps [Member] | Year 2026 [Member] | NGL [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in Bbl per day)	5,589
Swaps [Member] | Year 2027 [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in MMBtu per day) | MMBTU	0
Swaps [Member] | Year 2027 [Member] | NGL [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in Bbl per day)	0
Basis Swaps [Member] | Year 2024 [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in MMBtu per day) | MMBTU	478,374
Basis Swaps [Member] | Year 2025 [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in MMBtu per day) | MMBTU	256,658
Basis Swaps [Member] | Year 2026 [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in MMBtu per day) | MMBTU	122,500
Basis Swaps [Member] | Year 2027 [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in MMBtu per day) | MMBTU	35,000
Future [Member] | Year 2024 [Member] | NGL [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in Bbl per day)	14,511
Future [Member] | Year 2025 [Member] | NGL [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in Bbl per day)	4,767
Future [Member] | Year 2026 [Member] | NGL [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in Bbl per day)	0
Future [Member] | Year 2027 [Member] | NGL [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in Bbl per day)	0
Options [Member] | Year 2024 [Member] | Condensate [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in Bbl per day)	4,531
Options [Member] | Year 2025 [Member] | Condensate [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in Bbl per day)	3,447
Options [Member] | Year 2026 [Member] | Condensate [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in Bbl per day)	1,092
Options [Member] | Year 2027 [Member] | Condensate [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in Bbl per day)	0

Derivative Instruments and He_4

Derivative Instruments and Hedging Activities, Fair Values Derivatives, Balance Sheet Location, by Derivative Contract Type (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Derivatives, Fair Value [Line Items]
Derivative assets	$ 145.2	$ 204.4
Derivative assets	111.9	179.9
Derivative assets	33.3	24.5
Derivative liabilities	(70.8)	(460.2)
Derivative liabilities	(54)	(320.1)
Derivative liabilities	(16.8)	(140.1)
Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	132.5	182.9
Derivative liabilities	(19.4)	(124.7)
Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current Assets from Risk Management Activities [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	103.5	158.7
Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Other Long-term Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	29	24.2
Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current Liabilities from Risk Management Activities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	(16.4)	(93.8)
Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Long-term Position [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	(3)	(30.9)
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	12.7	21.5
Derivative liabilities	(51.4)	(335.5)
Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current Assets from Risk Management Activities [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	8.4	21.2
Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Other Long-term Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	4.3	0.3
Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current Liabilities from Risk Management Activities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	(37.6)	(226.3)
Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Long-term Position [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	$ (13.8)	$ (109.2)

Derivative Instruments and He_5

Derivative Instruments and Hedging Activities - Pro Forma Impact Of Offsetting Assets (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Derivative Asset [Abstract]
Derivative assets	$ 145.2	$ 204.4
Pro forma net presentation, asset, current	$ 69.4	$ 44.9
Derivative Asset, Current, Statement of Financial Position [Extensible Enumeration]	Derivative Asset Before Effects Of Master Netting Arrangements Current	Derivative Asset Before Effects Of Master Netting Arrangements Current
Pro forma net presentation, asset, noncurrent	$ 18.6	$ 7.3
Derivative Asset, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Derivative Asset Before Effects Of Master Netting Arrangements Noncurrent	Derivative Asset Before Effects Of Master Netting Arrangements Noncurrent
Pro forma net presentation, asset, total	$ 88	$ 52.2
Counterparties with Offsetting Positions or Collateral [Member]
Derivative Asset [Abstract]
Derivative assets	143.4	186.7
Pro forma net presentation, asset, total	86.2	34.5
Counterparties without Offsetting Position [Member]
Derivative Asset [Abstract]
Derivative assets	1.8	17.7
Pro forma net presentation, asset, current	0.2	17.7
Pro forma net presentation, asset, noncurrent	1.6
Pro forma net presentation, asset, total	1.8	17.7
Current Assets from Risk Management Activities [Member]
Derivative Asset [Abstract]
Derivative assets	111.9	179.9
Current Assets from Risk Management Activities [Member] | Counterparties with Offsetting Positions or Collateral [Member]
Derivative Asset [Abstract]
Derivative assets	111.7	162.2
Pro forma net presentation, asset	69.2	27.2
Current Assets from Risk Management Activities [Member] | Counterparties without Offsetting Position [Member]
Derivative Asset [Abstract]
Derivative assets	0.2	17.7
Other Long-term Assets [Member]
Derivative Asset [Abstract]
Derivative assets	33.3	24.5
Other Long-term Assets [Member] | Counterparties with Offsetting Positions or Collateral [Member]
Derivative Asset [Abstract]
Derivative assets	31.7	24.5
Pro forma net presentation, asset	17	$ 7.3
Other Long-term Assets [Member] | Counterparties without Offsetting Position [Member]
Derivative Asset [Abstract]
Derivative assets	$ 1.6

Derivative Instruments and He_6

Derivative Instruments and Hedging Activities - Pro Forma Impact Of Offsetting Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Derivative Liability [Abstract]
Gross liability	$ (70.8)	$ (460.2)
Pro forma net presentation, liability, current	$ (7.9)	$ (172.9)
Derivative Liability, Current, Statement of Financial Position [Extensible Enumeration]	Derivative Liability Before Effects Of Master Netting Arrangements Current	Derivative Liability Before Effects Of Master Netting Arrangements Current
Pro forma net presentation, liability, noncurrent	$ (2.2)	$ (100.5)
Derivative Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Derivative Liability Before Effects Of Master Netting Arrangements Noncurrent	Derivative Liability Before Effects Of Master Netting Arrangements Noncurrent
Pro forma net presentation, liability, total	$ (10.1)	$ (273.4)
Counterparties with Offsetting Positions or Collateral [Member]
Derivative Liability [Abstract]
Gross liability	(70.8)	(454.1)
Pro forma net presentation, liability, current	(7.9)	(169.5)
Pro forma net presentation, liability, noncurrent	(2.2)	(97.8)
Pro forma net presentation, liability, total	(10.1)	(267.3)
Counterparties without Offsetting Position [Member]
Derivative Liability [Abstract]
Gross liability		(6.1)
Pro forma net presentation, liability, current		(3.4)
Pro forma net presentation, liability, noncurrent		(2.7)
Pro forma net presentation, liability, total		(6.1)
Current Liabilities from Risk Management Activities [Member]
Derivative Liability [Abstract]
Gross liability	(54)	(320.1)
Current Liabilities from Risk Management Activities [Member] | Counterparties with Offsetting Positions or Collateral [Member]
Derivative Liability [Abstract]
Gross liability	(54)	(316.7)
Current Liabilities from Risk Management Activities [Member] | Counterparties without Offsetting Position [Member]
Derivative Liability [Abstract]
Gross liability		(3.4)
Long-Term Liabilities from Risk Management Activities [Member]
Derivative Liability [Abstract]
Gross liability	(16.8)	(140.1)
Long-Term Liabilities from Risk Management Activities [Member] | Counterparties with Offsetting Positions or Collateral [Member]
Derivative Liability [Abstract]
Gross liability	$ (16.8)	(137.4)
Long-Term Liabilities from Risk Management Activities [Member] | Counterparties without Offsetting Position [Member]
Derivative Liability [Abstract]
Gross liability		$ (2.7)

Derivative Instruments and He_7

Derivative Instruments and Hedging Activities, Pro Forma Impact - Offsetting Collateral (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Derivative Asset [Abstract]
Gross collateral	$ 3.5	$ 34.6
Counterparties with Offsetting Positions or Collateral [Member]
Derivative Asset [Abstract]
Gross collateral	3.5	34.6
Current Assets from Risk Management Activities [Member]
Derivative Asset [Abstract]
Gross collateral	3.6	12.2
Current Assets from Risk Management Activities [Member] | Counterparties with Offsetting Positions or Collateral [Member]
Derivative Asset [Abstract]
Gross collateral	3.6	12.2
Other Long-term Assets [Member]
Derivative Asset [Abstract]
Gross collateral	(0.1)	22.4
Other Long-term Assets [Member] | Counterparties with Offsetting Positions or Collateral [Member]
Derivative Asset [Abstract]
Gross collateral	$ (0.1)	$ 22.4

Derivative Instruments and He_8

Derivative Instruments and Hedging Activities - Additional Information (Details) - USD ($)	Dec. 31, 2023	Dec. 31, 2022
Derivative [Line Items]
Estimated fair value of derivative instruments, net asset	$ 74,400,000
Amount expected to reclassify commodity hedge related deferred losses to earnings before income taxes	103,400,000
Amount of deferred gains to be reclassified into earnings before income taxes over next twelve months	77,500,000
Loss contigency reduction of maximum loss due to counterparty credit risk by master netting provision	32,200,000
Derivative liability	10,100,000	$ 273,400,000
Derivative collateral amount	0
Credit Risk [Member]
Derivative [Line Items]
Derivative liability	9,900,000
Minimum [Member]
Derivative [Line Items]
Loss contigency estimate of possible loss	200,000
Maximum [Member]
Derivative [Line Items]
Loss contigency estimate of possible loss	$ 21,600,000

Derivative Instruments and He_9

Derivative Instruments and Hedging Activities - Amounts Included in OCI, Income and AOCI (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) reclassified from OCI into income (effective portion)	$ 153.4	$ (373)	$ (417.3)
Derivative Instrument, Gain (Loss) Reclassified from AOCI into Income, Effective Portion, Statement of Income or Comprehensive Income [Extensible Enumeration]	Revenues	Revenues	Revenues
Commodity Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) recognized in OCI on derivatives (effective portion)	$ (153.4)	$ 373	$ 417.3
Commodity Contracts [Member] | Revenues [Member] | Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) recognized in income on derivatives	287.7	(381.7)	(73.3)
Cash Flow Hedging [Member] | Commodity Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) recognized in OCI on derivatives (effective portion)	$ 193.4	$ (5.6)	$ (534.6)

Fair Value Measurements - Addit

Fair Value Measurements - Additional Information (Details) $ in Millions	12 Months Ended
	Dec. 31, 2023 USD ($) Derivative	Dec. 31, 2022 Derivative	Dec. 31, 2021 USD ($)
Fair Value Disclosures [Abstract]
Estimated fair value of derivative instruments, net asset	$ 74.4
Derivative fair value of net liability if commodity price increases by 10 percent	42.8
Derivative fair value of net asset if commodity price decreases by 10 percent	$ (192)
Derivative contract categorized as Level 3 | Derivative	0	0
Non-cash pre-tax impairments			$ 452.3

Fair Value Measurements - Break

Fair Value Measurements - Breakdown by Fair Value Hierarchy Category for Financial Instruments (Details) - USD ($) $ in Millions		Dec. 31, 2023	Dec. 31, 2022
Financial Instruments Recorded on Our Consolidated Balance Sheets at Fair Value:
Assets from commodity derivative contracts		$ 88	$ 52.2
Derivative Asset, Statement of Financial Position [Extensible Enumeration]		Assets	Assets
Liabilities from commodity derivative contracts		$ 10.1	$ 273.4
Derivative Liability, Statement of Financial Position [Extensible Enumeration]		Liabilities, Current	Liabilities, Current
Carrying Value [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Fair Value:
Assets from commodity derivative contracts	[1]	$ 144.6	$ 201.6
Liabilities from commodity derivative contracts	[1]	70.2	457.4
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Cash and cash equivalents		141.7	219
Carrying Value [Member] | TRGP Revolver and Commercial Paper Program [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		175	1,298.7
Carrying Value [Member] | TRGP Senior Unsecured Notes [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		6,470.5	2,741.6
Carrying Value [Member] | Term Loan Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		500	1,500
Carrying Value [Member] | Securitization Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		575	800
Fair Value [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Fair Value:
Assets from commodity derivative contracts	[1]	144.6	201.6
Liabilities from commodity derivative contracts	[1]	70.2	457.4
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Cash and cash equivalents		141.7	219
Fair Value [Member] | Level 1 [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Fair Value:
Assets from commodity derivative contracts	[1]	0	0
Liabilities from commodity derivative contracts	[1]	0	0
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Cash and cash equivalents		0	0
Fair Value [Member] | Level 2 [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Fair Value:
Assets from commodity derivative contracts	[1]	144.6	201.6
Liabilities from commodity derivative contracts	[1]	70.2	457.4
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Cash and cash equivalents		0	0
Fair Value [Member] | Level 3 [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Fair Value:
Assets from commodity derivative contracts	[1]	0	0
Liabilities from commodity derivative contracts	[1]		0
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Cash and cash equivalents		0	0
Fair Value [Member] | TRGP Revolver and Commercial Paper Program [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		175	1,298.7
Fair Value [Member] | TRGP Revolver and Commercial Paper Program [Member] | Level 1 [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		0	0
Fair Value [Member] | TRGP Revolver and Commercial Paper Program [Member] | Level 2 [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		175	1,298.7
Fair Value [Member] | TRGP Revolver and Commercial Paper Program [Member] | Level 3 [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		0	0
Fair Value [Member] | TRGP Senior Unsecured Notes [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		6,598.7	2,452.6
Fair Value [Member] | TRGP Senior Unsecured Notes [Member] | Level 1 [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		0	0
Fair Value [Member] | TRGP Senior Unsecured Notes [Member] | Level 2 [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		6,598.7	2,452.6
Fair Value [Member] | TRGP Senior Unsecured Notes [Member] | Level 3 [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		0	0
Fair Value [Member] | Term Loan Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		500	1,500
Fair Value [Member] | Term Loan Facility [Member] | Level 1 [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		0	0
Fair Value [Member] | Term Loan Facility [Member] | Level 2 [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		500	1,500
Fair Value [Member] | Term Loan Facility [Member] | Level 3 [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		0	0
Fair Value [Member] | Securitization Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		575	800
Fair Value [Member] | Securitization Facility [Member] | Level 1 [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		0	0
Fair Value [Member] | Securitization Facility [Member] | Level 2 [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		575	800
Fair Value [Member] | Securitization Facility [Member] | Level 3 [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		0	0
Senior Unsecured Notes [Member] | Carrying Value [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		5,034.4	5,034.4
Senior Unsecured Notes [Member] | Fair Value [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		4,945.1	4,711.3
Senior Unsecured Notes [Member] | Fair Value [Member] | Level 1 [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		0	0
Senior Unsecured Notes [Member] | Fair Value [Member] | Level 2 [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		4,945.1	4,711.3
Senior Unsecured Notes [Member] | Fair Value [Member] | Level 3 [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
Long-term debt		$ 0	$ 0
[1] The fair value of derivative contracts in this table is presented on a different basis than the Consolidated Balance Sheets presentation as disclosed in Note 14 – Derivative Instruments and Hedging Activities. The above fair values reflect the total value of each derivative contract taken as a whole, whereas the Consolidated Balance Sheets presentation is based on the individual maturity dates of estimated future settlements. As such, an individual contract could have both an asset and liability position when segregated into its current and long-term portions for Consolidated Balance Sheets classification purposes .

Related Party Transactions - Su

Related Party Transactions - Summary of Transactions with Unconsolidated Affiliates (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Related Party Transaction [Line Items]
Revenues		$ 16,060.3	$ 20,929.8	$ 16,949.8
Operating expenses		(1,077.9)	(912.8)	(747)
Targa Resources Partners LP [Member]
Related Party Transaction [Line Items]
Product purchases and fuel		(6.4)	(29.7)	(71.3)
Targa Resources Partners LP [Member] | Related Party [Member]
Related Party Transaction [Line Items]
Revenues		7.1	9.7	15
Operating expenses		(6.7)	(5.3)	(6.1)
General and administrative expenses		(0.9)	(0.9)	(0.8)
Targa Resources Partners LP [Member] | Gulf Coast Fractionators LP [Member] | Related Party [Member]
Related Party Transaction [Line Items]
Operating expenses		(4.4)	(1.7)	(1.1)
Targa Resources Partners LP [Member] | T2 Joint Ventures [Member] | Related Party [Member]
Related Party Transaction [Line Items]
Revenues	[1]		1.2	4.4
Operating expenses	[1]		(0.7)	(2.3)
Targa Resources Partners LP [Member] | Cayenne [Member]
Related Party Transaction [Line Items]
Product purchases and fuel		(6.4)	(4.7)	(4.8)
Targa Resources Partners LP [Member] | Cayenne [Member] | Related Party [Member]
Related Party Transaction [Line Items]
Operating expenses		(0.3)	(0.3)	(0.2)
Targa Resources Partners LP [Member] | GCX [Member]
Related Party Transaction [Line Items]
Product purchases and fuel	[2]		(25)	(66.5)
Targa Resources Partners LP [Member] | Little Missouri 4 [Member] | Related Party [Member]
Related Party Transaction [Line Items]
Revenues		7.1	8.5	10.6
Operating expenses		(2)	(2.6)	(2.5)
General and administrative expenses		$ (0.9)	$ (0.9)	$ (0.8)
[1] Following the closing of the South Texas Acquisition in April 2022, the T2 Joint Ventures are 100 % owned and consolidated by Targa. Following the closing of the GCX Sale in May 2022, Targa no longer has an ownership interest in GCX.

Related Party Transactions - _2

Related Party Transactions - Summary of Transactions with Unconsolidated Affiliates (Parenthetical) (Details)	Apr. 30, 2022
Targa Resources Partners Lp [Member] | South Texas Acquisition [Member] | T2 Joint Ventures [Member]
Related Party Transaction [Line Items]
Ownership Percentage	100%

Commitments (Details)

Commitments (Details) - Land Sites and Rights-of-Way [Member] - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Future non-cancelable commitments related to certain contractual obligations for each of the next five fiscal years and in aggregate thereafter [Abstract]
In Aggregate	[1]	$ 297.4
2024	[1]	8.5
2025	[1]	8.6
2026	[1]	10.3
2027	[1]	11.7
2028	[1]	17.3
Thereafter	[1]	241
Total expenses on non-cancelable commitments		$ 9	$ 5.8	$ 5.9
[1] Land site lease and rights of way provides for surface and underground access for gathering, processing and distribution assets that are located on property not owned by us. These agreements expire at various dates, with varying terms, some of which are perpetual.

Contingencies - Additional Info

Contingencies - Additional Information (Details) - USD ($) $ in Millions					12 Months Ended
	Oct. 26, 2023	Jul. 24, 2023	Oct. 15, 2020	Dec. 26, 2018	Dec. 31, 2023
Loss Contingencies [Line Items]
Cumulative interest on award					$ 55.5
Maximum [Member]
Loss Contingencies [Line Items]
Estimated potential loss					21.6
Minimum [Member]
Loss Contingencies [Line Items]
Estimated potential loss					0.2
Vitol [Member]
Loss Contingencies [Line Items]
Lawsuit filing date				December 26, 2018
Award date			October 15, 2020
Recovery seeking			$ 129	$ 129
Damages awarded			$ 10.5
New Mexico Environment Department [Member]
Loss Contingencies [Line Items]
Loss contingency amount predicted for fine or penalty		$ 0.3
Major Winter Storm [Member]
Loss Contingencies [Line Items]
Award date	October 26, 2023
Damages awarded	$ 6.9
Major Winter Storm [Member] | Maximum [Member]
Loss Contingencies [Line Items]
Estimated potential loss					10
Major Winter Storm [Member] | Minimum [Member]
Loss Contingencies [Line Items]
Estimated potential loss					$ 0

Revenue - Additional Informatio

Revenue - Additional Information (Details) - Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2024-01-01	Dec. 31, 2023
Minimum [Member]
Revenue Remaining Performance Obligation Expected Timing Of Satisfaction [Line Items]
Remaining duration of contracts	1 year
Maximum [Member]
Revenue Remaining Performance Obligation Expected Timing Of Satisfaction [Line Items]
Remaining duration of contracts	16 years

Revenue - Estimated Minimum Rev

Revenue - Estimated Minimum Revenue Expected to be Recognized in Future Related to Unsatisfied Performance Obligations (Details) - Fixed Price Contract [Member] $ in Millions	Dec. 31, 2023 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2024-01-01
Revenue Remaining Performance Obligation Expected Timing Of Satisfaction [Line Items]
Fixed consideration to be recognized	$ 497.2
Remaining duration of contracts	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2025-01-01
Revenue Remaining Performance Obligation Expected Timing Of Satisfaction [Line Items]
Fixed consideration to be recognized	$ 419.8
Remaining duration of contracts	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2026-01-01
Revenue Remaining Performance Obligation Expected Timing Of Satisfaction [Line Items]
Fixed consideration to be recognized	$ 2,383.3
Remaining duration of contracts

Income Taxes - Components of Fe

Income Taxes - Components of Federal and State Income Tax Provisions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Income tax (expense) benefit:
Current expense (benefit)	$ 13.6	$ 6.7	$ 2.7
Deferred expense (benefit)	349.6	125.1	12.1
Total income tax expense (benefit)	$ 363.2	$ 131.8	$ 14.8

Income Taxes - Components of De

Income Taxes - Components of Deferred Income Tax Assets and Liabilities (Details) - USD ($) $ in Millions		Dec. 31, 2023	Dec. 31, 2022
Deferred tax assets:
Net operating loss		$ 1,282.9	$ 1,568.5
Disallowed business interest expense carryforward		79.3	10.3
Deferred tax assets before valuation allowance		1,362.2	1,578.8
Valuation allowance		(7.1)	(36.9)
Deferred tax assets		1,355.1	1,541.9
Deferred tax liabilities:
Investments	[1]	(1,867.9)	(1,842)
Property, plant, and equipment		(3)	(4.2)
Other		(20)	(23.4)
Deferred tax liabilities		(1,890.9)	(1,869.6)
Net deferred tax asset (liability)		(535.8)	(327.7)
Net deferred tax asset (liability)
Federal		(507)	(290.5)
State		(28.8)	(37.2)
Net deferred tax asset (liability)		$ (535.8)	$ (327.7)
[1] Our deferred tax liability attributable to investments reflects the differences between the book and tax carrying values of our investment in the Partnership.

Income Taxes - Additional Infor

Income Taxes - Additional Information (Details) - USD ($)	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2021	Dec. 31, 2022	Aug. 16, 2022
Operating Loss Carryforwards [Line Items]
Additional income tax expense		$ 23,300,000
Maximum percentage of taxable income allowed to offset by net operating loss carryforwards per year	80%
Tax-effected valuation allowance	$ 7,100,000		$ 36,900,000
Increase (decrease) in valuation allowance	(29,800,000)
Uncertain tax reserves	0
Federal [Member]
Operating Loss Carryforwards [Line Items]
Total net operating loss carryforwards	$ 5,500,000,000
Operating loss carryforwards expiry date	Dec. 31, 2037
Tax-effected valuation allowance			6,400,000
State [Member]
Operating Loss Carryforwards [Line Items]
Tax-effected valuation allowance			$ 700,000
Expire in 2037 [Member] | Federal [Member]
Operating Loss Carryforwards [Line Items]
Total net operating loss carryforwards	$ 857,400,000
No Expiration Period [Member]
Operating Loss Carryforwards [Line Items]
Total net operating loss carryforwards	$ 4,700,000,000
Inflation Reduction Act [Member]
Operating Loss Carryforwards [Line Items]
Excise tax percentage on stock buybacks and tax incentives				1%
Corporate alternative minimum tax percentage				15%
Average annual adjusted financial statement income				$ 1,000,000,000

Income Taxes - Income Tax Recon

Income Taxes - Income Tax Reconciliation (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Income tax reconciliation:
Income (loss) before income taxes	$ 1,942.5	$ 1,663.2	$ 436.9
Less: Net income attributable to noncontrolling interest	(233.4)	(335.9)	(350.9)
Income attributable to Targa Resources Corp. before income taxes	$ 1,709.1	$ 1,327.3	$ 86
Federal statutory income tax rate	21%	21%	21%
Provision for federal income taxes	$ 358.9	$ 278.7	$ 18.1
Valuation allowance	(29.8)	(177.5)	(46.2)
State income taxes, net of federal tax benefit	37.8	33.6	(5.4)
State tax provision error correction	0	0	23.3
Return-to-provision	(5.7)	(0.6)	(1.3)
Change in income tax rate	11.5	(1.7)	21
Permanent adjustments	6.2	5.6	4.1
Stock compensation shortfall/(windfall)	(15.8)	(6.3)	1.4
Other, net	0.1	0	(0.2)
Total income tax expense (benefit)	$ 363.2	$ 131.8	$ 14.8

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Cash:
Interest paid, net of capitalized interest	[1]	$ 618.6	$ 401.3	$ 356
Income taxes (received) paid, net		8.5	1.6	1.3
Non-cash investing activities:
Change in deadstock commodity inventory		(13.7)	(3.8)	(15)
Impact of capital expenditure accruals on property, plant and equipment, net		58.2	60.1	53
Transfers from materials and supplies inventory to property, plant and equipment				2.4
Change in ARO liability and property, plant and equipment due to revised cash flow estimate and additions		4.9	0.8	(0.2)
Non-cash financing activities:
Changes in accrued distributions to noncontrolling interests		8.9	(26.1)	(50.9)
Reduction of owner's equity related to accrued dividends on unvested equity awards under share compensation arrangements		3.9	7.1	3.1
Non-cash distributions to noncontrolling interests	[2]		64.2
Accretion of deemed dividends on Series A Preferred			215.5
Lease liabilities arising from recognition of right-of-use assets:
Operating lease		53.1	9.7	20.1
Finance lease	[3]	$ 104.8	$ 220.7	$ 24.7
[1] Interest capitalized on major projects was $ 41.1 million, $ 16.3 million and $ 4.1 million for the years ended December 31, 2023, 2022 and 2021 . Represents the transfer of an undivided interest in certain gas gathering and processing facilities to a joint owner upon Targa ’ s recovery of a specified payout amount for our initial full funding of the facilities. The December 31, 2022 amount includes $ 171.2 million related to compressor leases from the Delaware Basin Acquisition that were subsequently amended and extended.

Supplemental Cash Flow Inform_4

Supplemental Cash Flow Information (Parenthetical) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Lessee, Lease, Description [Line Items]
Interest capitalized on major projects		$ 41.1	$ 16.3	$ 4.1
Finance Lease, Asset	[1]	351.9	266.1
Compressor [Member] | Delaware Basin Acquisition
Lessee, Lease, Description [Line Items]
Finance Lease, Asset		$ 171.2	$ 171.2
[1] The December 31, 2022 balance includes $ 171.2 million of assets and $ 167.0 million of liabilities related to compressor leases from the Delaware Basin Acquisition that were subsequently amended and extended.

Compensation Plans - Additional

Compensation Plans - Additional Information (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended	12 Months Ended
	Jan. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	May 31, 2017
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock compensation expense		$ 62.4	$ 57.5	$ 59.2
Unrecognized compensation expense		$ 87.5
Remaining weighted average vesting periods of unrecognized compensation expenses		2 years 3 months 18 days
Employer matching contribution percent		100%
Defined Contribution Plan, Plans Name [Extensible Enumeration]		http://www.targaresources.com/#FourZeroOneKPlansMember
Percentage of employees' gross pay for which employer contributes matching contribution		5%
Percentage of additional contribution per employee made by employer		3%
Percentage of contributions made in cash		100%
Contributions to defined contribution plan		$ 32.3	26.6	21.8
Accounting Standard Update 2016-09 [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Tax deficiencies of dividends on share-based compensation recognized as income tax expenses		$ 17	$ 6.7	$ 1.6
Restricted Stock Units (RSUs) [Member] | Subsequent Event [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Vested (in shares)	320,549
Shares withheld to satisfy tax withholding obligations	127,443
PSUs [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Expected volatility, minimum			80%
Expected volatility, maximum		38%		80%
PSUs [Member] | Subsequent Event [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Vested (in shares)	765,478
Shares withheld to satisfy tax withholding obligations	296,600
Director Grants [Member] | Subsequent Event [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Vested (in shares)	23,518
Shares withheld to satisfy tax withholding obligations	0
Unvested Restricted Stock Awards [Member] | Minimum [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Vesting period of awards		3 years
2010 TRC Stock Incentive Plan [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Fair values of share-based awards vested		$ 96.8	$ 93	$ 73.8
Cash dividends paid for the vested awards		$ 8.3	$ 9.6	$ 8.7
2010 TRC Stock Incentive Plan [Member] | Restricted Stock Units (RSUs) [Member] | Outside Directors [Member] | Subsequent Event [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Vesting date	2025-01
2010 TRC Stock Incentive Plan [Member] | Restricted Stock Units (RSUs) [Member] | 2024 Compensation Cycle [Member] | Third Year [Member] | Executive Management | Subsequent Event [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Granted (in shares)	128,316
Vesting date	2027-01
2010 TRC Stock Incentive Plan [Member] | PSUs [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Outstanding (in shares)		596,300	769,917
Granted (in shares)		140,020
Granted (in dollars per shares)		$ 128.71
Vesting period of awards			3 years
Expected term of grant date fair value		3 years
Vested (in shares)		291,365
2010 TRC Stock Incentive Plan [Member] | PSUs [Member] | 2021 Compensation Cycle [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Granted (in shares)				319,320
Vesting date				2024-01
2010 TRC Stock Incentive Plan [Member] | PSUs [Member] | 2023 Compensation Cycle [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Granted (in shares)		140,020
Vesting date		2026-01
2010 TRC Stock Incentive Plan [Member] | PSUs [Member] | 2024 Compensation Cycle [Member] | Executive Management | Subsequent Event [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Granted (in shares)	128,316
Vesting date	2027-01
2010 TRC Stock Incentive Plan [Member] | PSUs [Member] | 2022 Compensation Cycle [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Granted (in shares)			173,011
Vesting date			2025-01
2010 TRC Stock Incentive Plan [Member] | Restricted Stock Units In Lieu Of Bonus [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Granted (in shares)					81,336	95,687
Granted (in dollars per shares)					$ 41.39	$ 42.83
2010 TRC Stock Incentive Plan [Member] | Unvested Restricted Stock Awards [Member] | Outside Directors [Member] | Subsequent Event [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Granted (in shares)	20,414
2010 TRGP Plan [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Total number of units authorized (in shares)							15,000,000
Total number of units available (in shares)							5,000,000
Total number of additional units available (in shares)							10,000,000
2010 TRGP Plan [Member] | Restricted Stock Units (RSUs) [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Granted (in shares)		587,326	943,352	848,630
Granted (in dollars per shares)		$ 78.69	$ 63.87	$ 37.94
2010 TRGP Plan [Member] | Director Grants [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Granted (in shares)		23,518	31,117	67,591
Granted (in dollars per shares)		$ 74.13	$ 56.32	$ 30.33

Compensation Plans - 2010 TRC S

Compensation Plans - 2010 TRC Stock Incentive Plan (Details) - 2010 TRC Stock Incentive Plan [Member] - Restricted Stock and Restricted Stock Units [Member]	12 Months Ended
	Dec. 31, 2023 $ / shares shares
Nonvested, number of shares [Roll Forward]
Outstanding, beginning of period (in shares) | shares	3,228,418
Granted (in shares) | shares	610,844
Forfeited (in shares) | shares	(95,643)
Vested (in shares) | shares	(1,435,823)
Outstanding, end of period (in shares) | shares	2,307,796
Weighted-average grant-date fair value [Roll Forward]
Outstanding, beginning period (in dollars per share) | $ / shares	$ 42.60
Granted (in dollars per shares) | $ / shares	78.52
Forfeited (in dollars per share) | $ / shares	61.92
Vested (in dollars per share) | $ / shares	32.05
Outstanding, end of period (in dollars per share) | $ / shares	$ 57.84

Compensation Plans - Summary of

Compensation Plans - Summary of PSUs Under 2010 TRC Stock Incentive Plan (Details) - 2010 TRC Stock Incentive Plan [Member] - PSUs [Member]	12 Months Ended
	Dec. 31, 2023 $ / shares shares
Nonvested, number of shares [Roll Forward]
Outstanding, beginning of period (in shares) | shares	769,917
Granted (in shares) | shares	140,020
Forfeited (in shares) | shares	(22,272)
Vested (in shares) | shares	(291,365)
Outstanding, end of period (in shares) | shares	596,300
Weighted-average grant-date fair value [Roll Forward]
Outstanding, beginning period (in dollars per share) | $ / shares	$ 72.81
Granted (in dollars per shares) | $ / shares	128.71
Forfeited (in dollars per share) | $ / shares	117.52
Vested (in dollars per share) | $ / shares	69.70
Outstanding, end of period (in dollars per share) | $ / shares	$ 85.78

Segment Information - Additiona

Segment Information - Additional Information (Details)	12 Months Ended
	Dec. 31, 2023 Segment
Segment Reporting [Abstract]
Number of reportable segments	2

Segment Information - Revenues

Segment Information - Revenues and Operating Margin (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Revenues:
Revenues		$ 16,060.3	$ 20,929.8	$ 16,949.8
Sales of Commodities [Member]
Revenues:
Revenues		13,962.1	19,066	15,602.5
Fees from Midstream Services [Member]
Revenues:
Revenues		2,098.2	1,863.8	1,347.3
Gathering and Processing [Member]
Revenues:
Revenues		7,231.5	11,247	7,425.5
Operating margin	[1]	2,082.2	1,981	1,325.3
Logistics and Transportation [Member]
Revenues:
Revenues		13,655.8	19,742.1	16,159.7
Operating margin	[1]	1,948.7	1,456.3	1,264.3
Other [Member]
Revenues:
Revenues		275.5	(302.4)	(115.9)
Operating margin	[1]	275.5	(302.4)	(115.9)
Corporate and Eliminations [Member]
Revenues:
Revenues		(5,102.5)	(9,756.9)	(6,519.5)
Operating Segments [Member]
Revenues:
Revenues		16,060.3	20,929.8	16,949.8
Operating Segments [Member] | Sales of Commodities [Member]
Revenues:
Revenues		13,962.1	19,066	15,602.5
Operating Segments [Member] | Fees from Midstream Services [Member]
Revenues:
Revenues		2,098.2	1,863.8	1,347.3
Operating Segments [Member] | Gathering and Processing [Member]
Revenues:
Revenues		2,442.6	2,077	1,354.1
Operating Segments [Member] | Gathering and Processing [Member] | Sales of Commodities [Member]
Revenues:
Revenues		1,076.1	919.7	606.8
Operating Segments [Member] | Gathering and Processing [Member] | Fees from Midstream Services [Member]
Revenues:
Revenues		1,366.5	1,157.3	747.3
Operating Segments [Member] | Logistics and Transportation [Member]
Revenues:
Revenues		13,342.2	19,155.2	15,711.6
Operating Segments [Member] | Logistics and Transportation [Member] | Sales of Commodities [Member]
Revenues:
Revenues		12,610.5	18,448.7	15,111.6
Operating Segments [Member] | Logistics and Transportation [Member] | Fees from Midstream Services [Member]
Revenues:
Revenues		731.7	706.5	600
Operating Segments [Member] | Other [Member]
Revenues:
Revenues		275.5	(302.4)	(115.9)
Operating Segments [Member] | Other [Member] | Sales of Commodities [Member]
Revenues:
Revenues		275.5	(302.4)	(115.9)
Intersegment Eliminations [Member] | Gathering and Processing [Member]
Revenues:
Revenues		4,788.9	9,170	6,071.4
Intersegment Eliminations [Member] | Gathering and Processing [Member] | Sales of Commodities [Member]
Revenues:
Revenues		4,786.3	9,169.4	6,067.9
Intersegment Eliminations [Member] | Gathering and Processing [Member] | Fees from Midstream Services [Member]
Revenues:
Revenues		2.6	0.6	3.5
Intersegment Eliminations [Member] | Logistics and Transportation [Member]
Revenues:
Revenues		313.6	586.9	448.1
Intersegment Eliminations [Member] | Logistics and Transportation [Member] | Sales of Commodities [Member]
Revenues:
Revenues		267.9	541.7	409.5
Intersegment Eliminations [Member] | Logistics and Transportation [Member] | Fees from Midstream Services [Member]
Revenues:
Revenues		45.7	45.2	38.6
Intersegment Eliminations [Member] | Corporate and Eliminations [Member]
Revenues:
Revenues		(5,102.5)	(9,756.9)	(6,519.5)
Intersegment Eliminations [Member] | Corporate and Eliminations [Member] | Sales of Commodities [Member]
Revenues:
Revenues		(5,054.2)	(9,711.1)	(6,477.4)
Intersegment Eliminations [Member] | Corporate and Eliminations [Member] | Fees from Midstream Services [Member]
Revenues:
Revenues		$ (48.3)	$ (45.8)	$ (42.1)
[1] Operating margin is calculated by subtracting Product purchases and fuel and Operating expenses from Revenues.

Segment Information - Other Fin

Segment Information - Other Financial Information (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Other financial information [Abstract]
Total assets		$ 20,671.8	$ 19,560
Goodwill		45.2	45.2
Operating Segments [Member]
Other financial information [Abstract]
Total assets	[1]	20,671.8	19,560	$ 15,208.2
Goodwill		45.2	45.2	45.2
Capital expenditures		2,443.6	1,394.4	560.5
Operating Segments [Member] | Gathering and Processing [Member]
Other financial information [Abstract]
Total assets	[1]	12,685.2	12,133.6	7,998.1
Goodwill		45.2	45.2	45.2
Capital expenditures		1,514.7	918.1	471.7
Operating Segments [Member] | Logistics and Transportation [Member]
Other financial information [Abstract]
Total assets	[1]	7,777.8	7,175.7	7,041.9
Capital expenditures		910	453	78.1
Operating Segments [Member] | Other [Member]
Other financial information [Abstract]
Total assets	[1]	4.2		14
Operating Segments [Member] | Corporate and Eliminations [Member]
Other financial information [Abstract]
Total assets	[1]	204.6	250.7	154.2
Capital expenditures		$ 18.9	$ 23.3	$ 10.7
[1] Assets in the Corporate and Eliminations column primarily include tax-related assets, cash, prepaids and debt issuance costs for our revolving credit facilities.

Segment Information - Summary o

Segment Information - Summary of Consolidated Revenues Disaggregated by Product and Service (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Revenue from External Customer [Line Items]
Revenue recognized		$ 13,521	$ 19,820.7	$ 16,093.1
Non-customer revenue		441.1	(754.7)	(490.6)
Total revenues		16,060.3	20,929.8	16,949.8
Derivative Activities - Hedge [Member]
Revenue from External Customer [Line Items]
Non-customer revenue		153.4	(373)	(417.3)
Derivative Activities - Non-hedge [Member]
Revenue from External Customer [Line Items]
Non-customer revenue	[1]	287.7	(381.7)	(73.3)
Natural Gas [Member]
Revenue from External Customer [Line Items]
Revenue recognized		2,421.3	5,470.2	3,523.9
NGL [Member]
Revenue from External Customer [Line Items]
Revenue recognized		10,580.2	13,785.2	12,210.8
Condensate and Crude Oil [Member]
Revenue from External Customer [Line Items]
Revenue recognized		519.5	565.3	358.4
Gathering and Processing [Member]
Revenue from External Customer [Line Items]
Revenue recognized		1,342.8	1,137.2	730.3
Sales of Commodities [Member]
Revenue from External Customer [Line Items]
Total revenues		13,962.1	19,066	15,602.5
Other [Member]
Revenue from External Customer [Line Items]
Revenue recognized		53.6	69.3	46.7
NGL Transportation, Fractionation and Services [Member]
Revenue from External Customer [Line Items]
Revenue recognized		261.1	285.1	190.6
Storage Terminaling and Export [Member]
Revenue from External Customer [Line Items]
Revenue recognized		440.7	372.2	379.7
Fees from Midstream Services [Member]
Revenue from External Customer [Line Items]
Revenue recognized		2,098.2	1,863.8	1,347.3
Total revenues		$ 2,098.2	$ 1,863.8	$ 1,347.3
[1] Represents derivative activities that are not designated as hedging instruments under ASC 815.

Segment Information - Reconcili

Segment Information - Reconciliation of Reportable Segment Operating Margin to Income (Loss) Before Income Taxes (Details) - USD ($) $ in Millions		3 Months Ended	12 Months Ended
		Dec. 31, 2021	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Reconciliation of reportable segment operating margin to income (loss) before income taxes:
Depreciation and amortization expense			$ (1,329.6)	$ (1,096)	$ (870.6)
General and administrative expense			(348.7)	(309.7)	(273.2)
Other operating income (expense)			(1.5)	(0.2)	(12.4)
Impairment of long-lived assets		$ (452.3)			(452.3)
Interest expense, net			(687.8)	(446.1)	(387.9)
Equity earnings (loss)			9	9.1	(23.9)
Gain (loss) from financing activities			(2.1)	(49.6)	(16.6)
Gain (loss) from sale of equity-method investment				435.9
Other, net			(3.2)	(15.1)	0.1
Income (loss) before income taxes			1,942.5	1,663.2	436.9
Gathering and Processing [Member]
Reconciliation of reportable segment operating margin to income (loss) before income taxes:
Operating margin	[1]		2,082.2	1,981	1,325.3
Logistics and Transportation [Member]
Reconciliation of reportable segment operating margin to income (loss) before income taxes:
Operating margin	[1]		1,948.7	1,456.3	1,264.3
Other [Member]
Reconciliation of reportable segment operating margin to income (loss) before income taxes:
Operating margin	[1]		$ 275.5	$ (302.4)	$ (115.9)
[1] Operating margin is calculated by subtracting Product purchases and fuel and Operating expenses from Revenues.