HF Sinclair (DINO) 10-Q8 May 242024 Q1 Quarterly reportFinancial data

Company Profile

Cover Page

Cover Page - shares	3 Months Ended
Cover Page - shares	Mar. 31, 2024	May 03, 2024
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2024
Document Transition Report	false
Entity File Number	1-41325
Entity Registrant Name	HF SINCLAIR CORPORATION
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	87-2092143
Entity Address, Address Line One	2828 N. Harwood,
Entity Address, Address Line Two	Suite 1300
Entity Address, City or Town	Dallas
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	75201
City Area Code	214
Local Phone Number	871-3555
Title of 12(b) Security	Common Stock $0.01 par value
Trading Symbol	DINO
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding (in shares)		192,157,440
Entity Central Index Key	0001915657
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2024
Document Fiscal Period Focus	Q1
Amendment Flag	false

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Mar. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Current assets:
Cash and cash equivalents	$ 1,240,860	$ 1,353,747	$ 1,665,066
Accounts receivable: Product and transportation	1,649,800	1,527,950	1,626,199
Crude oil resales	163,777	197,169	76,950
Accounts receivable, total	1,813,577	1,725,119	1,703,149
Inventories: Crude oil and refined products	2,868,039	2,645,724	2,853,425
Materials, supplies and other	262,846	276,107	361,103
Total inventory	3,130,885	2,921,831	3,214,528
Income taxes receivable	42,841	56,528	53,563
Prepayments and other	94,297	89,229	112,013
Total current assets	6,322,460	6,146,454	6,748,319
Properties, plants and equipment, at cost	10,609,735	10,533,432	10,146,652
Less: accumulated depreciation	(4,021,845)	(3,906,600)	(3,457,747)
Properties, plants and equipment, net	6,587,890	6,626,832	6,688,905
Operating lease right-of-use assets	390,566	348,006	351,068
Other assets: Turnaround costs	660,306	644,957	376,158
Goodwill	2,977,511	2,977,744	2,978,315
Intangibles and other	977,257	972,272	982,718
Other assets, total	4,615,074	4,594,973	4,337,191
Total assets	17,915,990	17,716,265	18,125,483
Current liabilities:
Accounts payable	2,276,556	2,205,759	2,334,107
Income taxes payable	57,440	8,772	7,818
Operating lease liabilities	97,973	106,973	109,926
Current debt		0	306,959
Accrued liabilities	485,966	453,045	486,719
Total current liabilities	2,917,935	2,774,549	3,245,529
Long-term debt, net	2,678,645	2,739,083	2,948,513
Noncurrent operating lease liabilities	309,370	249,479	254,215
Deferred income taxes	1,307,585	1,297,130	1,262,165
Other long-term liabilities	426,366	418,726	397,489
Total liabilities	7,639,901	7,478,967
Commitments and Contingencies (see Note 13)
HF Sinclair stockholders’ equity:
Preferred stock, $1.00 par value – 5,000,000 shares authorized; none issued	0	0	0
Common stock $0.01 par value – 320,000,000 shares authorized; 223,231,546 shares issued as of March 31, 2024 and December 31, 2023, respectively	2,232	2,232	2,232
Additional capital	5,991,464	5,993,661	6,468,775
Retained earnings	5,594,493	5,379,182	4,130,252
Accumulated other comprehensive loss	(22,277)	(11,784)	(22,013)
Common stock held in treasury, at cost – 26,077,193 and 23,235,599 shares as of March 31, 2024 and December 31, 2023, respectively	(1,357,594)	(1,194,201)	(1,335,431)
Total HF Sinclair stockholders’ equity	10,208,318	10,169,090	9,243,815
Noncontrolling interest	67,771	68,208	773,757
Total equity	10,276,089	10,237,298	10,017,572
Total liabilities and equity	$ 17,915,990	$ 17,716,265	$ 18,125,483

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares	Mar. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Statement of Financial Position [Abstract]
Preferred stock par value (in USD per share)	$ 1	$ 1	$ 1
Preferred stock, shares authorized (in shares)	5,000,000	5,000,000	5,000,000
Preferred stock, shares issued (in shares)	0	0	0
Common stock par value (in USD per share)	$ 0.01	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	320,000,000	320,000,000	320,000,000
Common stock, shares issued (in shares)	223,231,546	223,231,546	223,231,546
Common stock held in treasury (in shares)	26,077,193	23,235,599	26,152,344

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Income Statement [Abstract]
Sales and other revenues	$ 7,027,145	$ 7,565,142	$ 31,964,395	$ 38,204,839	$ 18,389,142
Cost of products sold (exclusive of depreciation and amortization):
Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment)	5,926,500	6,104,057	25,784,449	30,680,013	15,567,052
Lower of cost or market inventory valuation adjustment	(219,370)	47,597	270,419	52,412	(310,123)
Cost of products sold (exclusive of depreciation and amortization)	5,707,130	6,151,654	26,054,868	30,732,425	15,256,929
Operating expenses (exclusive of depreciation and amortization)	607,112	639,383	2,438,148	2,334,893	1,517,478
Selling, general and administrative expenses (exclusive of depreciation and amortization)	103,374	95,913	498,240	426,485	362,010
Depreciation and amortization	198,729	173,983	770,573	656,787	503,539
Total operating costs and expenses	6,616,345	7,060,933	29,761,829	34,150,590	17,639,956
Income from operations	410,800	504,209	2,202,566	4,054,249	749,186
Other income (expense):
Earnings of equity method investments	7,346	3,882	17,369	(260)	12,432
Interest income	22,179	19,935	93,468	30,179	4,019
Interest expense	(40,691)	(45,822)	(190,796)	(175,628)	(125,175)
Gain on business interruption insurance settlement			0	15,202	0
Gain on tariff settlement			0	0	51,500
Loss on early extinguishment of debt			0	604	0
Gain on foreign currency transactions	443	870	2,530	(1,637)	(2,938)
Gain on sale of assets and other	2,019	1,631	27,370	13,337	98,128
Other income (expense) total	(8,704)	(19,504)	(50,059)	(118,203)	37,966
Income before income taxes:	402,096	484,705	2,152,507	3,936,046	787,152
Income tax expense:
Current	70,705	84,395	249,062	841,704	(4,672)
Deferred	14,769	15,305	192,550	53,168	128,570
Income tax expense (benefit) total	85,474	99,700	441,612	894,872	123,898
Net income	316,622	385,005	1,710,895	3,041,174	663,254
Less: net income attributable to noncontrolling interest	1,958	31,739	121,229	118,506	104,930
Net income attributable to HF Sinclair stockholders	$ 314,664	$ 353,266	$ 1,589,666	$ 2,922,668	$ 558,324
Earnings per share:
Basic (in USD per share)	$ 1.57	$ 1.79	$ 8.29	$ 14.28	$ 3.39
Diluted (in USD per share)	$ 1.57	$ 1.79	$ 8.29	$ 14.28	$ 3.39
Average number of common shares outstanding:
Basic (in shares)	198,710	195,445	190,035	202,566	162,569
Diluted (in shares)	198,710	195,445	190,035	202,566	162,569

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Net income	$ 316,622	$ 385,005	$ 1,710,895	$ 3,041,174	$ 663,254
Other comprehensive income (loss):
Foreign currency translation adjustment	(12,606)	2,926	13,161	(32,383)	(13,336)
Change in fair value of cash flow hedging instruments	(4,287)	270	(3,236)	(4,962)	(17,548)
Reclassification adjustments to net income on settlement of cash flow hedging instruments	4,287	1	3,236	5,288	17,579
Net unrealized gain on hedging instruments	0	271	0	326	31
Retirement restoration plan loss reclassified to net income	6	3
Net change in pension and other post-retirement benefit obligations	(699)	(960)	101	789	(457)
Other comprehensive income (loss) before income taxes	(13,305)	2,237	13,262	(31,268)	(13,762)
Income tax expense (benefit)	(2,812)	447	3,033	(6,584)	(2,971)
Other comprehensive income (loss)	(10,493)	1,790	10,229	(24,684)	(10,791)
Total comprehensive income	306,129	386,795	1,721,124	3,016,490	652,463
Less: noncontrolling interest in comprehensive income	1,958	31,739	121,229	118,506	104,930
Comprehensive income attributable to HF Sinclair stockholders	304,171	355,056	1,599,895	2,897,984	547,533
Pension obligations
Other comprehensive income (loss):
Actuarial gain (loss) on plan			1,909	(3,836)	2,104
Plan (gain) loss reclassified to net income	217	(45)	1,378	(208)	(407)
Post-retirement healthcare obligations
Other comprehensive income (loss):
Actuarial gain (loss) on plan			761	7,885	1,133
Plan (gain) loss reclassified to net income	$ (922)	$ (918)	(3,859)	(3,440)	(3,328)
Retirement restoration plan
Other comprehensive income (loss):
Actuarial gain (loss) on retirement restoration plan			(99)	349	2
Retirement restoration plan loss reclassified to net income			$ 11	$ 39	$ 39

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Cash flows from operating activities:
Net income	$ 316,622	$ 385,005	$ 1,710,895	$ 3,041,174	$ 663,254
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	198,729	173,983	770,573	656,787	503,539
Lower of cost or market inventory valuation adjustment	(219,370)	47,597	270,419	52,412	(310,123)
Earnings of equity method investments, inclusive of distributions	(3,821)	(1,799)	8,093	19,769	0
Early extinguishment loss on debt			0	(604)	0
Gain on sale of assets	(782)	(414)	(6,879)	(2,118)	(89,765)
Deferred income taxes	14,769	15,305	192,550	53,168	128,570
Equity-based compensation expense	5,380	3,325	41,135	30,318	39,273
Change in fair value – derivative instruments	(7,764)	15,402	16,555	9,989	(34,096)
(Increase) decrease in current assets:
Accounts receivable	(92,036)	86,369	(17,131)	(4,282)	(614,407)
Inventories	1,120	(280,263)	30,246	(224,421)	(344,559)
Income taxes receivable	13,462	10,494	(2,691)	42,641	(6,415)
Prepayments and other	1,263	28,007	8,062	(40,810)	(18,672)
Increase (decrease) in current liabilities:
Accounts payable	64,664	(220,018)	(108,859)	194,424	612,410
Income taxes payable	48,689	51,697	925	(17,169)	23,158
Accrued liabilities	30,655	32,424	(29,619)	78,349	83,602
Turnaround expenditures	(70,379)	(163,734)	(555,697)	(144,759)	(214,431)
Other, net	15,694	(5,675)	(31,342)	32,291	(14,656)
Net cash provided by operating activities	316,895	177,705	2,297,235	3,777,159	406,682
Cash flows from investing activities:
Additions to properties, plants and equipment	(89,108)	(100,069)	(353,451)	(485,043)	(725,073)
Acquisitions, net of cash acquired			0	(251,448)	(624,332)
Proceeds from sale of assets	811	1,572	17,361	3,344	106,357
Investment in Osage Pipe Line Company LLC	(5,000)	(2,500)
Distributions from equity method investments in excess of equity earnings	1,925	760	4,211	10,623	4,165
Net cash used for investing activities	(91,372)	(100,237)	(371,323)	(774,488)	(1,327,219)
Cash flows from financing activities:
Borrowings under credit agreements	0	42,000	60,000	510,000	555,500
Repayments under credit agreements	(61,500)	(58,500)	(272,500)	(682,000)	(629,000)
Redemption of senior notes - HEP			(307,827)	(41,420)	0
Purchase of treasury stock	(169,612)	(245,566)	(999,282)	(1,371,700)	(7,058)
Dividends	(99,353)	(87,987)	(340,736)	(255,928)	(57,663)
Distributions to noncontrolling interests	(2,395)	(25,986)	(102,523)	(96,192)	(75,395)
Contributions from noncontrolling interests			0	0	23,194
Payments on finance leases	(2,600)	(3,071)	(11,923)	(11,713)	(3,990)
HEP Merger Transaction consideration			(267,592)	0	0
Deferred financing costs			(899)	(9,273)	(14,500)
Other, net			(600)	(2,533)	(2,891)
Net cash used for financing activities	(335,460)	(379,110)	(2,243,882)	(1,560,759)	(211,803)
Effect of exchange rate on cash flow	(2,950)	1,506	6,651	(11,290)	(1,534)
Cash and cash equivalents:
Decrease for the period	(112,887)	(300,136)	(311,319)	1,430,622	(1,133,874)
Beginning of period	1,353,747	1,665,066	1,665,066	234,444	1,368,318
End of period	1,240,860	1,364,930	1,353,747	1,665,066	234,444
Cash paid during the period for:
Interest	(23,600)	(25,934)	(203,063)	(160,409)	(136,429)
Income taxes, net	(7,644)	(22,010)	(250,815)	(816,379)	19,760
Decrease in accrued and unpaid capital expenditures	$ (5,678)	$ (17,819)	(5,924)	(31,714)	(15,319)
HEP
Cash flows from investing activities:
Additions to properties, plants and equipment			(31,962)	(38,964)	(88,336)
Investment in Osage Pipe Line Company LLC			(7,482)	(13,000)	0
Cash flows from financing activities:
Proceeds from issuance of senior notes - HEP			$ 0	$ 400,000	$ 0

CONSOLIDATED STATEMENTS OF EQUI

CONSOLIDATED STATEMENTS OF EQUITY - USD ($) $ in Thousands	Total	Common Stock	Additional Capital	Retained Earnings	Accumulated other comprehensive loss	Treasury Stock	Non-controlling Interest
Common stock outstanding at beginning of period (in shares) at Dec. 31, 2020		256,046,000
Stockholders' equity at beginning of period at Dec. 31, 2020	$ 5,722,203	$ 2,560	$ 4,207,672	$ 3,913,179	$ 13,462	$ (2,968,512)	$ 553,842
Treasury stock outstanding at beginning of period (in shares) at Dec. 31, 2020						93,632,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	663,254			558,324			104,930
Dividends	(57,663)			(57,663)
Other comprehensive income (loss), net of tax	(10,791)				(10,791)
Issuance of common shares under incentive compensation plans (in shares)						(804,000)
Issuance of common shares under incentive compensation plans	0		(24,313)			$ 24,313
Equity-based compensation	39,273		36,716				2,557
Purchase of treasury stock, inclusive of excise tax (in shares)						217,000
Purchase of treasury stock, inclusive of excise tax	(7,058)					$ (7,058)
Distributions to noncontrolling interest holders	(75,395)						(75,395)
Contributions from noncontrolling interests	23,194						23,194
Purchase of HEP units for equity grants	(2,548)						(2,548)
Other	(4)			(4)
Common stock outstanding at end of period (in shares) at Dec. 31, 2021		256,046,000
Stockholders' equity at end of period at Dec. 31, 2021	6,294,465	$ 2,560	4,220,075	4,413,836	2,671	$ (2,951,257)	606,580
Treasury stock outstanding at end of period (in shares) at Dec. 31, 2021						93,045,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	3,041,174			2,922,668			118,506
Dividends	(255,928)			(255,928)
Other comprehensive income (loss), net of tax	(24,684)				(24,684)
Common shares issued in connection with Sinclair Transactions (in shares)		60,230,000
Issuance of common shares for HFC Transactions	2,149,008	$ 602	2,148,406
Issuance of common shares under incentive compensation plans (in shares)						(849,000)
Issuance of common shares under incentive compensation plans	0		(42,962)			$ 42,962
Equity-based compensation	$ 30,318		28,474				1,844
Purchase of treasury stock, inclusive of excise tax (in shares)	25,716,042					27,001,000
Purchase of treasury stock, inclusive of excise tax	$ (1,378,390)					$ (1,378,390)
Retirement of treasury stock (in shares)		(93,045,000)				(93,045,000)
Retirement of treasury stock	0	$ (930)		(2,950,324)		$ 2,951,254
Distributions to noncontrolling interest holders	(96,192)						(96,192)
Purchase of HEP units for equity grants	(2,363)						(2,363)
Equity attributable to HEP common unit issuance, net of tax	318,439		95,047				223,392
Acquisition of remaining UNEV interests	(58,275)		19,735				(78,010)
Common stock outstanding at end of period (in shares) at Dec. 31, 2022		223,231,000
Stockholders' equity at end of period at Dec. 31, 2022	$ 10,017,572	$ 2,232	6,468,775	4,130,252	(22,013)	$ (1,335,431)	773,757
Treasury stock outstanding at end of period (in shares) at Dec. 31, 2022	26,152,344					26,152,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	$ 385,005			353,266			31,739
Dividends	(87,987)			(87,987)
Other comprehensive income (loss), net of tax	1,790				1,790
Issuance of common shares under incentive compensation plans (in shares)						(38,000)
Issuance of common shares under incentive compensation plans	0		(1,934)			$ 1,934
Equity-based compensation	$ 3,325		2,973				352
Purchase of treasury stock, inclusive of excise tax (in shares)	4,793,857					4,810,000
Purchase of treasury stock, inclusive of excise tax	$ (243,192)					$ (243,192)
Distributions to noncontrolling interest holders	(25,986)						(25,986)
Common stock outstanding at end of period (in shares) at Mar. 31, 2023		223,231,000
Stockholders' equity at end of period at Mar. 31, 2023	10,050,527	$ 2,232	6,469,814	4,395,531	(20,223)	$ (1,576,689)	779,862
Treasury stock outstanding at end of period (in shares) at Mar. 31, 2023						30,924,000
Common stock outstanding at beginning of period (in shares) at Dec. 31, 2022		223,231,000
Stockholders' equity at beginning of period at Dec. 31, 2022	$ 10,017,572	$ 2,232	6,468,775	4,130,252	(22,013)	$ (1,335,431)	773,757
Treasury stock outstanding at beginning of period (in shares) at Dec. 31, 2022	26,152,344					26,152,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	$ 1,710,895			1,589,666			121,229
Dividends	(340,736)			(340,736)
Other comprehensive income (loss), net of tax	10,229				10,229
Issuance of common shares under incentive compensation plans (in shares)						(957,000)
Issuance of common shares under incentive compensation plans	0		(49,229)			$ 49,229
Equity-based compensation	$ 41,135		39,711				1,424
Purchase of treasury stock, inclusive of excise tax (in shares)	18,779,880					19,113,000
Purchase of treasury stock, inclusive of excise tax	$ (992,592)					$ (992,592)
Distributions to noncontrolling interest holders	(102,523)						(102,523)
Purchase of HEP units for equity grants	(600)						(600)
HEP Merger Transaction	(106,082)		(465,596)			$ 1,084,593	(725,079)
HEP Merger Transaction						(21,072,000)
Common stock outstanding at end of period (in shares) at Dec. 31, 2023		223,231,000
Stockholders' equity at end of period at Dec. 31, 2023	$ 10,237,298	$ 2,232	5,993,661	5,379,182	(11,784)	$ (1,194,201)	68,208
Treasury stock outstanding at end of period (in shares) at Dec. 31, 2023	23,235,599					23,236,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	$ 316,622			314,664			1,958
Dividends	(99,353)			(99,353)
Other comprehensive income (loss), net of tax	(10,493)				(10,493)
Issuance of common shares under incentive compensation plans (in shares)						(147,000)
Issuance of common shares under incentive compensation plans	0		(7,577)			$ 7,577
Equity-based compensation	$ 5,380		5,380
Purchase of treasury stock, inclusive of excise tax (in shares)	2,930,742					2,988,000
Purchase of treasury stock, inclusive of excise tax	$ (170,970)					$ (170,970)
Distributions to noncontrolling interest holders	(2,395)						(2,395)
Common stock outstanding at end of period (in shares) at Mar. 31, 2024		223,231,000
Stockholders' equity at end of period at Mar. 31, 2024	$ 10,276,089	$ 2,232	$ 5,991,464	$ 5,594,493	$ (22,277)	$ (1,357,594)	$ 67,771
Treasury stock outstanding at end of period (in shares) at Mar. 31, 2024	26,077,193					26,077,000

CONSOLIDATED STATEMENTS OF EQ_2

CONSOLIDATED STATEMENTS OF EQUITY (Parenthetical) - $ / shares	3 Months Ended		12 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Statement of Stockholders' Equity [Abstract]
Dividends declared per common share (in USD per share)	$ 0.50	$ 0.45	$ 1.80	$ 1.20	$ 0.35

Description of Business and Pre

Description of Business and Presentation of Financial Statements	3 Months Ended	12 Months Ended
	Mar. 31, 2024	Dec. 31, 2023
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Description of Business and Presentation of Financial Statements	Description of Business and Presentation of Financial Statements References herein to HF Sinclair, “we,” “our,” “ours,” and “us” refer only to HF Sinclair and its consolidated subsidiaries or to HF Sinclair or an individual subsidiary and not to any other person, with certain exceptions. References herein to Holly Energy Partners, L.P. (“HEP”) with respect to time periods prior to the closing of the HEP Merger Transaction (as defined below) on December 1, 2023 refer to HEP and its consolidated subsidiaries. We are an independent energy company that produces and markets high-value light products such as gasoline, diesel fuel, jet fuel, renewable diesel and other specialty products. We own and operate refineries located in Kansas, Oklahoma, New Mexico, Wyoming, Washington and Utah. We provide petroleum product and crude oil transportation, terminalling, storage and throughput services to our refineries and the petroleum industry. We market our refined products principally in the Southwest United States, the Rocky Mountains extending into the Pacific Northwest and in other neighboring Plains states and we supply high-quality fuels to more than 1,500 branded stations and license the use of the Sinclair brand at more than 300 additional locations throughout the country. We produce renewable diesel at two of our facilities in Wyoming and our facility in New Mexico. In addition, our subsidiaries produce and market base oils and other specialized lubricants in the United States, Canada and the Netherlands, and export products to more than 80 countries. On December 1, 2023, pursuant to the Agreement and Plan of Merger, dated as of August 15, 2023 (the “Merger Agreement”), by and among HEP, HF Sinclair, Navajo Pipeline Co., L.P., a Delaware limited partnership and an indirect wholly owned subsidiary of HF Sinclair (“HoldCo”), Holly Apple Holdings LLC, a Delaware limited liability company and a wholly owned subsidiary of HoldCo (“Merger Sub”), HEP Logistics Holdings, L.P., a Delaware limited partnership and the general partner of HEP (“HLH”), and Holly Logistic Services, L.L.C., a Delaware limited liability company and the general partner of HLH (the “General Partner”), Merger Sub merged with and into HEP, with HEP surviving as an indirect, wholly owned subsidiary of HF Sinclair (the “HEP Merger Transaction”). Under the terms of the Merger Agreement, each outstanding common unit representing a limited partner interest in HEP (an “HEP common unit”), other than the HEP common units already owned by HF Sinclair and its subsidiaries, was converted into the right to receive 0.315 shares of HF Sinclair common stock and $4.00 in cash, without interest. The Merger Agreement consideration totaled $267.6 million in cash and resulted in the issuance of 21,072,326 shares of HF Sinclair common stock from treasury stock. The HEP Merger Transaction was accounted for in accordance with Financial Accounting Standards Board Accounting Standards Codification ( “ ASC ” ) 810, “ Consolidation. ” Since we controlled HEP both before and after the HEP Merger Transaction, the changes in our ownership interest in HEP resulting from the HEP Merger Transaction were accounted for as an equity transaction, and no gain or loss was recognized in our Consolidated Statements of Income. The tax effects of the HEP Merger Transaction were recorded as adjustments to deferred income taxes and additional capital consistent with ASC 740, “Income Taxes.” For a description of our existing indebtedness, as well as associated changes in connection with the HEP Merger Transaction, see Note 9. We have prepared these consolidated financial statements without audit. In management’s opinion, these consolidated financial statements include all normal recurring adjustments necessary for a fair presentation of our consolidated financial position as of March 31, 2024, the consolidated results of income, comprehensive income and statements of equity for the three months ended March 31, 2024 and 2023, and consolidated cash flows for the three months ended March 31, 2024 and 2023 in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”). Although certain notes and other information required by generally accepted accounting principles in the United States (“GAAP”) have been condensed or omitted, we believe that the disclosures in these consolidated financial statements are adequate to make the information presented not misleading. These consolidated financial statements should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2023, and with our audited consolidated financial statements as of and for the year ended December 31, 2023, included in Exhibit 99.1 to this Quarterly Report on Form 10-Q. Accounts Receivable: Our accounts receivable primarily consist of amounts due from customers that are primarily from sales of refined products and renewable diesel. Credit is extended based on our evaluation of the customer’s financial condition, and in certain circumstances, collateral, such as letters of credit or guarantees, is required. We reserve for expected credit losses based on our historical loss experience as well as expected credit losses from current economic conditions and management’s expectations of future economic conditions. Credit losses are charged to the allowance for expected credit losses when an account is deemed uncollectible. Our allowance for expected credit losses was $2.8 million at March 31, 2024, and $3.2 million at December 31, 2023. Inventories: Inventories related to our refining operations are stated at the lower of cost, using the last-in, first-out (“LIFO”) method for crude oil and unfinished and finished refined products or market. Inventories related to our renewables business are stated at the lower of cost, using the LIFO method for feedstock and unfinished and finished renewable products, or market. In periods of rapidly declining prices, LIFO inventories may have to be written down to market value due to the higher costs assigned to LIFO layers in prior periods. In addition, the use of the LIFO inventory method may result in increases or decreases to cost of sales in years that inventory volumes decline as the result of charging cost of sales with LIFO inventory costs generated in prior periods. An actual valuation of inventory under the LIFO method is made at the end of each year based on the inventory levels at that time. Accordingly, interim LIFO calculations are based on management’s estimates of expected year-end inventory levels and are subject to the final year-end LIFO inventory valuation. Inventories of our Petro-Canada Lubricants and Sonneborn businesses are stated at the lower of cost, using the first-in, first-out method or net realizable value. Inventories consisting of process chemicals, materials and maintenance supplies and RINs are stated at the lower of weighted average cost or net realizable value. Leases: At inception, we determine if an arrangement is or contains a lease. Right-of-use (“ROU”) assets represent our right to use an underlying asset for the lease term and lease liabilities represent our payment obligation under the leasing arrangement. ROU assets and lease liabilities are recognized at the commencement date based on the present value of lease payments over the lease term. We use our estimated incremental borrowing rate (“IBR”) to determine the present value of lease payments as most of our leases do not contain an implicit rate. Our IBR represents the interest rate that we would pay to borrow, on a collateralized basis, an amount equal to the lease payments over a similar term in a similar economic environment. We use the implicit rate when readily determinable. Operating leases are recorded in “Operating lease right-of-use assets” and current and noncurrent “Operating lease liabilities” on our consolidated balance sheets. Finance leases are included in “Properties, plants and equipment, at cost,” “Accrued liabilities” and “Other long-term liabilities” on our consolidated balance sheets. Our lease term includes an option to extend the lease when it is reasonably certain that we will exercise that option. Leases with a term of 12 months or less are not recorded on our consolidated balance sheets. For certain equipment leases, we apply a portfolio approach for the operating lease ROU assets and liabilities. Also, as a lessee, we separate non-lease components that are identifiable and exclude them from the determination of net present value of lease payment obligations. In addition, as a lessor, we do not separate the non-lease (service) component in contracts in which the lease component is the dominant component. We treat these combined components as an operating lease. We bifurcate the consideration received for sales-type lease contracts between lease and service revenue, with the service component accounted for within the scope of ASC 606, “Revenue from Contracts with Customers.” Lessor: Our consolidated statements of income reflect the lease revenue we recognize from contracts with third parties in which we are the lessor. As the lessor, we classify customer contracts that contain leases into one of three categories: operating leases, direct finance leases, or sales-type leases. This classification is determined by evaluating key factors such as the lease term, the fair value of the underlying asset, and the residual value of the underlying assets. Revenue Recognition: Revenues on refined products, branded fuel sales, renewable diesel, and excess crude oil sales are recognized when delivered (via pipeline, in-tank or rack), and the customer obtains control of such inventory, which is typically when title passes and the customer is billed. All revenues are reported inclusive of shipping and handling costs billed and exclusive of any taxes billed to customers. Shipping and handling costs incurred are reported as cost of products sold. Our Lubricants & Specialties business has sales agreements with marketers and distributors that provide certain rights of return or provisions for the repurchase of products previously sold to them. Under these agreements, revenues and cost of revenues are deferred until the products have been sold to end customers. Our Lubricants & Specialties business also has agreements that create an obligation to deliver products at a future date for which consideration has already been received and recorded as deferred revenue. This revenue is recognized when the products are delivered to the customer. Our Midstream business recognizes revenues as products are shipped through its pipelines and terminals and as other services are rendered. Additionally, we have certain throughput agreements that specify minimum volume requirements, whereby we bill a customer for a minimum level of shipments in the event a customer ships below their contractual requirements. If there are no future performance obligations, we recognize these deficiency payments as revenue. In certain of these throughput agreements, a customer may later utilize such shortfall billings as credit towards future volume shipments in excess of its minimum levels within its respective contractual shortfall make-up period. Such amounts represent an obligation to perform future services, which may be initially deferred and later recognized as revenue based on estimated future shipping levels, including the likelihood of a customer’s ability to utilize such amounts prior to the end of the contractual shortfall make-up period. We recognize the service portion of these deficiency payments as revenue when we do not expect it will be required to satisfy these performance obligations in the future based on the pattern of rights exercised by the customer. Payment terms under our contracts with customers are consistent with industry norms and are typically payable within 30 days of the date of invoice. Foreign Currency Translation: Assets and liabilities recorded in foreign currencies are translated into U.S. dollars using exchange rates in effect as of the balance sheet date. Revenue and expense accounts are translated using the weighted average exchange rates during the period presented. Foreign currency translation adjustments are recorded as a component of accumulated other comprehensive income. We have intercompany notes that were issued to fund certain of our foreign businesses. Remeasurement adjustments resulting from the conversion of intercompany financing amounts to functional currencies are recorded as gains and losses as a component of other income (expense) in the consolidated statements of income. Such adjustments are not recorded in the Lubricants & Specialties segment operations, but in Corporate and Other. See Note 14 for additional information on our segments. Income Taxes: Provisions for income taxes include deferred taxes resulting from temporary differences in income for financial and tax purposes, using the liability method of accounting for income taxes. The liability method requires the effect of tax rate changes on deferred income taxes to be reflected in the period in which the rate change was enacted. The liability method also requires that deferred tax assets be reduced by a valuation allowance unless it is more likely than not that the assets will be realized. We account for U.S. tax on global intangible low-taxed income in the period in which it is incurred. Potential interest and penalties related to income tax matters are recognized in income tax expense. We believe we have the appropriate support for the income tax positions taken and to be taken on our income tax returns and that our accruals for tax liabilities are adequate for all open years based on an assessment of many factors, including past experience and interpretations of tax law applied to the facts of each matter. For the three months ended March 31, 2024, we recorded income tax expense of $85.5 million compared to $99.7 million for the three months ended March 31, 2023. This decrease was principally due to lower pre-tax income during the three months ended March 31, 2024, compared to the same period of 2023. Our effective tax rates were 21.3% and 20.6% for the three months ended March 31, 2024 and 2023, respectively. The difference between the U.S. federal statutory rate and the effective tax rate for the three months ended March 31, 2024 is primarily due to the relationship between pre-tax results and non-taxable permanent differences. The difference in the U.S. federal statutory rate and the effective tax rate for the three months ended March 31, 2023 was primarily due to the impact of federal tax credits and the relationship between pre-tax results and the earnings attributable to the noncontrolling interest that is not included in income for tax purposes. Inventory Repurchase Obligations: We periodically enter into same-party sell/buy transactions, whereby we sell certain refined product inventory and subsequently repurchase the inventory in order to facilitate delivery to certain locations. Such sell/bu y transactions are accounted for as inventory repurchase obligations, under which proceeds received under the initial sale are recognized as an inventory repurchase obligation that is subsequently reversed when the inventory is repurchased. We received proceeds of $6.3 million for each of the three months ended March 31, 2024 and 2023, and subsequently repaid $6.6 million and $7.0 million, respectively, under these sell/buy transactions. Accounting Pronouncements - Not Yet Adopted In November 2023, Accounting Standards Update (“ASU”) 2023-07, “Improvements to Reportable Segment Disclosures” was issued. ASU 2023-07 requires, among other updates, enhanced disclosures about significant segment expenses that are regularly provided to the chief operating decision maker, as well as the aggregate amount of other segment items included in the reported measure of segment profit or loss. This aims to provide more decision-useful information to stakeholders by giving a clearer picture of the costs incurred by each reportable segment. ASU 2023-07 is effective for fiscal years beginning after December 15, 2023, and interim periods within fiscal years beginning after December 15, 2024, and requires retrospective adoption. Early adoption is permitted. We are assessing the impact of this guidance on our disclosures.	Description of Business and Summary of Significant Accounting Policies Description of Business: References herein to HF Sinclair Corporation (“HF Sinclair”) include HF Sinclair and its consolidated subsidiaries. In these financial statements, the words “we,” “our,” “ours” and “us” refer only to HF Sinclair and its consolidated subsidiaries or to HF Sinclair or an individual subsidiary and not to any other person, with certain exceptions. References herein to HF Sinclair “we,” “our,” “ours” and “us” with respect to time periods prior to March 14, 2022 refer to HollyFrontier Corporation (“HollyFrontier”) and its consolidated subsidiaries and do not include Hippo Holding LLC (now known as Sinclair Holding LLC), the parent company of Sinclair Oil LLC, Sinclair Transportation Company LLC or their respective consolidated subsidiaries (collectively, the “Acquired Sinclair Businesses”). References herein to HF Sinclair “we,” “our,” “ours” and “us” with respect to time periods from and after March 14, 2022 include the operations of the Acquired Sinclair Businesses. Unless otherwise specified, the financial statements included herein include financial information for HF Sinclair, which for the time period from March 14, 2022 to December 31, 2023 includes the combined business operations of HollyFrontier and the Acquired Sinclair Businesses. References herein to Holly Energy Partners, L.P. (“HEP”) with respect to time periods prior to the closing of the HEP Merger Transaction (as defined below) on December 1, 2023 refer to HEP and its consolidated subsidiaries. We are an independent energy company that produces and markets high-value light products such as gasoline, diesel fuel, jet fuel, renewable diesel and other specialty products. We own and operate refineries located in Kansas, Oklahoma, New Mexico, Wyoming, Washington and Utah. We provide petroleum product and crude oil transportation, terminalling, storage and throughput services to our refineries and the petroleum industry. We market our refined products principally in the Southwest United States, the Rocky Mountains extending into the Pacific Northwest and in other neighboring Plains states and we supply high-quality fuels to more than 1,500 branded stations and license the use of the Sinclair brand at more than 300 additional locations throughout the country. We produce renewable diesel at two of our facilities in Wyoming and our facility in New Mexico. In addition, our subsidiaries produce and market base oils and other specialized lubricants in the United States, Canada and the Netherlands, and export products to more than 80 countries. On December 1, 2023, pursuant to the Agreement and Plan of Merger dated as of August 15, 2023 (the “Merger Agreement”) by and among HEP, HF Sinclair, Navajo Pipeline Co., L.P., a Delaware limited partnership and an indirect wholly owned subsidiary of HF Sinclair (“HoldCo”), Holly Apple Holdings LLC, a Delaware limited liability company and a wholly owned subsidiary of HoldCo (“Merger Sub”), HEP Logistics Holdings, L.P., a Delaware limited partnership and the general partner of HEP (“HLH”), and Holly Logistic Services, L.L.C., a Delaware limited liability company and the general partner of HLH, Merger Sub merged with and into HEP, with HEP surviving as an indirect, wholly owned subsidiary of HF Sinclair (the “HEP Merger Transaction”). Under the terms of the Merger Agreement, each outstanding common unit representing a limited partner interest in HEP (an “HEP common unit”), other than the HEP common units already owned by HF Sinclair and its subsidiaries, was converted into the right to receive 0.315 shares of HF Sinclair common stock and $4.00 in cash, without interest. The Merger Agreement consideration totaled $267.6 million in cash and resulted in the issuance of 21,072,326 shares of HF Sinclair common stock from treasury stock. The HEP Merger Transaction was accounted for in accordance with Financial Accounting Standards Board ( “ FASB ” ) Accounting Standards Codification ( “ ASC ” ) 810, “ Consolidation. ” Since we controlled HEP both before and after the HEP Merger Transaction, the changes in our ownership interest in HEP resulting from the HEP Merger Transaction were accounted for as an equity transaction, and no gain or loss was recognized in our Consolidated Statements of Income. The tax effects of the HEP Merger Transaction were recorded as adjustments to deferred income taxes and additional capital consistent with ASC 740, “ Income Taxes. ” For a description of our existing indebtednes s, as well as changes thereto associ ated with the HEP Merger Transaction, see Note 13. In connection with the HEP Merger Transaction, for the year ended December 31, 2023, we incurred $23.5 million in incremental direct acquisition and integration costs that principally relate to legal, advisory and other professional fees and are presented as selling, general and administrative expenses in our statements of income. On May 4, 2021, HollyFrontier Puget Sound Refining LLC (now known as HF Sinclair Puget Sound Refining LLC), a wholly owned subsidiary of HollyFrontier, entered into a sale and purchase agreement with Equilon Enterprises LLC d/b/a Shell Oil Products US (“Shell”) to acquire Shell’s Puget Sound refinery and related assets, including the on-site cogeneration facility and related logistics assets (the “Puget Sound Refinery”). The acquisition closed on November 1, 2021. See Note 2 for additional information. On April 27, 2021, our wholly owned subsidiary, 7037619 Canada Inc., entered into a contract for sale of real property in Mississauga, Ontario for base consideration of $98.8 million, or CAD 125 million. The transaction closed on September 15, 2021, and we recorded a gain on sale of assets totaling $86.0 million for the year ended December 31, 2021, which was recognized in “Gain on sale of assets and other” on our consolidated statements of income. During the first quarter of 2021, we initiated a restructuring within our Lubricants & Specialties segment. As a result of this restructuring, we recorded $7.8 million in employee severance costs for the year ended December 31, 2021, which were recognized primarily as selling, general and administrative expenses in our Lubricants & Specialties segment. In the third quarter of 2020, we permanently ceased petroleum refining operations at our Cheyenne, Wyoming refinery (the “Cheyenne Refinery”) and subsequently began converting certain assets at our Cheyenne Refinery to renewable diesel production. In connection with the cessation of petroleum refining operations at our Cheyenne Refinery, we recognized $1.7 million and $25.8 million in decommissioning expense for the years ended December 31, 2022 and 2021, respectively. We also recognized $1.0 million in employee severance costs for the year ended December 31, 2021. These charges were all recognized in operating expenses in our Corporate and Other segment. Principles of Consolidation: Our consolidated financial statements include our accounts and the accounts of partnerships and joint ventures that we control through an ownership interest greater than 50% or through a controlling financial interest with respect to variable interest entities. All significant intercompany transactions and balances have been eliminated. Variable Interest Entities: A variable interest entity ( “ VIE ” ) is a legal entity whose equity owners do not have sufficient equity at risk for the entity to finance its activities without additional subordinated financial support or, as a group, the equity holders lack the power, through voting rights, to direct the activities that most significantly impact the entity's financial performance, the obligation to absorb the entity's expected losses or rights to expected residual returns. See Note 4 for additional information. Use of Estimates: The preparation of financial statements in accordance with U.S. generally accepted accounting principles (“GAAP”) requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. Actual results could differ from those estimates. Cash Equivalents: We consider all highly liquid instruments with a maturity of three months or less at the date of purchase to be cash equivalents. Cash equivalents are stated at cost, which approximates market value and are primarily invested in highly-rated instruments issued by government or municipal entities with strong credit standings. Balance Sheet Offsetting: We purchase and sell inventories of crude oil with certain same-parties that are net settled in accordance with contractual net settlement provisions. Our policy is to present such balances on a net basis since it presents our accounts receivables and payables consistent with our contractual settlement provisions. Accounts Receivable: Our accounts receivable primarily consist of amounts due from customers that are primarily from sales of refined products and renewable diesel. Credit is extended based on our evaluation of the customer's financial condition, and in certain circumstances collateral, such as letters of credit or guarantees, is required. We reserve for expected credit losses based on our historical loss experience as well as expected credit losses from current economic conditions and management’s expectations of future economic conditions. Credit losses are charged to the allowance for expected credit losses when an account is deemed uncollectible. Our allowance for expected credit losses was $3.2 million at December 31, 2023 and $7.7 million at December 31, 2022. Accounts receivable attributable to crude oil resales generally represent the sale of excess crude oil to other purchasers and / or users in cases when our crude oil supplies are in excess of our immediate needs as well as certain reciprocal buy / sell exchanges of crude oil. At times we enter into such buy / sell exchanges to facilitate the delivery of quantities to certain locations. In many cases, we enter into net settlement agreements relating to the buy / sell arrangements, which may mitigate credit risk. Inventories: Inventories related to our refining operations are stated at the lower of cost, using the last-in, first-out (“LIFO”) method for crude oil and unfinished and finished refined products, or market. Inventories related to our renewable business are stated at the lower of cost, using the LIFO method for feedstock and unfinished and finished renewable products, or market. Cost, consisting of raw material, transportation and conversion costs, is determined using the LIFO inventory valuation methodology and market is determined using current replacement costs. Under the LIFO method, the most recently incurred costs are charged to cost of sales and inventories are valued at the earliest acquisition costs. In periods of rapidly declining prices, LIFO inventories may have to be written down to market value due to the higher costs assigned to LIFO layers in prior periods. In addition, the use of the LIFO inventory method may result in increases or decreases to cost of sales in years that inventory volumes decline as the result of charging cost of sales with LIFO inventory costs generated in prior periods. An actual valuation of inventory under the LIFO method is made at the end of each year based on the inventory levels at that time. Accordingly, interim LIFO calculations are based on management’s estimates of expected year-end inventory levels and are subject to the final year-end LIFO inventory valuation. Inventories of our Petro-Canada Lubricants and Sonneborn businesses are stated at the lower of cost, using the first-in, first-out (“FIFO”) method, or net realizable value. Inventories consisting of process chemicals, materials and maintenance supplies and RINs are stated at the lower of weighted-average cost or net realizable value. Leases: At inception, we determine if an arrangement is or contains a lease. Right-of-use (“ROU”) assets represent our right to use an underlying asset for the lease term and lease liabilities represent our payment obligation under the leasing arrangement. ROU assets and lease liabilities are recognized at the commencement date based on the present value of lease payments over the lease term. We use our estimated incremental borrowing rate (“IBR”) to determine the present value of lease payments as most of our leases do not contain an implicit rate. Our IBR represents the interest rate which we would pay to borrow, on a collateralized basis, an amount equal to the lease payments over a similar term in a similar economic environment. We use the implicit rate when readily determinable. Operating leases are recorded in “Operating lease right-of-use assets” and current and noncurrent “Operating lease liabilities” on our consolidated balance sheets. Finance leases are included in “Properties, plants and equipment, at cost” and “Accrued liabilities” and “Other long-term liabilities” on our consolidated balance sheets. Our lease term includes an option to extend the lease when it is reasonably certain that we will exercise that option. Leases with a term of 12 months or less are not recorded on our balance sheets. For certain equipment leases, we apply a portfolio approach for the operating lease ROU assets and liabilities. Also, as a lessee, we separate non-lease components that are identifiable and exclude them from the determination of net present value of lease payment obligations. In addition, as a lessor, we do not separate the non-lease (service) component in contracts in which the lease component is the dominant component. We treat these combined components as an operating lease. We bifurcate the consideration received for sales-type lease contracts between lease and service revenue, with the service component accounted for within the scope of ASC 606, “Revenue from Contracts with Customers”. Derivative Instruments: All derivative instruments are recognized as either assets or liabilities on our consolidated balance sheets and are measured at fair value. Changes in the derivative instrument's fair value are recognized in earnings unless specific hedge accounting criteria are met. Cash flows from all our derivative activity are reported in the operating section on our consolidated statements of cash flows. See Note 14 for additional information. Properties, Plants and Equipment: Properties, plants and equipment are stated at cost. Depreciation is provided by the straight-line method over the estimated useful lives of the assets, primarily 15 to 32 years for refining, pipeline and terminal facilities, 10 to 40 years for buildings and improvements, 5 to 30 years for other fixed assets and 5 years for vehicles. Asset Retirement Obligations: We record legal obligations associated with the retirement of long-lived assets that result from the acquisition, construction, development and / or the normal operation of long-lived assets. The fair value of the estimated cost to retire a tangible long-lived asset is recorded as a liability with the associated retirement costs capitalized as part of the asset's carrying amount in the period in which it is incurred and when a reasonable estimate of the fair value of the liability can be made. If a reasonable estimate cannot be made at the time the liability is incurred, we record the liability when sufficient information is available to estimate the liability's fair value. Certain of our refining assets have no recorded liability for asset retirement obligations since the timing of any retirement and related costs are currently indeterminable. Our asset retirement obligations were $64.6 million and $61.8 million at December 31, 2023 and 2022, respectively, which are included in “Other long-term liabilities” on our consolidated balance sheets. Accretion expense was insignificant for the years ended December 31, 2023, 2022 and 2021. Asset retirement obligations assumed in the Sinclair Transactions, as defined in Note 2, were $6.2 million. Intangibles, Goodwill and Long-lived Assets: Intangible assets are assets (other than financial assets) that lack physical substance, and goodwill represents the excess of the cost of an acquired entity over the fair value of the assets acquired and liabilities assumed. Goodwill acquired in a business combination and intangibles with indefinite useful lives are not amortized, whereas intangible assets with finite useful lives are amortized on a straight-line basis. Goodwill and intangible assets that are not subject to amortization are tested for impairment annually or more frequently if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying amount. Our goodwill impairment testing first entails either a quantitative assessment or an optional qualitative assessment to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount. If we determine that based on the qualitative factors that it is more likely than not that the carrying amount of the reporting unit is greater than its fair value, a quantitative test is performed in which we estimate the fair value of the related reporting unit. If the carrying amount of a reporting unit exceeds its fair value, the goodwill of that reporting unit is impaired, and we measure goodwill impairment as the excess of the carrying amount of the reporting unit over the related fair value. The carrying amount of our intangible assets and goodwill may fluctuate from period to period due to the effects of foreign currency translation adjustments on goodwill and intangible assets assigned to our Lubricants & Specialties segment. For purposes of long-lived asset impairment evaluation, we group our long-lived assets as follows: (i) our refinery asset groups, which include certain logistics assets, (ii) our renewables products asset groups, (iii) our Lubricants & Specialties asset groups, (iv) our Marketing assets and (v) our Midstream asset groups, which is comprised of logistics assets not included in our refinery asset groups. These asset groups represent the lowest level for which independent cash flows can be identified. Our long-lived assets are evaluated for impairment by identifying whether indicators of impairment exist and, if so, assessing whether such long-lived assets are recoverable from estimated future undiscounted cash flows. The actual amount of impairment loss measured, if any, is equal to the amount by which the asset group’s carrying value exceeds its fair value. See Note 11 for additional information regarding goodwill and intangible assets. Equity Method Investments: We account for investments in which we have a noncontrolling interest, yet have significant influence over the entity, using the equity method of accounting, whereby we record our pro-rata share of earnings of these companies and contributions to and distributions from the joint ventures as adjustments to our investment balance. The following table summarizes our recorded investment compared to its share of underlying equity for each of its investee. The differences are being amortized as adjustments to our pro-rata share of earnings in the joint ventures. Balance at December 31, 2023 Underlying Equity Recorded Investment Balance Difference (In thousands) Equity Method Investments Osage Pipe Line Company, LLC $ 1,144 $ 27,135 $ (25,991) Cheyenne Pipeline, LLC 30,508 41,985 (11,477) Cushing Connect Terminal Holdings LLC 48,135 32,474 15,661 Pioneer Investments Corp. 24,188 131,244 (107,056) Saddle Butte Pipeline III, LLC 66,436 33,107 33,329 Total $ 170,411 $ 265,945 $ (95,534) Balance at December 31, 2022 Underlying Equity Recorded Investment Balance Difference (In thousands) Equity Method Investments Osage Pipe Line Company, LLC $ 2,901 $ 29,773 $ (26,872) Cheyenne Pipeline, LLC 27,655 40,019 (12,364) Cushing Connect Terminal Holdings LLC 49,915 34,746 15,169 Pioneer Investments Corp. 23,835 133,182 (109,347) Saddle Butte Pipeline III, LLC 67,349 32,884 34,465 Total $ 171,655 $ 270,604 $ (98,949) Revenue Recognition: Revenues on refined product, branded fuel sales, renewable diesel and excess crude oil sales are recognized when delivered (via pipeline, in-tank or rack) and the customer obtains control of such inventory, which is typically when title passes and the customer is billed. All revenues are reported inclusive of shipping and handling costs billed and exclusive of any taxes billed to customers. Shipping and handling costs incurred are reported as cost of products sold. Our lubricants and specialties business has sales agreements with marketers and distributors that provide certain rights of return or provisions for the repurchase of products previously sold to them. Under these agreements, revenues and cost of revenues are deferred until the products have been sold to end customers. Our lubricants and specialties business also has agreements that create an obligation to deliver products at a future date for which consideration has already been received and recorded as deferred revenue. This revenue is recognized when the products are delivered to the customer. Our midstream business recognizes revenues as products are shipped through its pipelines and terminals and as other services are rendered. Additionally, we have certain throughput agreements that specify minimum volume requirements, whereby we bill a customer for a minimum level of shipments in the event a customer ships below their contractual requirements. If there are no future performance obligations, we recognize these deficiency payments as revenue. In certain of these throughput agreements, a customer may later utilize such shortfall billings as credit towards future volume shipments in excess of its minimum levels within its respective contractual shortfall make-up period. Such amounts represent an obligation to perform future services, which may be initially deferred and later recognized as revenue based on estimated future shipping levels, including the likelihood of a customer’s ability to utilize such amounts prior to the end of the contractual shortfall make-up period. We recognize the service portion of these deficiency payments as revenue when we do not expect it will be required to satisfy these performance obligations in the future based on the pattern of rights exercised by the customer. Payment terms under our contracts with customers are consistent with industry norms and are typically payable within 30 days of the date of invoice. Cost Classifications: Costs of products sold include the cost of crude oil, other feedstocks, blendstocks and purchased finished products, inclusive of transportation costs. We purchase crude oil that at times exceeds the supply needs of our refineries. Quantities in excess of our needs are sold at market prices to purchasers of crude oil that are recorded on a gross basis with the sales price recorded as revenues and the corresponding acquisition cost as cost of products sold. Additionally, we enter into buy / sell exchanges of crude oil with certain parties to facilitate the delivery of quantities to certain locations that are netted at cost. Operating expenses include direct costs of labor, maintenance materials and services, utilities and other direct operating costs. Selling, general and administrative expenses include compensation, professional services and other support costs. Deferred Maintenance Costs: Our refinery units require regular major maintenance and repairs which are commonly referred to as “turnarounds.” Catalysts used in certain refinery processes also require regular “change-outs.” The required frequency of the maintenance varies by unit and by catalyst, but generally occurs no less than once every five years. Turnaround costs are deferred and amortized over the period until the next scheduled turnaround. Other repairs and maintenance costs are expensed when incurred. Deferred turnaround and catalyst amortization expense was $238.7 million, $159.3 million and $136.9 million for the years ended December 31, 2023, 2022 and 2021, respectively. Environmental Costs: Environmental costs are charged to operating expenses Contingencies: We are subject to proceedings, lawsuits and other claims related to environmental, labor, product and other matters. We are required to assess the likelihood of any adverse judgments or outcomes to these matters as well as potential ranges of probable losses. We accrue for contingencies when it is probable that a loss has occurred and when the amount of that loss is reasonably estimable. A determination of the amount of reserves required, if any, for these contingencies is made after careful analysis of each individual issue. The required reserves may change in the future due to new developments in each matter or changes in approach such as a change in settlement strategy in dealing with these matters. Foreign Currency Translation: Assets and liabilities recorded in foreign currencies are translated into U.S. dollars using exchange rates in effect as of the balance sheet date. Revenue and expense accounts are translated using the weighted-average exchange rates during the period presented. Foreign currency translation adjustments are recorded as a component of accumulated other comprehensive income. We have intercompany notes that were issued to fund certain of our foreign businesses. Remeasurement adjustments resulting from the conversion of such intercompany financing amounts to functional currencies are recorded as gains or losses as a component of other income (expense) on our consolidated statements of income. Such adjustments are not recorded to the Lubricants & Specialties segment operations, but to Corporate and Other. See Note 20 for additional information on our segments. Income Taxes: Provisions for income taxes include deferred taxes resulting from temporary differences in income for financial and tax purposes, using the liability method of accounting for income taxes. The liability method requires the effect of tax rate changes on deferred income taxes to be reflected in the period in which the rate change was enacted. The liability method also requires that deferred tax assets be reduced by a valuation allowance unless it is more likely than not that the assets will be realized. We account for U.S. tax on global intangible low-taxed income in the period in which it is incurred. Potential interest and penalties related to income tax matters are recognized in income tax expense. We believe we have appropriate support for the income tax positions taken and to be taken on our income tax returns and that our accruals for tax liabilities are adequate for all open years based on an assessment of many factors, including past experience and interpretations of tax law applied to the facts of each matter. Inventory Repurchase Obligations: We periodically enter into same-party sell / buy transactions, whereby we sell certain refined product inventory and subsequently repurchase the inventory in order to facilitate delivery to certain locations. Such sell / buy transactions are accounted for as inventory repurchase obligations under which proceeds received under the initial sell is recognized as inventory repurchase obligations that are subsequently reversed when the inventories are repurchased. For the years ended December 31, 2023, 2022 and 2021, we received proceeds of $25.7 million, $42.1 million and $43.5 million, respectively, and subsequently repaid $27.4 million, $42.8 million and $45.4 million, respectively, under these sell / buy transactions. Accounting Pronouncements - Recently Adopted In October 2021, Accounting Standards Update (“ASU”) 2021-08, “Accounting for Contract Assets and Contract Liabilities from Contracts with Customers,” was issued requiring that an acquiring entity recognize and measure contract assets and contract liabilities acquired in a business combination in accordance with ASC 606, “Revenue from Contracts with Customers.” We adopted this standard effective January 1, 2023, but did not have a business combination under the scope of ASC 805, “Business Combinations” for the year ended December 31, 2023. Accounting Pronouncements - Not Yet Adopted In November 2023, ASU 2023-07, “Improvements to Reportable Segment Disclosures” was issued. ASU 2023-07 requires, among other updates, enhanced disclosures about significant segment expenses that are regularly provided to the chief operating decision maker, as well as the aggregate amount of other segment items included in the reported measure of segment profit or loss. This aims to provide more decision-useful information to stakeholders by giving a clearer picture of the costs incurred by each reportable segment. ASU 2023-07 is effective for fiscal years beginning after December 15, 2023, and interim periods within fiscal years beginning after December 15, 2024, and requires retrospective adoption. Early adoption is permitted. We are assessing the impact of this guidance on our disclosures.

Cushing Connect Joint Venture

Cushing Connect Joint Venture	3 Months Ended	12 Months Ended
Cushing Connect Joint Venture	Mar. 31, 2024	Dec. 31, 2023
Equity Method Investments and Joint Ventures [Abstract]
Cushing Connect Joint Venture	Cushing Connect Joint Venture In 2019, HEP Cushing LLC (“HEP Cushing”), then a wholly owned subsidiary of HEP and now a wholly owned subsidiary of HF Sinclair, and Plains Marketing, L.P., a wholly owned subsidiary of Plains All American Pipeline, L.P. (“Plains”) formed a 50/50 joint venture, Cushing Connect Pipeline & Terminal LLC (“Cushing Connect”), for (i) the development, construction, ownership and operation of a new 160,000 barrel per day common carrier crude oil pipeline (the “Cushing Connect Pipeline”) that connects the Cushing, Oklahoma crude oil hub to our Tulsa refineries and (ii) the ownership and operation of 1.5 million barrels of crude oil storage in Cushing, Oklahoma (the “Cushing Connect Terminal” and together with Cushing Connect and the Cushing Connect Pipeline, the “Cushing Connect Joint Venture”). The Cushing Connect Terminal was fully in service beginning in April 2020, and the Cushing Connect Pipeline was placed in service during the third quarter of 2021. Long-term commercial agreements have been entered into to support the Cushing Connect assets. Cushing Connect entered into a contract with an affiliate of HEP, now a subsidiary of HF Sinclair, to manage the operation of the Cushing Connect Pipeline and with an affiliate of Plains to manage the operation of the Cushing Connect Terminal. The total investment in Cushing Connect was generally shared proportionately among the partners. However, HEP was solely responsible for any Cushing Connect Pipeline construction costs that exceeded the budget by more than 10%. HEP’s share of the cost of the Cushing Connect Terminal contributed by Plains and Cushing Connect Pipeline construction costs was approximately $74.0 million. Cushing Connect and its two subsidiaries, Cushing Connect Pipeline and Cushing Connect Terminal, are variable interest entities (“VIE”) as defined under GAAP. A VIE is a legal entity whose equity owners do not have sufficient equity at risk for the entity to finance its activities without additional subordinated financial support or, as a group, the equity holders lack the power, through voting rights, to direct the activities that most significantly impact the entity’s financial performance, the obligation to absorb the entity’s expected losses or rights to expected residual returns. Cushing Connect and its two subsidiaries are VIEs because they did not originally have sufficient equity at risk to finance their activities without additional financial support. We are the primary beneficiary of two of these entities as HEP constructed and operates the Cushing Connect Pipeline, and we have more ability to direct the activities that most significantly impact the financial performance of Cushing Connect and Cushing Connect Pipeline. Therefore, we consolidate these two entities. We are not the primary beneficiary of Cushing Connect Terminal, which we account for using the equity method of accounting. Our maximum exposure to loss as a result of our involvement with Cushing Connect Terminal is not expected to be material due to the long-term terminalling agreements in place to support operations. With the exception of the assets of HEP Cushing, creditors of the Cushing Connect Joint Venture legal entities have no recourse to our assets. Any recourse to HEP Cushing would be limited to the extent of HEP Cushing’s assets, which other than its investment in the Cushing Connect Joint Venture, are not significant. Furthermore, our creditors have no recourse to the assets of the Cushing Connect Joint Venture legal entities. The most significant assets of Cushing Connect and Cushing Connect Pipeline that are available to settle only their obligations, along with their most significant liabilities for which their creditors do not have recourse to our general credit, were: March 31, December 31, (In thousands) Cash and cash equivalents $ 916 $ 1,536 Properties, plants and equipment, at cost 102,979 102,936 Less: accumulated depreciation (8,907) (8,022) Intangibles and other 31,674 32,473	Cushing Connect Joint Venture In 2019, HEP Cushing LLC, then a wholly owned subsidiary of HEP and now a wholly owned subsidiary of HF Sinclair, and Plains Marketing, L.P., a wholly owned subsidiary of Plains All American Pipeline, L.P. (“Plains”) formed a 50/50 joint venture, Cushing Connect Pipeline & Terminal LLC (“Cushing Connect”), for (i) the development, construction, ownership and operation of a new 160,000 barrel per day common carrier crude oil pipeline (the “Cushing Connect Pipeline”) that connects the Cushing, Oklahoma crude oil hub to our Tulsa refineries and (ii) the ownership and operation of 1.5 million barrels of crude oil storage in Cushing, Oklahoma (the “Cushing Connect Terminal” and together with Cushing Connect and the Cushing Connect Pipeline, the “Cushing Connect Joint Venture”). The Cushing Connect Terminal was fully in-service beginning in April 2020, and the Cushing Connect Pipeline was placed in service during the third quarter of 2021. Long-term commercial agreements have been entered into to support the Cushing Connect assets. Cushing Connect entered into a contract with an affiliate of HEP, now a subsidiary of HF Sinclair, to manage the operation of the Cushing Connect Pipeline and with an affiliate of Plains to manage the operation of the Cushing Connect Terminal. The total investment in Cushing Connect was generally shared proportionately among the partners. However, HEP was solely responsible for any Cushing Connect Pipeline construction costs that exceeded the budget by more than 10%. HEP’s share of the cost of the Cushing Connect Terminal contributed by Plains and Cushing Connect Pipeline construction costs was approximately $74.0 million. Cushing Connect and its two subsidiaries, Cushing Connect Pipeline and Cushing Connect Terminal are each VIEs as defined under GAAP. A VIE is a legal entity whose equity owners do not have sufficient equity at risk for the entity to finance its activities without additional subordinated financial support or, as a group, the equity holders lack the power, through voting rights, to direct the activities that most significantly impact the entity's financial performance, the obligation to absorb the entity's expected losses or rights to expected residual returns. Cushing Connect and its two subsidiaries are each VIE’s because they did not originally have sufficient equity at risk to finance their activities without additional financial support. We are the primary beneficiary of two of these entities as HEP constructed and operates the Cushing Connect Pipeline, and we have more ability to direct the activities that most significantly impact the financial performance of Cushing Connect and Cushing Connect Pipeline. Therefore, we consolidate these two entities. We are not the primary beneficiary of Cushing Connect Terminal, which we account for using the equity method of accounting. Our maximum exposure to loss as a result of our involvement with Cushing Connect Terminal is not expected to be material due to the long-term terminalling agreements in place to support operations. With the exception of the assets of HEP Cushing, creditors of the Cushing Connect Joint Venture legal entities have no recourse to our assets. Any recourse to HEP Cushing would be limited to the extent of HEP Cushing's assets, which other than its investment in Cushing Connect Joint Venture, are not significant. Furthermore, our creditors have no recourse to the assets of the Cushing Connect Joint Venture legal entities. The most significant assets of Cushing Connect and Cushing Connect Pipeline that are available to settle only their obligations, along with their most significant liabilities for which their creditors do not have recourse to our general credit, were: Years Ended December 31, 2023 2022 (In thousands) Cash and cash equivalents 1,536 2,147 Properties, plants and equipment, at cost 102,936 102,635 Less accumulated depreciation (8,022) (4,484) Intangibles and other 32,473 34,746

Revenues

Revenues	3 Months Ended	12 Months Ended
Revenues	Mar. 31, 2024	Dec. 31, 2023
Revenue from Contract with Customer [Abstract]
Revenues	Revenues Substantially all revenue-generating activities relate to sales of refined products, branded fuel, renewable diesel and excess crude oil inventories sold at market prices (variable consideration) under contracts with customers. Additionally, we have revenues attributable to our logistics services provided under petroleum product and crude oil pipeline transportation, processing, storage and terminalling agreements with third parties. Disaggregated revenues were as follows: Three Months Ended 2024 2023 (In thousands) Revenues by type Refined product revenues Transportation fuels (1) $ 4,628,631 $ 4,507,894 Specialty lubricant products (2) 614,221 679,862 Asphalt, fuel oil and other products (3) 483,316 440,339 Total refined product revenues 5,726,168 5,628,095 Excess crude oil revenues (4) 267,096 710,897 Renewable diesel revenues (5) 179,669 202,413 Transportation and logistics services 23,099 26,416 Marketing revenues (6) 775,807 937,385 Other revenues (7) 55,306 59,936 Total sales and other revenues $ 7,027,145 $ 7,565,142 Three Months Ended 2024 2023 (In thousands) Refined product revenues by market United States: Mid-Continent $ 2,215,841 $ 2,007,156 Southwest 975,702 832,702 Rocky Mountains 1,988,491 2,197,827 Northeast 219,347 263,904 Canada 255,772 250,724 Europe, Asia and Latin America 71,015 75,782 Total refined product revenues $ 5,726,168 $ 5,628,095 (1) Transportation fuels revenues are attributable to our Refining segment’s wholesale marketing of gasoline, diesel and jet fuel. (2) Specialty lubricant products consist of base oil, waxes, finished lubricants and other specialty fluids. (3) Revenues from asphalt, fuel oil and other products include amounts attributable to our Refining and Lubricants & Specialties segments of $422.0 million and $61.3 million, respectively, for the three months ended March 31, 2024, and $386.8 million and $53.6 million, respectively, for the three months ended March 31, 2023. (4) Excess crude oil revenues represent sales of purchased crude oil inventory that at times exceeds the supply needs of our refineries. (5) Renewable diesel revenues are attributable to our Renewables segment. (6) Marketing revenues consist primarily of branded gasoline and diesel fuel. (7) Other revenues are principally attributable to our Refining segment. Our consolidated balance sheets reflect contract liabilities related to unearned revenues attributable to future service obligations under our third-party transportation agreements and production agreements from our Sonneborn operation s. The following table present s changes to our contract liabilities: Three Months Ended March 31, 2024 2023 (In thousands) Balance at January 1 $ 7,533 $ 10,722 Increase 5,693 5,159 Recognized as revenue (6,115) (5,744) Balance at March 31 $ 7,111 $ 10,137 As of March 31, 2024, we have long-term contracts with customers that specify minimum volumes of gasoline, diesel, lubricants and specialties to be sold ratably at market prices through 2032. Future prices are subject to market fluctuations and therefore, we have elected the exemption to exclude variable consideration under these contracts under ASC 606-10-50-14A. Aggregate minimum volumes expected to be sold (future performance obligations) under our long-term product sales contracts with customers are as follows: Remainder of 2024 2025 2026 Thereafter Total (In thousands) Refined product sales volumes (barrels) 26,099 27,204 19,003 47,888 120,194 Additionally, we have long-term contracts with third-party customers that specify minimum volumes of product to be transported through our pipelines and terminals that result in fixed-minimum annual revenues through 2033. Annual minimum revenues attributable to our third-party contracts as of March 31, 2024, are presented below: Remainder of 2024 2025 2026 Thereafter Total (In thousands) Midstream operations contractual minimum revenues $ 15,534 $ 11,114 $ 7,656 $ 42,592 $ 76,896	Revenues Substantially all revenue-generating activities relate to sales of refined product, branded fuel, renewable diesel and excess crude oil inventories sold at market prices (variable consideration) under contracts with customers. Additionally, we have revenues attributable to logistics services provided under petroleum product and crude oil pipeline transportation, processing, storage and terminalling agreements with third parties. Disaggregated revenues were as follows: Years Ended December 31, 2023 2022 2021 (In thousands) Revenues by type Refined product revenues Transportation fuels (1) $ 19,867,388 $ 25,895,867 $ 13,414,543 Specialty lubricant products (2) 2,521,025 2,826,206 2,322,242 Asphalt, fuel oil and other products (3) 2,167,049 2,147,710 948,581 Total refined product revenues 24,555,462 30,869,783 16,685,366 Excess crude oil revenues (4) 2,147,466 2,342,288 1,547,696 Renewable diesel revenues (5) 781,309 654,893 — Transportation and logistic services 117,749 109,200 103,646 Marketing revenues (6) 4,146,292 3,911,922 — Other revenues (7) 216,117 316,753 52,434 Total sales and other revenues $ 31,964,395 $ 38,204,839 $ 18,389,142 Years Ended December 31, 2023 2022 2021 (In thousands) Refined product revenues by market United States Mid-Continent $ 9,362,688 $ 13,924,566 $ 9,094,885 Southwest 3,814,142 4,965,298 3,477,562 Rocky Mountains 9,131,345 9,533,476 2,118,619 Northeast 959,239 1,037,771 824,900 Canada 1,022,174 1,063,961 836,317 Europe, Asia and Latin America 265,874 344,711 333,083 Total refined product revenues $ 24,555,462 $ 30,869,783 $ 16,685,366 (1) Transportation fuels revenues are attributable to our Refining segment wholesale marketing of gasoline, diesel and jet fuel. (2) Specialty lubricant products consist of base oil, waxes, finished lubricants and other specialty fluids. (3) Asphalt, fuel oil and other products revenue include revenues attributable to our Refining and Lubricants & Specialties segments o f $1,928.6 million and $238.4 million, res pectively, for the year ended December 31, 2023. For the year ended December 31, 2022 such revenues attributable to our Refining and Lubricants & Specialties were $1,827.3 million and $314.8 million, respectively. For the year ended December 31, 2021 such revenue attributable to our Refining and Lubricants & Specialties segments were $724.3 million and $224.3 million, respectively. (4) Excess crude oil revenues represent sales of purchased crude oil inventory that at times exceeds the supply needs of our refineries. (5) Renewable diesel revenues are attributable to our Renewables segment. (6) Marketing segment revenues consist primarily of branded gasoline and diesel fuel. (7) Other revenues are principally attributable to our Refining segment. Our consolidated balance sheets reflect contract liabilities related to unearned revenues attributable to future service obligations under our third-party transportation agreements and production agreements from our Sonneborn operations. The following table presents changes to contract liabilities: Years Ended December 31, 2023 2022 2021 (In thousands) Balance at January 1 $ 10,722 $ 9,278 $ 6,738 Increase 21,381 32,040 32,301 Recognized as revenue (24,570) (30,596) (29,761) Balance at December 31 $ 7,533 $ 10,722 $ 9,278 As of December 31, 2023, we have long-term contracts with customers that specify minimum volumes of gasoline, diesel, lubricants and specialties to be sold ratably at market prices through 2032 . Future prices are subject to market fluctuations and therefore, we have elected the exemption to exclude variable consideration under these contracts under ASC 606-10-50-14A. Aggregate minimum volumes expected to be sold (future performance obligations) under our long-term product sales contracts with customers are as follows, which include branded sales volumes assumed upon our acquisition of the Acquired Sinclair Businesses: 2024 2025 2026 Thereafter Total (In thousands) Refined product sales volumes (barrels) 35,563 25,506 17,891 47,240 126,200 Additionally, we have long-term contracts with third-party customers that specify minimum volumes of product to be transported through our pipelines and terminals that result in fixed-minimum annual reven ues throu gh 2033. Annua l minimum revenues attributable to our third-party contracts as of December 31, 2023 are presented below: 2024 2025 2026 Thereafter Total (In thousands) Midstream operations contractual minimum revenues $ 20,656 $ 11,097 $ 7,656 $ 42,592 $ 82,001 For the years ended December 31, 2023, 2022 and 2021, we had one customer, Shell, together with certain of its affiliates, that accounted for 10% or more of our total annual revenues at approximately 12%, 15% and 13%, respectively, which were primarily generated through our Refining segment operations.

Fair Value Measurements

Fair Value Measurements	3 Months Ended	12 Months Ended
Fair Value Measurements	Mar. 31, 2024	Dec. 31, 2023
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements Fair value measurements are derived using inputs (assumptions that market participants would use in pricing an asset or liability, including assumptions about risk). GAAP categorizes inputs used in fair value measurements into three broad levels as follows: • (Level 1) Quoted prices in active markets for identical assets or liabilities. • (Level 2) Observable inputs other than quoted prices included in Level 1, such as quoted prices for similar assets and liabilities in active markets, similar assets and liabilities in markets that are not active or can be corroborated by observable market data. • (Level 3) Unobservable inputs that are supported by little or no market activity and that are significant to the fair value of the assets or liabilities. This includes valuation techniques that involve significant unobservable inputs. The carrying amounts of derivative instruments and RINs credit obligations at March 31, 2024 and December 31, 2023 were as follows: Fair Value by Input Level Carrying Amount Level 1 Level 2 Level 3 (In thousands) March 31, 2024 Assets: Commodity forward contracts $ 8,564 $ — $ 8,564 $ — Foreign currency forward contracts 1,713 — 1,713 — Total assets $ 10,277 $ — $ 10,277 $ — Liabilities: NYMEX futures contracts $ 9,744 $ 9,744 $ — $ — Commodity price swaps 1,310 — 1,310 — Commodity forward contracts 7,336 — 7,336 — Foreign currency forward contracts 691 — 691 — RINs credit obligations (1) 29,553 — 29,553 — Total liabilities $ 48,634 $ 9,744 $ 38,890 $ — Fair Value by Input Level Carrying Amount Level 1 Level 2 Level 3 (In thousands) December 31, 2023 Assets: NYMEX futures contracts $ 836 $ 836 $ — $ — Commodity forward contracts 2,908 — 2,908 — Total assets $ 3,744 $ 836 $ 2,908 $ — Liabilities: Commodity price swaps $ 7,808 $ — $ 7,808 $ — Commodity forward contracts 1,848 — 1,848 — Foreign currency forward contracts 7,893 — 7,893 — Total liabilities $ 17,549 $ — $ 17,549 $ — (1) Represent obligations for RINs credits for which we did not have sufficient quantities at March 31, 2024 to satisfy our Environmental Protection Agency (“EPA”) regulatory blending requirements. Level 1 Fair Value Measurements Our New York Mercantile Exchange (“NYMEX”) futures contracts are exchange-traded and are measured and recorded at fair value using quoted market prices, a Level 1 input. Level 2 Fair Value Measurements Derivative instruments consisting of foreign currency forward contracts, commodity price swaps, commodity collar contracts and forward sales and purchase contracts are measured and recorded at fair value using Level 2 inputs. The fair value of the commodity price swap contracts is based on the net present value of expected future cash flows related to both variable and fixed rate legs of the respective swap agreements. The measurements are computed using market-based observable input and quoted forward commodity prices with respect to our commodity price swaps. The fair value of the commodity collar contracts is based on forward natural gas prices. The fair value of the forward sales and purchase contracts is computed using quoted forward commodity prices. The fair value of foreign currency forward contracts is based on values provided by a third party, which were derived using market quotes for similar type instruments, a Level 2 input. RINs credit obligations are valued based on current market prices.	Fair Value Measurements Fair value measurements are derived using inputs (assumptions that market participants would use in pricing an asset or liability, including assumptions about risk). GAAP categorizes inputs used in fair value measurements into three broad levels as follows: • (Level 1) Quoted prices in active markets for identical assets or liabilities. • (Level 2) Observable inputs other than quoted prices included in Level 1, such as quoted prices for similar assets and liabilities in active markets, similar assets and liabilities in markets that are not active or can be corroborated by observable market data. • (Level 3) Unobservable inputs that are supported by little or no market activity and that are significant to the fair value of the assets or liabilities. This includes valuation techniques that involve significant unobservable inputs. The carrying amounts of derivative instruments and RINs receivable and credit obligations at December 31, 2023 and 2022 were as follows: Carrying Amount Fair Value by Input Level Level 1 Level 2 Level 3 (In thousands) December 31, 2023 Assets: NYMEX futures contracts $ 836 $ 836 $ — $ — Commodity forward contracts 2,908 — 2,908 — Total assets $ 3,744 $ 836 $ 2,908 $ — Liabilities: Commodity price swaps $ 7,808 $ — $ 7,808 $ — Commodity forward contracts 1,848 — 1,848 — Foreign currency forward contracts 7,893 — 7,893 — Total liabilities $ 17,549 $ — $ 17,549 $ — Carrying Amount Fair Value by Input Level Level 1 Level 2 Level 3 (In thousands) December 31, 2022 Assets: Commodity price swaps $ 342 $ — $ 342 $ — Commodity forward contracts 2,949 — 2,949 — RINs receivable (1) 81,232 — 81,232 — Foreign currency forward contracts 15,359 — 15,359 — Total assets $ 99,882 $ — $ 99,882 $ — Liabilities: NYMEX futures contracts $ 2,750 $ 2,750 $ — $ — Commodity collar contracts 6,275 — 6,275 — Commodity forward contracts 2,987 — 2,987 — RINs credit obligations (1) 81,232 — 81,232 — Total liabilities $ 93,244 $ 2,750 $ 90,494 $ — (1) REH Company was financially responsible for satisfaction of RINs credit obligations for all periods prior to the closing of the Sinclair Transactions. See Note 2 for additional information on RINs credit obligations assumed in the Sinclair Transactions. Level 1 Fair Value Measurements Our New York Mercantile Exchange (“NYMEX”) futures contracts are exchange traded and are measured and recorded at fair value using quoted market prices, a Level 1 input. Level 2 Fair Value Measurements Derivative instruments consisting of foreign currency forward contracts, commodity price swaps, commodity collar contracts and forward sales and purchase contracts are measured and recorded at fair value using Level 2 inputs. The fair value of the commodity price swap contracts is based on the net present value of expected future cash flows related to both variable and fixed rate legs of the respective swap agreements. The measurements are computed using market-based observable input and quoted forward commodity prices with respect to our commodity price swaps. The fair value of the commodity collar contracts is based on forward natural gas prices. The fair value of the forward sales and purchase contracts are computed using quoted forward commodity prices. The fair value of foreign currency forward contracts are based on values provided by a third party, which were derived using market quotes for similar type instruments, a Level 2 input. Nonrecurring Fair Value Measurements During the years ended December 31, 2022 and 2021, we recognized assets and liabilities based on fair value measurements for the Sinclair Transactions and the acquisition of Puget Sound Refinery (see Note 2). The fair value measurements were based on a combination of valuation methods including discounted cash flows, the guideline public company and guideline transaction methods and obsolescence adjusted replacement costs, all of which are Level 3 inputs.

Earnings Per Share

Earnings Per Share	3 Months Ended	12 Months Ended
Earnings Per Share	Mar. 31, 2024	Dec. 31, 2023
Earnings Per Share [Abstract]
Earnings Per Share	Earnings Per Share Basic earnings per share is calculated as net income attributable to HF Sinclair stockholders, adjusted for participating securities’ share in earnings divided by the average number of shares of common stock outstanding. Diluted earnings per share includes the incremental shares resulting from certain share-based awards. The following is a reconciliation of the denominators of the basic and diluted per share computations for net income attributable to HF Sinclair stockholders: Three Months Ended 2024 2023 (In thousands, except per share data) Net income attributable to HF Sinclair stockholders $ 314,664 $ 353,266 Participating securities’ share in earnings (1) 1,969 2,925 Net income attributable to common shares $ 312,695 $ 350,341 Average number of shares of common stock outstanding 198,710 195,445 Average number of shares of common stock outstanding assuming dilution 198,710 195,445 Basic earnings per share $ 1.57 $ 1.79 Diluted earnings per share $ 1.57 $ 1.79 (1) Unvested restricted stock unit awards and unvested performance share units that settle in HF Sinclair common stock represent participating securities because they participate in nonforfeitable dividends or distributions with the common stockholders of HF Sinclair. Participating earnings represent the distributed and undistributed earnings of HF Sinclair attributable to the participating securities. Unvested restricted stock unit awards and performance share units do not participate in undistributed net losses as they are not contractually obligated to do so.	Earnings Per Share Basic earnings per share is calculated as net income attributable to HF Sinclair stockholders, adjusted for participating securities’ share in earnings divided by the average number of shares of common stock outstanding. Diluted earnings per share includes the incremental shares resulting from certain share-based awards. The following is a reconciliation of the denominators of the basic and diluted per share computations for net income attributable to HF Sinclair stockholders: Years Ended December 31, 2023 2022 2021 (In thousands, except per share data) Net income attributable to HF Sinclair stockholders $ 1,589,666 $ 2,922,668 $ 558,324 Participating securities’ share in earnings (1) 14,045 29,465 7,465 Net income attributable to common shares $ 1,575,621 $ 2,893,203 $ 550,859 Average number of shares of common stock outstanding 190,035 202,566 162,569 Average number of shares of common stock outstanding assuming dilution 190,035 202,566 162,569 Basic earnings per share $ 8.29 $ 14.28 $ 3.39 Diluted earnings per share $ 8.29 $ 14.28 $ 3.39 (1) Unvested restricted stock unit awards and unvested performance share units that settle in HF Sinclair common stock represent participating securities because they participate in nonforfeitable dividends or distributions with the common stockholders of HF Sinclair. Participating earnings represent the distributed and undistributed earnings of HF Sinclair attributable to the participating securities. Unvested restricted stock unit awards and performance share units do not participate in undistributed net losses as they are not contractually obligated to do so.

Stock-Based Compensation

Stock-Based Compensation	3 Months Ended	12 Months Ended
Stock-Based Compensation	Mar. 31, 2024	Dec. 31, 2023
Share-Based Payment Arrangement [Abstract]
Stock-Based Compensation	Stock-Based Compensation We have a principal share-based compensation plan, the HF Sinclair Corporation Amended and Restated 2020 Long Term Incentive Plan (the “2020 Plan”). The 2020 Plan provides for the grant of unrestricted and restricted stock, restricted stock units, other stock-based awards, stock options, performance awards, substitute awards, cash awards and stock appreciation rights. The restricted stock unit awards generally vest over a period of one The compensation cost for these plans was $5.8 million and $3.3 million for the three months ended March 31, 2024 and 2023 , respectively. Additionally, prior to the HEP Merger Transaction, HEP maintained an equity-based compensation plan for the General Partner’s non-employee directors and certain executives and employees. Compensation costs attributable to HEP’s equity-based compensation plan was $0.4 million for the three months ended March 31, 2023. A summary of restricted stock units and performance share units activity during the three months ended March 31, 2024, is presented below: Restricted Stock Units Performance Share Units Outstanding at January 1, 2024 1,102,755 485,531 Granted (1) 2,020 — Vested (153,811) (1,859) Forfeited (186,799) (49,060) Outstanding at March 31, 2024 764,165 434,612 (1) Weighted average grant date fair value per unit $ 59.52 $ —	Stock-Based Compensation We have a principal share-based compensation plan (the HF Sinclair Corporation Amended and Restated 2020 Long Term Incentive Plan, the “2020 Plan”). The 2020 Plan provides for the grant of unrestricted and restricted stock, restricted stock units, other stock-based awards, stock options, performance awards, substitute awards, cash awards and stock appreciation rights. Subject to adjustment for certain events, an aggregate of 6,368,930 of these awards may be issued pursuant to awards granted under the 2020 Plan. We also have a stock compensation deferral plan which allows non-employee directors to defer settlement of vested stock granted under our share-based compensation plan. Our accounting policy for the recognition of compensation expense for awards with pro-rata vesting is to expense the costs ratably over the vesting periods. Share-based awards paid in cash upon vesting are accounted for as liability awards and recorded at fair value at the end of each reporting period with a mark-to-mark adjustment recognized in earnings. The stock-based compensation expense and associated tax benefit were as follows: Years Ended December 31, 2023 2022 2021 (In thousands) Compensation expense: Restricted stock units $ 30,067 $ 27,264 $ 29,453 Performance stock units 12,145 8,683 12,591 Total compensation expense $ 42,212 $ 35,947 $ 42,044 Tax benefit recognized on compensation expense $ 10,203 $ 8,918 $ 10,545 Additionally, prior to the HEP Merger Transaction, HEP maintained an equity-based compensation plan for Holly Logistic Services, L.L.C.'s non-employee directors and certain executives and employees (the “HEP LTIP”). Compensation cost attributable to HEP’s equity-based compensation plan was $1.5 million, $1.9 million and $2.6 million for the years ended December 31, 2023, 2022 and 2021, respectively. In connection with the HEP Merger Transaction, on December 4, 2023, HF Sinclair registered additional shares of HF Sinclair common stock under the 2020 Plan pursuant to General Instruction E of Form S-8, which authorized the 2020 Plan’s assumption of authorized but unissued HEP common units remaining under the HEP LTIP at the time of the HEP Merger Transaction, adjusted to reflect the applicable exchange rate pursuant to the HEP Merger Transaction. Restricted Stock Units Under the 2020 Plan, we grant certain officers and other key employees restricted stock unit awards, which are payable in stock or cash and generally vest over a period of one A summary of restricted stock unit activity during the year ended December 31, 2023 is presented below: Restricted Stock Units Grants Weighted Average Grant Date Fair Value Outstanding at January 1, 2023 1,055,875 $ 39.46 Granted 529,559 $ 52.59 Vested (641,944) $ 33.17 Forfeited (65,952) $ 38.55 Converted from performance share units 225,217 $ 45.46 Outstanding at December 31, 2023 1,102,755 $ 50.71 For the years ended December 31, 2023, 2022 and 2021, restricted stock units vested having a grant date fair value of $21.3 million, $26.5 million and $28.4 million, respectively. For the years ended December 31, 2022 and 2021, we granted restricted stock units having a weighted average grant date fair value of $59.41 and $33.95, respectively. As of December 31, 2023, there was $28.9 million of total unrecognized compensation cost related to non-vested restricted stock unit grants. That cost is expected to be recognized over a weighted-average period of 1.5 years. For the years ended December 31, 2023, 2022 and 2021, we paid $3.9 million, $5.8 million and $3.4 million, respectively, in cash equal to the value of the stock award on the vest date to certain employees to settle 71,589, 96,005 and 105,459 restricted stock units, respectively. Performance Share Units Under the 2020 Plan, we grant certain officers and other key employees performance share units, which are payable in stock or cash upon meeting certain criteria over the service period, and generally vest over a period of three years. Under the terms of our performance share unit grants, awards are subject to “financial performance” and “market performance” criteria. Financial performance is based on our financial performance compared to a peer group of independent refining companies, while market performance is based on the relative standing of total shareholder return achieved by HF Sinclair compared to peer group companies. The number of shares ultimately issued or cash paid under these awards can range from zero to 200% of target award amounts. Holders of performance share units have the right to receive dividend equivalents and other distributions with respect to such performance share units based on the target level of payout. A summary of performance share unit activity and changes during the year ended December 31, 2023 is presented below: Performance Share Units Grants Weighted Average Grant Date Fair Value Outstanding at January 1, 2023 771,197 $ 41.78 Granted 263,881 $ 67.73 Vested (298,978) $ 24.47 Forfeited (25,352) $ 40.76 Converted to restricted stock units (225,217) $ 52.44 Outstanding at December 31, 2023 485,531 $ 61.66 For the year ended December 31, 2023, we issued 375,376 shares of common stock, representing a payout of up to 125% on vested performance share units having a grant date fair value of $7.3 million. For the years ended December 31, 2022 and 2021, we issued common stock upon the vesting of the performance share units having a grant date fair value of $6.2 million and $4.5 million, respectively. As of December 31, 2023, there was $20.1 million of total unrecognized compensation cost related to non-vested performance share units. That cost is expected to be recognized over a weighted-average period of 2.2 years. For the years ended December 31, 2023 and 2022, we paid $1.2 million and $0.7 million, respectively, in cash equal to the value of the stock award on the vest date to certain employees to settle 23,587 and 12,108 performance share units, respectively.

Inventories

Inventories	3 Months Ended	12 Months Ended
Inventories	Mar. 31, 2024	Dec. 31, 2023
Inventory Disclosure [Abstract]
Inventories	Inventories Inventories consist of the following components: March 31, December 31, (In thousands) Crude oil $ 798,070 $ 858,411 Other raw materials and unfinished products (1) 743,302 683,066 Finished products (2) 1,438,867 1,435,817 Lower of cost or market reserve (112,200) (331,570) Process chemicals (3) 38,731 50,917 Repair and maintenance supplies and other (4) 224,115 225,190 Total inventory $ 3,130,885 $ 2,921,831 (1) Other raw materials and unfinished products include feedstocks and blendstocks, other than crude. (2) Finished products include gasolines, jet fuels, diesels, renewable diesels, lubricants, asphalts, LPG’s and residual fuels. (3) Process chemicals include additives and other chemicals. (4) Includes RINs. At March 31, 2024, the LIFO value of our Refining segment inventories was equal to cost. T h e December 31, 2023, market reserve of $220.6 million reversed resulting in a decrease to cost of products sold totaling $220.6 million for the three months ended March 31, 2024. Our Renewables segment inventories that are valued at the lower of LIFO cost or market reflect a valuation reserve of $112.2 million and $111.0 million at March 31, 2024 and December 31, 2023, respectively. A new market reserve of $112.2 million as of March 31, 2024, was based on market conditions and prices at that time. The effect of the change in the lower of cost or market reserve was an increase to cost of products sold totaling $1.2 million for the three months ended March 31, 2024, and an increase to cost of products sold totaling $47.6 million for the three months ended March 31, 2023.	Inventories Inventories consist of the following components: December 31, 2023 2022 (In thousands) Crude oil $ 858,411 $ 818,737 Other raw materials and unfinished products (1) 683,066 842,855 Finished products (2) 1,435,817 1,252,984 Lower of cost or market reserve (331,570) (61,151) Process chemicals (3) 50,917 53,900 Repairs and maintenance supplies and other (4) 225,190 307,203 Total inventory $ 2,921,831 $ 3,214,528 (1) Other raw materials and unfinished products include feedstocks and blendstocks, other than crude. (2) Finished products include gasolines, jet fuels, diesels, renewable diesels, lubricants, asphalts, LPG’s and residual fuels. (3) Process chemicals include additives and other chemicals. (4) Includes RINs. Our Refining segment inventories that are valued at the lower of LIFO cost or market reflect a new market reserve of $220.6 million that was established as of December 31, 2023 based on market conditions and prices at that time. The effect of the change in the lower of cost or market reserve was an increase to cost of products sold totaling $220.6 million for the year ended December 31, 2023. The excess replacement cost over the LIFO value of our Refining segment inventories was $39.0 million at December 31, 2022. For the year ended December 31, 2021, we recorded a decrease to cost of products sold of $318.9 million due to the effect of the change in the lower of cost or market reserve recorded on our Refining segment inventories at that time. Our Renewables segment inventories that are valued at the lower of LIFO cost or market reflect a valuation reserve of $111.0 million and $61.2 million at December 31, 2023 and 2022, respectively. A new market reserve of $111.0 million as of December 31, 2023 was based on market conditions and prices at that time. The effect of the change in the lower of cost or market reserve was an increase of cost of products sold totaling $49.9 million and $52.4 million for the years ended December 31, 2023 and 2022, respectively.

Environmental

Environmental	3 Months Ended	12 Months Ended
Environmental	Mar. 31, 2024	Dec. 31, 2023
Environmental Expense and Liabilities [Abstract]
Environmental	Environmental Environmental costs are charged to operating expenses if they relate to an existing condition caused by past operations and do not contribute to current or future revenue generation. We have ongoing investigations of environmental matters at various locations and routinely assess our recorded environmental obligations, if any, with respect to such matters. Liabilities are recorded when site restoration, environmental remediation, cleanup and other obligations are known or considered probable and can be reasonably estimated. Such estimates are undiscounted and require judgment with respect to costs, time frame and extent of required remedial and cleanup activities and are subject to periodic adjustments based on currently available information. Recoveries of environmental costs through insurance, indemnification arrangements or other sources are included in other assets to the extent such recoveries are considered probable. We incurred expenses of $1.8 million and $13.3 million for the three months ended March 31, 2024 and 2023 , respectively, for environmental remediation obligations. The accrued environmental liability reflected on our consolidated balance sheets was $191.6 million and $195.4 million at March 31, 2024 and December 31, 2023, respectively, of which $164.4 million and $161.4 million, respectively, were classified as other long-term liabilities. These accruals include remediation and monitoring costs expected to be incurred over an extended period of time. Estimated liabilities could increase in the future when the results of ongoing investigations become known, are considered probable and can be reasonably estimated.	Environmental We expense d $26.5 million, $13.4 million and $7.8 million for the years ended December 31, 2023, 2022 and 2021, respectively, for environmental remediation obligations. The accrued environmental liability reflected on our consolidated balance sheets was $195.4 million and $192.3 million at December 31, 2023 and 2022, respectively, of w hich $161.4 million and $170.0 million, respectively, were classified as other long-term liabilities. These accruals include remediation and monitoring costs expected to be incurred over an extended period of time. Accrued environmental liabilities assumed in the Sinclair Transactions were $72.2 million at the acquisition date and an associated receivable from third parties of $21.5 million. Estimated liabilities could increase in the future when the results of ongoing investigations become known, are considered probable and can be reasonably estimated.

Debt

Debt	3 Months Ended	12 Months Ended
Debt	Mar. 31, 2024	Dec. 31, 2023
Debt Disclosure [Abstract]
Debt	Debt HF Sinclair Credit Agreement We have a $1.65 billion senior unsecured revolving credit facility m aturing in April 2026 (the “HF Sinclair Credit Agreement”). The HF Sinclair Credit Agreement may be used for revolving credit loans and letters of credit from time to time and is available to fund general corporate purposes. At March 31, 2024, we were in compliance with all covenants, had no outstanding borrowings and had outstanding letters of credit totaling $0.3 million under the HF Sinclair Credit Agreement. Indebtedness under the HF Sinclair Credit Agreement bears interest, at our option, based on the currency of such indebtedness at either (a) a base rate equal to the highest of the Federal Funds Effective Rate (as defined in the HF Sinclair Credit Agreement) plus 0.5%, Spread Adjusted Term SOFR (as defined in the HF Sinclair Credit Agreement) for a one-month interest period plus 1% and the prime rate (as publicly announced from time to time by the administrative agent), as applicable, plus an applicable margin (ranging from 0.25% to 1.125%), (b) the CDOR Rate (as defined in the HF Sinclair Credit Agreement) plus an applicable margin (ranging from 1.25% to 2.125%), (c) the Spread Adjusted Term SOFR (as defined in the HF Sinclair Credit Agreement) plus an applicable margin (ranging from 1.25% to 2.125%) or (d) the Daily Simple RFR (as defined in the HF Sinclair Credit Agreement) plus an applicable margin (ranging from 1.25% to 2.125%). In each case, the applicable margin is based on HF Sinclair’s debt rating assigned by Standard & Poor’s Financial Services LLC and Moody’s Investors Service, Inc. HEP Credit Agreement Our wholly owned subsidiary, HEP, has a $1.2 billion seni or secured revolving credit facility maturing in July 2025 (the “HEP Credit Agreement”). In connection with the consummation of the HEP Merger Transaction, we amended the HEP Credit Agreement to, among other things, (a) provide a guaranty from us and terminate all guaranties from subsidiaries of HEP, (b) amend the definition of “Investment Grade Rating” (as defined in the HEP Credit Agreement) to reference the credit rating of our senior unsecured indebtedness, (c) eliminate the requirement to deliver separate audited and unaudited financial statements for HEP and its subsidiaries and only provide certain segment-level reporting for HEP with any compliance certificate delivered in accordance with the HEP Credit Agreement and (d) amend certain covenants to eliminate certain restrictions on (i) amendments to intercompany contracts, (ii) transactions with us and our subsidiaries and (iii) investments in and contributions, dividends, transfers and distributions to us and our subsidiaries. The HEP Credit Agreement is available to fund capital expenditures, investments, acquisitions, distribution payments, working capital and for general corporate purposes. It is also available to fund letters of credit up to a $50 million sub-limit and has an accordion feature that allows us to increase the commitments under the HEP Credit Agreement up to a maximum amount of $1.7 billion. At March 31, 2024, we were in compliance with all of its covenants, had outstanding borrowings of $394.0 million an d no outstanding letters of credit under the HEP Credit Agreement. Prior to the Investment Grade Date (as defined in the HEP Credit Agreement), indebtedness under the HEP Credit Agreement bears interest, at our option, at either (a) the Alternate Base Rate (as defined in the HEP Credit Agreement) plus an applicable margin (ranging from 0.75% to 1.75%) or (b) Adjusted Term SOFR (as defined in the HEP Credit Agreement) plus an applicable margin (ranging from 1.75% to 2.75%). In each case, the applicable margin is based upon the Total Leverage Ratio (as defined in the HEP Credit Agreement). The weighted average interest rate in effect under the HEP Credit Agreement on our borrowings was 7.05% as of March 31, 2024. Senior Notes At March 31, 2024 , our senior notes consisted of the following: • $202.900 million in aggregate principal amount of 5.875% senior notes maturing April 2026 (the “HollyFrontier 5.875% Senior Notes”), • $74.966 million in aggregate principal amount of 4.500% senior notes maturing October 2030 (the “HollyFrontier 4.500% Senior Notes” and, collectively, with the HollyFrontier 5.875% Senior Notes, the “HollyFrontier Senior Notes”), • $797.100 million in aggregate principal amount of 5.875% senior notes maturing April 2026 (the “HF Sinclair 5.875% Senior Notes”), • $325.034 million in aggregate principal amount of 4.500% senior notes maturing October 2030 (the “HF Sinclair 4.500% Senior Notes”), • $498.879 million in aggregate principal amount of 5.000% senior notes maturing February 2028 (the “HF Sinclair 5.000% Senior Notes”), • $399.875 million in aggregate principal amount of 6.375% senior notes maturing April 2027 (the “HF Sinclair 6.375% Senior Notes” and, collectively with the HF Sinclair 5.875% Senior Notes, HF Sinclair 4.500% Senior Notes and HF Sinclair 5.000% Senior Notes, the “HF Sinclair Senior Notes”), • $1.121 million in aggregate principal amount of 5.000% senior notes maturing February 2028 (the “HEP 5.000% Senior Notes”), and • $0.125 million in aggregate principal amount of 6.375% senior notes maturing April 2027 (the “HEP 6.375% Senior Notes” and, collectively with the HEP 5.000% Senior Notes, the “HEP Senior Notes”). Our unsecured senior notes and unsubordinated obligations rank equally with all future unsecured and unsubordinated indebtedness. Further, we may from time to time seek to retire some or all of our outstanding debt or debt agreements through cash purchases, and/or exchanges, open market purchases, privately negotiated transactions, tender offers or otherwise. Such transactions, if any, may be material and will depend on prevailing market conditions, our liquidity requirements and other factors. HF Sinclair Financing Arrangements Certain of our wholly owned subsidiaries entered into financing arrangements whereby such subsidiaries sold a portion of their precious metals catalyst to a financial institution and then leased back the precious metals catalyst in exchange for cash. The volume of the precious metals catalyst and the lease rate are fixed over the term of each lease, and the lease payments are recorded as interest expense. The current leases mature in one year or less. Upon maturity, we must either satisfy the obligation at fair market value or refinance to extend the maturity. These financing arrangements are recorded at a Level 2 fair value totaling $34.3 million and $37.0 million at March 31, 2024 and December 31, 2023, respectively, and are included in “Accrued liabilities” on our consolidated balance sheets. See Note 4 for additional information on Level 2 inputs. HF Sinclair may, from time to time, issue letters of credit pursuant to uncommitted letters of credit facilities with its lenders. At March 31, 2024, there were no letters of credit outstanding under such credit facilities. The carrying amounts of long-term debt are as follows: March 31, December 31, (In thousands) HollyFrontier 5.875% Senior Notes $ 202,900 $ 202,900 4.500% Senior Notes 74,966 74,966 277,866 277,866 HF Sinclair 5.875% Senior Notes 797,100 797,100 4.500% Senior Notes 325,034 325,034 5.000% Senior Notes 498,879 498,879 6.375% Senior Notes 399,875 399,875 2,020,888 2,020,888 HEP 5.000% Senior Notes 1,121 1,121 6.375% Senior Notes 125 125 1,246 1,246 HEP Credit Agreement 394,000 455,500 Unamortized discount and debt issuance costs (15,355) (16,417) Total long-term debt, net $ 2,678,645 $ 2,739,083 The fair values of the senior notes are as follows: March 31, December 31, (In thousands) HF Sinclair, HollyFrontier and HEP Senior Notes $ 2,268,035 $ 2,271,856 These fair values are based on a Level 2 input. See Note 4 for additional information on Level 2 inputs. We capitalized $0.7 million and $1.2 million for the three months ended March 31, 2024 and 2023, respectively, of interest attributable to construction projects.	Debt HF Sinclair Credit Agreement We have a $1.65 billion senior unsecured revolving credit facility maturing in April 2026 (the “HF Sinclair Credit Agreement”). The HF Sinclair Credit Agreement may be used for revolving credit loans and letters of credit from time to time and is available to fund general corporate purposes. At December 31, 2023, we were in compliance with all covenants, had no outstanding borrowings and had outstanding letters of credit totaling $0.3 million under the HF Sinclair Credit Agreement. Indebtedness under the HF Sinclair Credit Agreement bears interest, at our option based on the currency of such indebtedness at either (a) a base rate equal to the highest of the Federal Funds Effective Rate (as defined in the HF Sinclair Credit Agreement) plus half of 1%, Spread Adjusted Term SOFR (as defined in the HF Sinclair Credit Agreement) for a one-month interest period plus 1% and the prime rate (as publicly announced from time to time by the administrative agent), as applicable, plus an applicable margin (ranging from 0.25% - 1.125%), (b) the CDOR Rate (as defined in the HF Sinclair Credit Agreement) plus an applicable margin (ranging from 1.25% to 2.125%), (c) the Spread Adjusted Term SOFR (as defined in the HF Sinclair Credit Agreement) plus an applicable margin (ranging from 1.25% to 2.125%) or (d) the Daily Simple RFR (as defined in the HF Sinclair Credit Agreement) plus an applicable margin (ranging from 1.25% to 2.125%). In each case, the applicable margin is based on HF Sinclair's debt rating assigned by Standard & Poor’s Financial Services LLC and Moody’s Investors Service, Inc. HEP Credit Agreement Our wholly owned subsidiary, HEP, has a $1.2 billion senior secured revolving credit facility maturing in July 2025 (the “HEP Credit Agreement”). In connection with the consummation of the HEP Merger Transaction, we amended the HEP Credit Agreement to, among other things, (a) provide a guaranty from us and terminated all guaranties from subsidiaries of HEP, (b) amended the definition of “Investment Grade Rating” (as defined in the HEP Credit Agreement) to reference the credit rating of our senior unsecured indebtedness, (c) eliminated the requirement to deliver separate audited and unaudited financial statements for HEP and its subsidiaries and only provide certain segment-level reporting for HEP with any compliance certificate delivered in accordance with the HEP Credit Agreement and (d) amended certain covenants to eliminate certain restrictions on (i) amendments to intercompany contracts, (ii) transactions with us and our subsidiaries and (iii) investments in and contributions, dividends, transfers and distributions to us and our subsidiaries. The HEP Credit Agreement is available to fund capital expenditures, investments, acquisitions, distribution payments, working capital and for general corporate purposes. It is also available to fund letters of credit up to a $50 million sub-limit and has an accordion feature that allows us to increase the commitments under the HEP Credit Agreement up to a maximum amount of $1.7 billion. At December 31, 2023, we were in compliance with all of its covenants, had outstanding borrowings of $455.5 million an d no outstanding letters of credit under the HEP Credit Agreement. Prior to the Investment Grade Date (as defined in the HEP Credit Agreement), indebtedness under the HEP Credit Agreement bears interest, at our option, at either (a) the Alternate Base Rate (as defined in the HEP Credit Agreement) plus an applicable margin (ranging from 0.75% - 1.75%) or (b) Adjusted Term SOFR (as defined in the HEP Credit Agreement) plus an applicable margin (ranging from 1.75% - 2.75%). In each case, the applicable margin is based upon the Total Leverage Ratio (as defined in the HEP Credit Agreement). The weighted average interest rate in effect under the HEP Credit Agreement on our borrowings was 7.08% and 6.32% as of December 31, 2023 and 2022, respectively. HEP Senior Notes Exchange On December 4, 2023, we completed our offers to exchange any and all outstanding HEP 5.000% senior notes maturing February 2028 (the “HEP 5.000% Senior Notes”) and HEP 6.375% senior notes maturing April 2027 (the “HEP 6.375% Senior Notes” and, collectively with the HEP 5.000% Senior Notes, the “HEP Senior Notes”) for the HF Sinclair 5.000% senior notes maturing February 2028 (the “HF Sinclair 5.000% Senior Notes”) and the HF Sinclair 6.375% senior notes maturing April 2027 (the “HF Sinclair 6.375% Senior Notes”, and, collectively with the HF Sinclair 5.000% Senior Notes , the “New HF Sinclair Senior Notes”) to be issued by HF Sinclair with registration rights and cash. In connection with the exchange offers, HEP amended the indenture governing the HEP Senior Notes to eliminate (i) substantially all of the restrictive covenants, (ii) certain of the events which may lead to an “Event of Default”, (iii) the SEC reporting covenant and (iv) the requirement of HEP to offer to purchase the HEP Senior Notes upon a change of control. The New HF Sinclair Senior Notes are unsecured and unsubordinated obligations of ours and rank equally with all our other existing and future unsecured and unsubordinated indebtedness. Each series of the New HF Sinclair Senior Notes has the same interest rate, interest payment dates, maturity date and redemption terms as the corresponding series of HEP Senior Notes. The New HF Sinclair Senior Notes were issued in exchange for the HEP Senior Notes pursuant to a private exchange offer exempt from registration under the Securities Act of 1933, as amended. Senior Notes At December 31, 2023 , our senior notes consisted of the following: • $202.900 million in aggregate principal amount of 5.875% senior notes maturing April 2026 (the “HollyFrontier 5.875% Senior Notes”), • $74.966 million in aggregate principal amount of 4.500% senior notes maturing October 2030 (the “HollyFrontier 4.500% Senior Notes” and, collectively with the HollyFrontier 5.875% Senior Notes, the “HollyFrontier Senior Notes”), • $797.100 million in aggregate principal amount of 5.875% senior notes maturing April 2026 (the “HF Sinclair 5.875% Senior Notes”), • $325.034 million in aggregate principal amount of 4.500% senior notes maturing October 2030 (the “HF Sinclair 4.500% Senior Notes”), • $498.879 million in aggregate principal amount of HF Sinclair 5.000% Senior Notes, • $399.875 million in aggregate principal amount of HF Sinclair 6.375% Senior Notes (collectively with the HF Sinclair 5.875% Senior Notes, HF Sinclair 4.500% Senior Notes and HF Sinclair 5.000% Senior Notes, the “HF Sinclair Senior Notes”), • $1.121 million in aggregate principal amount of HEP 5.000% Senior Notes and • $0.125 million in aggregate principal amount of HEP 6.375% Senior Notes. Our senior notes are unsecured and unsubordinated obligations of ours and rank equally with all future unsecured and unsubordinated indebtedness. In October 2023, we repaid at maturity our $59.6 million aggregate principal amount HollyFrontier 2.625% senior notes maturing October 2023 (the “HollyFrontier 2.625% Senior Notes”) and $248.2 million aggregate principal amount HF Sinclair 2.625% senior notes maturing October 2023 (the “HF Sinclair 2.625% Senior Notes”). During the fourth quarter of 2022, we made open market repurchases of HF Sinclair 2.625% Senior Notes and HollyFrontier 2.625% Senior Notes that resulted in the extinguishment of $42.2 million in principal of the HF Sinclair 2.625% Senior Notes and fifteen thousand dollars in principal of the HollyFrontier 2.625% Senior Notes. Total cash consideration paid to repurchase the principal amount outstanding, excluding accrued interest, totaled $41.4 million, and we recognized a $0.6 million gain on the extinguishment of debt during the year ended December 31, 2022. Further, we may from time to time seek to retire some or all of our outstanding debt or debt agreements through cash purchases, and/or exchanges, open market purchases, privately negotiated transactions, tender offers or otherwise. Such transactions, if any, may be material and will depend on prevailing market conditions, our liquidity requirements and other factors. HF Sinclair Financing Arrangements Certain of our wholly owned subsidiaries entered into financing arrangements whereby such subsidiaries sold a portion of their precious metals catalyst to a financial institution and then leased back the precious metals catalyst in exchange for cash. The volume of the precious metals catalyst and the lease rate are fixed over the term of each lease, and the lease payments are recorded as interest expense. The current leases mature in one year or less. Upon maturity, we must either satisfy the obligation at fair market value or refinance to extend the maturity. These financing arrangements are recorded at a Level 2 fair value totaling $37.0 million and $39.8 million at December 31, 2023 and 2022, respectively, and are included in “Accrued liabilities” on our consolidated balance sheets. See Note 6 for additional information on Level 2 inputs. HF Sinclair may, from time to time, issue letters of credit pursuant to uncommitted letters of credit facilities with its lenders. At December 31, 2023, there were no l etters of credit outstanding under such credit facilities. The carrying amounts of outstanding debt are as follows: December 31, 2023 2022 (In thousands) HollyFrontier 2.625% Senior Notes $ — $ 59,637 5.875% Senior Notes 202,900 202,900 4.500% Senior Notes 74,966 74,966 277,866 337,503 HF Sinclair 2.625% Senior Notes $ — $ 248,190 5.875% Senior Notes 797,100 797,100 4.500% Senior Notes 325,034 325,034 5.000% Senior Notes 498,879 — 6.375% Senior Notes 399,875 — 2,020,888 1,370,324 HEP 5.000% Senior Notes 1,121 500,000 6.375% Senior Notes 125 400,000 1,246 900,000 HEP Credit Agreement 455,500 668,000 Less current debt (1) — (306,959) Unamortized discount and debt issuance costs (1) (16,417) (20,355) Total long-term debt (2) $ 2,739,083 $ 2,948,513 (1) The 2.625% HollyFrontier Senior Notes and HF Sinclair 2.625% Senior Notes, inclusive of unamortized discount and debt issuance costs of $0.9 million at December 31, 2022 were due October 2023 and were classified as current debt on our consolidated balance sheets. (2) At December 31, 2022, total HF Sinclair standalone long-term debt, which excluded HEP long-term debt, was $1.4 billion. The fair values of the senior notes are as follows: December 31, 2023 2022 (In thousands) HollyFrontier and HF Sinclair Senior Notes $ 2,270,668 $ 1,655,726 HEP Senior Notes $ 1,188 $ 852,658 These fair values are based on a Level 2 input. See Note 6 for additional information on Level 2 inputs. Principal maturities of outstanding debt as of December 31, 2023 are as follows: Years Ending December 31, (In thousands) 2024 $ — 2025 455,500 2026 1,000,000 2027 400,000 2028 500,000 Thereafter 400,000 Total $ 2,755,500

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	3 Months Ended	12 Months Ended
Derivative Instruments and Hedging Activities	Mar. 31, 2024	Dec. 31, 2023
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	Derivative Instruments and Hedging Activities Commodity Price Risk Management Our primary market risk is commodity price risk. We are exposed to market risks related to the volatility in crude oil and refined products, as well as volatility in the price of natural gas used in our refining operations. We periodically enter into derivative contracts in the form of commodity price swaps, collar contracts, forward purchase and sales and futures contracts to mitigate price exposure with respect to our inventory positions, natural gas purchases, sales prices of refined products and crude oil costs. Foreign Currency Risk Management We are exposed to market risk related to the volatility in foreign currency exchange rates. We periodically enter into derivative contracts in the form of foreign exchange forward contracts to mitigate the exposure associated with fluctuations on intercompany notes with our foreign subsidiaries that are not denominated in the U.S. dollar. Accounting Hedges We periodically have swap contracts to lock in basis spread differentials on forecasted purchases of crude oil and forward sales contracts that lock in the prices of future sales of crude oil and refined product. These contracts have been designated as accounting hedges and are measured at fair value with offsetting adjustments (gains/losses) recorded directly to other comprehensive income (loss). These fair value adjustments are later reclassified to earnings as the hedging instruments mature. The following table presents the pre-tax effect on other comprehensive income (“OCI”) and earnings due to fair value adjustments and maturities of hedging instruments under hedge accounting: Net Unrealized Gain Loss Reclassified Derivatives Designated as Cash Flow Hedging Instruments Three Months Ended Income Statement Location Three Months Ended 2024 2023 2024 2023 (In thousands) (In thousands) Commodity contracts $ — $ 271 Sales and other revenues $ (4,287) $ (1) Total $ — $ 271 $ (4,287) $ (1) Economic Hedges We have commodity contracts including NYMEX futures contracts to lock in prices on forecasted purchases and sales of inventory and basis swap contracts to mitigate exposure to natural gas price volatility and forward purchase and sell contracts of refined products, as well as periodically have contracts to lock in basis spread differentials on forecasted purchases of crude oil and collar contracts to mitigate exposure to natural gas price volatility, that serve as economic hedges (derivatives used for risk management, but not designated as accounting hedges). We also have forward currency contracts to fix the rate of foreign currency. In addition, our catalyst financing arrangements discussed in Note 9 could require repayment under certain conditions based on the future pricing of platinum, which is an embedded derivative. These contracts are measured at fair value with offsetting adjustments (gains/losses) recorded directly to earnings. The following table presents the pre-tax effect on income due to maturities and fair value adjustments of our economic hedges: Gain (Loss) Recognized in Earnings Derivatives Not Designated as Hedging Instruments Income Statement Location Three Months Ended 2024 2023 (In thousands) Commodity contracts Cost of products sold $ (20,665) $ 6,748 Operating expenses (213) (14,058) Interest expense 2,763 2,406 Foreign currency contracts Gain on foreign currency transactions 10,131 114 Total $ (7,984) $ (4,790) As of March 31, 2024, we have the following notional contract volumes related to outstanding derivative instruments: Notional Contract Volumes by Year of Maturity Derivatives Not Designated as Hedging Instruments Total Outstanding Notional 2024 2025 Unit of Measure NYMEX futures (WTI) - short 2,575,000 2,575,000 — Barrels Forward gasoline and diesel contracts - long 1,190,000 1,190,000 — Barrels Foreign currency forward contracts 386,671,810 281,628,809 105,043,001 U.S. dollar Forward commodity contracts (platinum) 36,969 14,549 22,420 Troy ounces Natural gas price swaps (basis spread) - long 3,300,000 3,300,000 — MMBTU The following tables present the fair value and balance sheet locations of our outstanding derivative instruments. These amounts are presented on a gross basis with offsetting balances that reconcile to a net asset or liability position in our consolidated balance sheets. We present on a net basis to reflect the net settlement of these positions in accordance with provisions of our master netting arrangements. Derivatives in Net Asset Position Derivatives in Net Liability Position Gross Assets Gross Liabilities Offset in Balance Sheet Net Assets Recognized in Balance Sheet Gross Liabilities Gross Assets Offset in Balance Sheet Net Liabilities Recognized in Balance Sheet (In thousands) March 31, 2024 Derivatives not designated as cash flow hedging instruments: NYMEX futures contracts $ — $ — $ — $ 9,744 $ — $ 9,744 Commodity price swap contracts — — — 1,310 — 1,310 Commodity forward contracts 8,564 — 8,564 7,336 — 7,336 Foreign currency forward contracts 1,713 — 1,713 1,771 (1,080) 691 $ 10,277 $ — $ 10,277 $ 20,161 $ (1,080) $ 19,081 Total net balance $ 10,277 $ 19,081 Balance sheet classification: Prepayment and other $ 10,277 Accrued liabilities $ 19,081 Derivatives in Net Asset Position Derivatives in Net Liability Position Gross Assets Gross Liabilities Offset in Balance Sheet Net Assets Recognized in Balance Sheet Gross Liabilities Gross Assets Offset in Balance Sheet Net Liabilities Recognized in Balance Sheet (In thousands) December 31, 2023 Derivatives not designated as cash flow hedging instruments: NYMEX futures contracts $ 836 $ — $ 836 $ — $ — $ — Commodity price swap contracts — — — 7,808 — 7,808 Commodity forward contracts 2,908 — 2,908 1,848 — 1,848 Foreign currency forward contracts — — — 7,893 — 7,893 $ 3,744 $ — $ 3,744 $ 17,549 $ — $ 17,549 Total net balance $ 3,744 $ 17,549 Balance sheet classification: Prepayment and other $ 3,744 Accrued liabilities $ 17,549	Derivative Instruments and Hedging Activities Commodity Price Risk Management Our primary market risk is commodity price risk. We are exposed to market risks related to the volatility in crude oil and refined products, as well as volatility in the price of natural gas used in our refining operations. We periodically enter into derivative contracts in the form of commodity price swaps, collar contracts, forward purchase and sales and futures contracts to mitigate price exposure with respect to our inventory positions, natural gas purchases, sales prices of refined products and crude oil costs. Foreign Currency Risk Management We are exposed to market risk related to the volatility in foreign currency exchange rates. We periodically enter into derivative contracts in the form of foreign exchange forward contracts to mitigate the exposure associated with fluctuations on intercompany notes with our foreign subsidiaries that are not denominated in the U.S. dollar. Accounting Hedges We had swap contracts serving as cash flow hedges against price risk on forecasted purchases of natural gas that matured as of December 31, 2021. We also periodically have swap contracts to lock in basis spread differentials on forecasted purchases of crude oil and forward sales contracts that lock in the prices of future sales of crude oil and refined product. These contracts have been designated as accounting hedges and are measured at fair value with offsetting adjustments (gains/losses) recorded directly to other comprehensive income (loss). These fair value adjustments are later reclassified to earnings as the hedging instruments mature. The following table presents the pre-tax effect on other comprehensive income (“OCI”) and earnings due to fair value adjustments and maturities of hedging instruments under hedge accounting: Net Unrealized Gain Recognized in OCI Gain (Loss) Reclassified into Earnings Derivatives Designated as Cash Flow Hedging Instruments Years Ended December 31, Income Statement Location Years Ended December 31, 2023 2022 2021 2023 2022 2021 (In thousands) Commodity contracts $ — $ 326 $ 31 Sales and other revenues $ (3,236) $ (5,288) $ (19,239) Operating expenses — — 1,660 Total $ — $ 326 $ 31 $ (3,236) $ (5,288) $ (17,579) Economic Hedges We have commodity contracts including NYMEX futures contracts to lock in prices on forecasted purchases and sales of inventory and basis swap contracts to mitigate exposure to natural gas price volatility and forward purchase and sell contracts of refined products, as well as periodically have contracts to lock in basis spread differentials on forecasted purchases of crude oil and collar contracts to mitigate exposure to natural gas price volatility, that serve as economic hedges (derivatives used for risk management, but not designated as accounting hedges). We also have forward currency contracts to fix the rate of foreign currency. In addition, our catalyst financing arrangements discussed in Note 13 could require repayment under certain conditions based on the future pricing of platinum, which is an embedded derivative. These contracts are measured at fair value with offsetting adjustments (gains/losses) recorded directly to earnings. The following table presents the pre-tax effect on earnings due to maturities and fair value adjustments of our economic hedges: Gain (Loss) Recognized in Earnings Derivatives Not Designated as Hedging Instruments Years Ended December 31, Income Statement Location 2023 2022 2021 (In thousands) Commodity contracts Cost of products sold $ 10,162 $ (17,189) $ (22,909) Operating expenses (20,783) (13,780) — Interest expense 2,050 (4,420) 11,816 Foreign currency contracts Gain (loss) on foreign currency transactions (7,414) 27,826 (4,013) Total $ (15,985) $ (7,563) $ (15,106) As of December 31, 2023, we have the following notional contract volumes related to outstanding derivative instruments (all maturing in 2024): Total Outstanding Notional Unit of Measure Derivatives not designated as hedging instruments: NYMEX futures (WTI) - short 640,000 Barrels Forward gasoline contracts - long 800,000 Barrels Foreign currency forward contracts 387,613,367 U. S. dollar Forward commodity contracts (platinum) 36,969 Troy ounces Natural gas price swaps (basis spread) - long 6,667,000 MMBTU The following table presents the fair value and balance sheet locations of our outstanding derivative instruments. These amounts are presented on a gross basis with offsetting balances that reconcile to a net asset or liability position on our consolidated balance sheets. We present on a net basis to reflect the net settlement of these positions in accordance with provisions of our master netting arrangements. Derivatives in Net Asset Position Derivatives in Net Liability Position Gross Assets Gross Liabilities Offset in Balance Sheet Net Assets Recognized in Balance Sheet Gross Liabilities Gross Assets Offset in Balance Sheet Net Liabilities Recognized in Balance Sheet (In thousands) December 31, 2023 Derivatives not designated as cash flow hedging instruments: NYMEX futures contracts $ 836 $ — $ 836 $ — $ — $ — Commodity price swap contracts — — — 7,808 — 7,808 Commodity forward contracts 2,908 — 2,908 1,848 — 1,848 Foreign currency forward contracts — — — 7,893 — 7,893 $ 3,744 $ — $ 3,744 $ 17,549 $ — $ 17,549 Total net balance $ 3,744 $ 17,549 Balance sheet classification: Prepayment and other $ 3,744 Accrued liabilities $ 17,549 Derivatives in Net Asset Position Derivatives in Net Liability Position Gross Assets Gross Liabilities Offset in Balance Sheet Net Assets Recognized in Balance Sheet Gross Liabilities Gross Assets Offset in Balance Sheet Net Liabilities Recognized in Balance Sheet (In thousands) December 31, 2022 Derivatives not designated as cash flow hedging instruments: NYMEX futures contracts $ — $ — $ — $ 2,750 $ — $ 2,750 Commodity price swap contracts 342 — 342 — — — Commodity collar contracts — — — 6,275 — 6,275 Commodity forward contracts 2,949 — 2,949 2,987 — 2,987 Foreign currency forward contracts 15,359 — 15,359 — — — $ 18,650 $ — $ 18,650 $ 12,012 $ — $ 12,012 Total net balance $ 18,650 $ 12,012 Balance sheet classification: Prepayments and other $ 18,650 Accrued liabilities $ 12,012

Stockholders' Equity

Stockholders' Equity	3 Months Ended	12 Months Ended
Stockholders' Equity	Mar. 31, 2024	Dec. 31, 2023
Equity [Abstract]
Stockholders' Equity	Stockholders ’ Equity In August 2023, our Board of Directors approved a $1.0 billion share repurchase program (the “August 2023 Share Repurchase Program”), which replaced all existing share repurchase programs at that time. The August 2023 Share Repurchase Program authorized us to repurchase common stock in the open market or through privately negotiated transactions. Privately negotiated repurchases from REH Company were also authorized under this share repurchase program, subject to REH Company’s interest in selling its shares and other limitations. As of March 31, 2024, we had remaining authorization to repurchase up to $510.3 million under the August 2023 Share Repurchase Program. On April 1, 2024, we repurchased 5,000,000 shares of our outstanding common stock from REH Company in a privately negotiated transaction under the August 2023 Share Repurchase Program and pursuant to the Stock Purchase Agreement, dated April 1, 2024 (the “April 2024 Stock Purchase Agreement”), between us and REH Company. The price paid under the April Stock Purchase Agreement was $59.22 per share resulting in an aggregate purchase price of $296.1 million. The purchase price was funded with cash on hand. As of May 7, 2024, we had repurchased $785.8 million under the August 2023 Share Repurchase Program. On May 7, 2024, our Board of Directors approved a new $1.0 billion share repurchase program (the “May 2024 Share Repurchase Program”), which replaced all existing share repurchase programs, including the approximately $214.2 million remaining under the August 2023 Share Repurchase Program. The May 2024 Share Repurchase Program authorizes us to repurchase common stock in the open market or through privately negotiated transactions. Privately negotiated repurchases from REH Company are also authorized under the May 2024 Share Repurchase Program, subject to REH Company’s interest in selling its shares and other limitations. The timing and amount of share repurchases, including those from REH Company, will depend on market conditions and corporate, tax, regulatory and other relevant considerations. In addition, we are authorized by our Board of Directors to repurchase shares in an amount sufficient to offset shares issued under our compensation programs. The May 2024 Share Repurchase Program may be discontinued at any time by our Board of Directors. The following table presents the total open market and privately negotiated purchases of shares under our share repurchase programs for the three months ended March 31, 2024 and 2023: Three Months Ended 2024 2023 Number of shares repurchased (1) 2,930,742 4,793,857 Cash paid for shares repurchased (in thousands) $ 166,128 $ 240,323 (1) During the three months ended March 31, 2024, 1,516,326 shares were repurchased for $85.0 million, pursuant to privately negotiated repurchases from REH Company. During the three months ended March 31, 2023, 1,969,279 shares were repurchased for $100.0 million pursuant to privately negotiated repurchases from REH Company. During the three months ended March 31, 2024 and 2023, we withheld 58,082 and 16,200 shares, respectively, of our common stock under the terms of stock-based compensation agreements to provide funds for the payment of payroll and income taxes due at the vesting of share-based awards. On May 8, 2024, our Board of Directors announced that it declared a regular quarterly dividend in the amount of $0.50 per share, payable on June 5, 2024 to holders of record of common stock on May 22, 2024.	Stockholders' Equity In September 2022, our Board of Directors approved a $1.0 billion share repurchase program (the “ September 2022 Share Repurchase Program”), which replaced all existing share repurchase programs at that time, authorizing us to repurchase common stock in the open market or through privately negotiated transactions. Privately negotiated repurchases from REH Company were also authorized under the September 2022 Share Repurchase Program, subject to REH Company’s interest in selling its shares and other limitations. As of August 15, 2023, we had repurchased $995.0 million under the September 2022 Share Repurchase Program. On August 15, 2023, our Board of Directors approved a new $1.0 billion share repurchase program (the “ August 2023 Share Repurchase Program”), which replaced all existing share repurchase programs, including the $5.0 million remaining authorization under the September 2022 Share Repurchase Program. The August 2023 Share Repurchase Program authorizes us to repurchase common stock in the open market or through privately negotiated transactions. Privately negotiated repurchases from REH Company are also authorized under the August 2023 Share Repurchase Program, subject to REH Company’s interest in selling its shares and other limitations. The timing and amount of share repurchases, including those from REH Company, will depend on market conditions and corporate, tax, regulatory and other relevant considerations. In addition, we are authorized by our Board of Directors to repurchase shares in an amount sufficient to offset shares issued under our compensation programs. The August 2023 Share Repurchase Program may be discontinued at any time by our Board of Directors. On January 3, 2024, we repurchased 454,380 shares of our outstanding common stock from REH Company in a privately negotiated transaction under the August 2023 Share Repurchase Program and pursuant to the Stock Purchase Agreement, dated January 3, 2024 (the “January Stock Purchase Agreement”), between us and REH Company. The price paid by us under the January Stock Purchase Agreement was $55.02 per share resulting in an aggregate purchase price of $25.0 million. The purchase price was funded with cash on hand. On February 8, 2024, we repurchased 1,061,946 shares of our outstanding common stock from REH Company in a privately negotiated transaction under the August 2023 Share Repurchase Program and pursuant to the Stock Purchase Agreement, dated February 8, 2024 (the “February Stock Purchase Agreement”), between us and REH Company. The price paid by us under the February Stock Purchase Agreement was $56.50 per share resulting in an aggregate purchase price of $60.0 million. The purchase price was funded with cash on hand. As of February 15, 2024, we had remaining authorization to repurchase up to $591.4 million under the August 2023 Share Repurchase Program. The following table presents total open market and privately negotiated purchases of shares under our share repurchase programs for the years ended December 31, 2023 and 2022. Years Ended December 31, 2023 2022 Number of shares repurchased (1) 18,779,880 25,716,042 Cash paid for shares repurchased (in thousands) $ 974,474 $ 1,313,006 (1) During the years ended December 31, 2023 and 2022, 15,515,302 and 14,407,274 shares, respectively, were repurchased for $810.6 million and $750.0 million, respectively, pursuant to privately negotiated repurchases from REH Company. On December 14, 2022, we agreed to repurchase an aggregate of 1,000,000 shares of our outstanding common stock from a registered broker for an aggregate purchase price of $48.6 million (the “December 2022 Repurchase”). The purchase price was funded with cash on hand. The shares repurchased are held as treasury stock. The December 2022 Repurchase was made in connection with the sale by REH Company of approximately 5,000,000 shares of common stock, inclusive of the 1,000,000 shares we repurchased, in an unregistered block trade permitted under applicable securities laws (such sale, the “Sale”). In connection with the Sale, REH Company agreed to customary “lock-up” restrictions that expired 60 days following the date of the Sale, subject to waiver by the broker and certain exceptions, including, but not limited to, privately negotiated sales or transfers of common stock to us from REH Company. The December 2022 Repurchase was made pursuant to separate authorization from our Board of Directors and not as part of the September 2022 Share Repurchase Program, and accordingly, did not reduce the remaining authorization thereunder. During the years ended December 31, 2023, 2022 and 2021, we withheld 332,741, 278,025, and 217,151 shares, respectively, of our common stock from certain employees in the amounts of $18.1 million, $16.5 million and $7.1 million, respectively. These withholdings were made under the terms of restricted stock unit and performance share unit agreements upon vesting, at which time, we concurrently made cash payments to fund payroll and income taxes on behalf of officers and employees who elected to have shares withheld from vested amounts to pay such taxes.

Other Comprehensive Income (Los

Other Comprehensive Income (Loss)	3 Months Ended	12 Months Ended
Other Comprehensive Income (Loss)	Mar. 31, 2024	Dec. 31, 2023
Other Comprehensive Income (Loss), before Tax [Abstract]
Other Comprehensive Income (Loss)	Other Comprehensive Income (Loss) The components and allocated tax effects of other comprehensive income (loss) are as follows: Before-Tax Tax Expense After-Tax (In thousands) Three Months Ended March 31, 2024 Net change in foreign currency translation adjustment $ (12,606) $ (2,643) $ (9,963) Net change in pension and other post-retirement benefit obligations (699) (169) (530) Other comprehensive loss attributable to HF Sinclair stockholders $ (13,305) $ (2,812) $ (10,493) Three Months Ended March 31, 2023 Net change in foreign currency translation adjustment $ 2,926 $ 614 $ 2,312 Net unrealized gain on hedging instruments 271 66 205 Net change in pension and other post-retirement benefit obligations (960) (233) (727) Other comprehensive income attributable to HF Sinclair stockholders $ 2,237 $ 447 $ 1,790 The following table presents the statements of income line item effects for reclassifications out of accumulated other comprehensive income (“AOCI”): AOCI Component Gain (Loss) Reclassified From AOCI Statement of Income Line Item Three Months Ended March 31, 2024 2023 (In thousands) Hedging instruments: Commodity price swaps $ (4,287) $ (1) Sales and other revenues (1,039) — Income tax benefit (3,248) (1) Net of tax Other post-retirement benefit obligations: Pension obligations (217) 45 Gain on sale of assets and other (53) 11 Income tax expense (benefit) (164) 34 Net of tax Post-retirement healthcare obligations 922 918 Gain on sale of assets and other 223 223 Income tax expense 699 695 Net of tax Retirement restoration plan (6) (3) Gain on sale of assets and other (1) (1) Income tax benefit (5) (2) Net of tax Total reclassifications for the period $ (2,718) $ 726 Accumulated other comprehensive loss in the equity section of our consolidated balance sheets includes: March 31, December 31, (In thousands) Foreign currency translation adjustment $ (32,988) $ (23,026) Unrealized loss on pension obligations 836 619 Unrealized gain on post-retirement benefit obligations 9,875 10,623 Accumulated other comprehensive loss $ (22,277) $ (11,784)	Other Comprehensive Income (Loss) The components and allocated tax effects of other comprehensive income (loss) are as fo llows: Before-Tax Tax Expense After-Tax (In thousands) Year Ended December 31, 2023 Net change in foreign currency translation adjustment $ 13,161 $ 2,760 $ 10,401 Net change in pension and other post-retirement benefit obligations 101 273 (172) Other comprehensive income attributable to HF Sinclair stockholders $ 13,262 $ 3,033 $ 10,229 Year Ended December 31, 2022 Net change in foreign currency translation adjustment $ (32,383) $ (6,817) $ (25,566) Net unrealized gain on hedging instruments 326 67 259 Net change in pension and other post-retirement benefit obligations 789 166 623 Other comprehensive loss attributable to HF Sinclair stockholders $ (31,268) $ (6,584) $ (24,684) Year Ended December 31, 2021 Net change in foreign currency translation adjustment $ (13,336) $ (2,793) $ (10,543) Net unrealized gain on hedging instruments 31 8 23 Net change in pension and other post-retirement benefit obligations (457) (186) (271) Other comprehensive loss attributable to HF Sinclair stockholders $ (13,762) $ (2,971) $ (10,791) The following table presents the statement of income line item effects for reclassifications out of accumulated other comprehensive income (“AOCI”): AOCI Component Gain (Loss) Reclassified From AOCI Income Statement Line Item Years Ended December 31, 2023 2022 2021 (In thousands) Hedging instruments: Commodity price swaps $ (3,236) $ (5,288) $ (19,239) Sales and other revenues — — 1,660 Operating expenses (3,236) (5,288) (17,579) (784) (1,282) (4,430) Income tax expense (benefit) (2,452) (4,006) (13,149) Net of tax Other post-retirement benefit obligations: Pension obligations (1,378) 208 407 Other, net (334) 50 103 Income tax expense (benefit) (1,044) 158 304 Net of tax Post-retirement healthcare obligations 3,859 3,440 3,328 Other, net 935 834 839 Income tax expense (benefit) 2,924 2,606 2,489 Net of tax Retirement restoration plan (11) (39) (39) Other, net (3) (9) (10) Income tax expense (benefit) (8) (30) (29) Net of tax Total reclassifications for the period $ (580) $ (1,272) $ (10,385) Accumulated other comprehensive loss in the equity section of our consolidated balance sheets includes: Years Ended December 31, 2023 2022 (In thousands) Foreign currency translation adjustment $ (23,026) $ (33,427) Unrealized gain (loss) on pension obligations 619 (2,661) Unrealized gain on post-retirement benefit obligations 10,623 14,075 Accumulated other comprehensive loss $ (11,784) $ (22,013)

Contingencies

Contingencies	3 Months Ended	12 Months Ended
Contingencies	Mar. 31, 2024	Dec. 31, 2023
Commitments and Contingencies Disclosure [Abstract]
Contingencies	Contingencies In the ordinary course of business, we may become party to legal, regulatory or administrative proceedings or governmental investigations, including environmental and other matters. Damages or penalties may be sought from us in some matters and certain matters may require years to resolve. While the outcome and impact of these proceedings and investigations on us cannot be predicted with certainty, based on the advice of counsel and information currently available to us, management believes that the resolution of these proceedings and investigations through settlement or adverse judgment will not either individually or in the aggregate have a material adverse effect on our financial condition, results of operations or cash flows. During 2017 and 2019, the EPA granted the Cheyenne, Wyoming refinery (the “Cheyenne Refinery”) and the refinery in Woods Cross, Utah (the “Woods Cross Refinery”) each a one-year small refinery exemption from the Renewable Fuel Standard program requirements for the 2016 and 2018, respectively, compliance years. As a result, the Cheyenne Refinery’s and Woods Cross Refinery’s gasoline and diesel production were not subject to the renewable volume obligation for the respective years. Upon each exemption granted, we increased our inventory of RINs and reduced our cost of products sold. On April 7, 2022, the EPA issued a decision reversing the grant of small refinery exemptions for our Woods Cross Refinery and Cheyenne Refinery for the 2018 compliance year. On June 3, 2022, the EPA issued a decision reversing the grant of small refinery exemptions for our Woods Cross Refinery and Cheyenne Refinery for the 2016 compliance year and denying small refinery exemption petitions for our Woods Cross Refinery and Cheyenne Refinery for the 2019 and 2020 compliance years. Certain of our subsidiaries are currently pursuing legal challenges to the EPA’s decisions to reverse its grant of small refinery exemptions for the 2016 and 2018 compliance years. The first lawsuit, filed against the EPA on May 6, 2022, and currently pending before the U.S. Court of Appeals for the DC Circuit, seeks to have the EPA’s reversal of our 2018 small refinery exemption petitions overturned. The second lawsuit, filed against the EPA on August 5, 2022, and currently pending before the U.S. Court of Appeals for the DC Circuit, seeks to have the EPA’s reversal of our 2016 small refinery exemption petitions overturned and to have the EPA’s denial of our 2019 and 2020 small refinery exemption petitions reversed. In addition, pursuant to the June 2022 and April 2022 decisions, respectively, the EPA established an alternative compliance demonstration to not impose obligations on small refineries that had exemptions reversed for the 2016 and 2018 compliance years. On June 24, 2022, Growth Energy filed two lawsuits in the U.S. Court of Appeals for the DC Circuit against the EPA, challenging the alternative compliance demonstration for the 2016 and 2018 compliance years. On July 25, 2022, certain of our subsidiaries intervened on behalf of the EPA to aid the defense of the EPA’s alternative compliance demonstration decision. It is too early to predict the outcome of these matters. We are unable to estimate the costs we may incur, if any, at this time.	Contingencies and Contractual Commitments We are a party to various litigation and legal proceedings which we believe, based on advice of counsel, will not either individually or in the aggregate have a materially adverse effect on our financial condition, results of operations or cash flows. During the year ended December 31, 2023, we recognized a gain of $15.0 million, which is reflected in our Refining segment, from the settlement of a preservation of property claim related to winter storm Uri that occurred in the first quarter of 2021. Additionally, during the year ended December 31, 2022, we recognized a gain of $15.2 million, which is reflected in our Corporate and Other segment, from the settlement of our business interruption claim Pursuant to the Business Combination Agreement, all pre-closing RINs obligations of REH Company’s subsidiaries (which are now subsidiaries of HF Sinclair as a result of the HFC Transactions) remained with REH Company. REH Company was required to transfer to HF Sinclair the number of each applicable type of RIN required for REH Company to demonstrate compliance for any pre-closing obligations it retained by the deadlines set forth in the Business Combination Agreement. If REH Company did not deliver all the required RINs by the applicable deadline, then, within five days following the delivery of an invoice therefor, REH Company was required to pay to HF Sinclair the amount of all out-of-pocket costs and expenses incurred by HF Sinclair to comply with REH Company’s pre-closing obligations prior to such deadline, including the price of any RINs purchased by HF Sinclair. In relation to thi s, 2,570,000 shares of HF Sinclair common stock, out of the purchase consideration paid to REH Company, were held in escrow to secure REH Company’s RINs credit obligations under Section 6.22 of the Business Combination Agreement and were released in January 2024 upon their satisfaction of the RINs credit obligation relating thereto. The 5,290,000 HEP common units that were also held in escrow to secure REH Company's RINs credit obligations were released to REH Company in April 2023 upon their satisfaction of the RINs credit obligations relating thereto. During 2017 and 2019, the EPA granted the Cheyenne Refinery and the refinery in Woods Cross, Utah (the “Woods Cross Refinery”) each a one-year small refinery exemption from the Renewable Fuel Standard (“RFS”) program requirements for the 2016 and 2018, respectively, compliance years. As a result, the Cheyenne Refinery’s and Woods Cross Refinery’s gasoline and diesel production are not subject to the Renewable Volume Obligation for the respective years. Upon each exemption granted, we increased our inventory of RINs and reduced our cost of products sold. On April 7, 2022, the EPA issued a decision reversing the grant of small refinery exemptions for our Woods Cross and Cheyenne refineries for the 2018 compliance year. On June 3, 2022, the EPA issued a decision reversing the grant of small refinery exemptions for our Woods Cross and Cheyenne refineries for the 2016 compliance year and denying small refinery exemption petitions for our Woods Cross and Cheyenne refineries for the 2019 and 2020 compliance years. Various subsidiaries of HollyFrontier are currently pursuing legal challenges to the EPA’s decisions to reverse its grant of small refinery exemptions for the 2016 and 2018 compliance years. The first lawsuit, filed against the EPA on May 6, 2022 and currently pending before the U.S. Court of Appeals for the DC Circuit, seeks to have the EPA’s reversal of our 2018 small refinery exemption petitions overturned. The second lawsuit, filed against the EPA on August 5, 2022 and currently pending before the U.S. Court of Appeals for the DC Circuit, seeks to have the EPA’s reversal of our 2016 small refinery exemption petitions overturned and to have the EPA’s denial of our 2019 and 2020 small refinery exemption petitions reversed. In addition, for both the 2016 and 2018 compliance years, pursuant to the June 2022 and April 2022 decisions, respectively, the EPA established an alternative compliance demonstration for small refineries pursuant to which the EPA is not imposing any obligations for the small refineries whose exemptions were reversed. On June 24, 2022, Growth Energy filed two lawsuits in the U.S. Court of Appeals for the DC Circuit against the EPA challenging the alternative compliance demonstration for the 2016 and 2018 compliance years. On July 25, 2022, various subsidiaries of HollyFrontier intervened on behalf of the EPA to aid the defense of the EPA’s alternative compliance demonstration decision. It is too early to predict the outcome of these matters. We are unable to estimate the costs we may incur, if any, at this time. We have been party to multiple proceedings before the Federal Energy Regulatory Commission (“FERC”) challenging the rates charged by SFPP, L.P. (“SFPP”) on its East Line pipeline facilities from El Paso, Texas to Phoenix, Arizona. In March 2018, FERC ruled that SFPP, as a master limited partnership, was prohibited from including an allowance for investor income taxes in the cost of service underlying its East Line rates. We reached a negotiated settlement with SFPP that provides for a payment to us of $51.5 million. FERC approved the settlement on December 31, 2020 subject to a rehearing period that resulted in a settlement effective date of February 2, 2021. Under the terms of the settlement agreement, SFPP made the $51.5 million payment to us on February 10, 2021 we recorded as “Gain on tariff settlement” on our consolidated statements of income for the year ended December 31, 2021. Contractual Commitments We have various long-term agreements (entered in the normal course of business) to purchase crude oil, natural gas, feedstocks and other resources to ensure we have adequate supplies to operate our refineries. The substantial majority of our purchase obligations are based on market prices or rates. These contracts expire i n 2024 thro ugh 2028. We also have long-term agreements with third parties for the transportation and storage of crude oil, natural gas and feedstocks to our refineries and for terminal and storage services that expire in 2024 through 2038. At December 31, 2023 , the minimum future transportation and storage fees under transportation agreements having terms in excess of one year are as follows: (In thousands) 2024 $ 237,534 2025 241,403 2026 203,316 2027 203,484 2028 207,742 Thereafter 1,079,956 Total $ 2,173,435 Transportation and storage costs incurred under these agreements totaled $200.5 million , $180.2 million and $160.5 million for the years ended December 31, 2023, 2022 and 2021, respectively.

Segment Information

Segment Information	3 Months Ended	12 Months Ended
Segment Information	Mar. 31, 2024	Dec. 31, 2023
Segment Reporting [Abstract]
Segment Information	Segment Information Our operations are organized into five reportable segments: Refining, Renewables, Marketing, Lubricants & Specialties and Midstream. Our operations that are not included in one of these five reportable segments are included in Corporate and Other. Intersegment transactions are eliminated in our consolidated financial statements and are included in Eliminations. Corporate and Other and Eliminations are aggregated and presented under the Corporate, Other and Eliminations column. The Refining segment represents the operations of our El Dorado, Tulsa, Navajo, Woods Cross, Puget Sound, Parco and Casper refineries and HF Sinclair Asphalt Company LLC (“Asphalt”). Refining activities involve the purchase and refining of crude oil and wholesale marketing of refined products, such as gasoline, diesel fuel and jet fuel. These petroleum products are primarily marketed in the Mid-Continent, Southwest and Rocky Mountains extending into the Pacific Northwest geographic regions of the United States. Asphalt operates various asphalt terminals in Arizona, New Mexico and Oklahoma. The Renewables segment represents the operations of our Cheyenne renewable diesel unit (“RDU”), the pre-treatment unit at our Artesia, New Mexico facility, the Artesia RDU, and the Sinclair RDU. The Marketing segment represents branded fuel sales to Sinclair branded sites in the United States and licensing fees for the use of the Sinclair brand at additional locations throughout the country. The Marketing segment also includes branded fuel sales to non-Sinclair branded sites from legacy HollyFrontier Corporation (“HollyFrontier”) agreements and revenues from other marketing activities. Our branded sites are located in several states across the United States with the highest concentration of the sites located in our West and Mid-Continent regions. The Lubricants & Specialties segment represents Petro-Canada Lubricants Inc.’s production operations, located in Mississauga, Ontario, which includes lubricant products such as base oils, white oils, specialty products and finished lubricants, and the operations of our Petro-Canada Lubricants business that includes the marketing of products to both retail and wholesale outlets through a global sales network with locations in Canada, the United States and Europe. Additionally, the Lubricants & Specialties segment includes specialty lubricant products produced at our Tulsa refineries that are marketed throughout North America and are distributed in Central and South America and the operations of Red Giant Oil Company LLC, one of the leading suppliers of locomotive engine oil in North America. Also, the Lubricants & Specialties segment includes Sonneborn, a producer of specialty hydrocarbon chemicals such as white oils, petrolatums and waxes with manufacturing facilities in the United States and Europe. The Midstream segment includes all of the operations of HEP, which owns and operates logistics and refinery assets consisting of petroleum product and crude oil pipelines, and terminals, tankage and loading rack facilities in the Mid-Continent, Southwest and Rocky Mountains geographic regions of the United States. The Midstream segment also includes 50% ownership interests in each of Osage Pipeline Company, LLC, the owner of a pipeline running from Cushing, Oklahoma to El Dorado, Kansas, Cheyenne Pipeline, LLC, the owner of a pipeline running from Fort Laramie, Wyoming to Cheyenne, Wyoming, and Cushing Connect, a 25.12% ownership interest in Saddle Butte Pipeline III, LLC, the owner of a pipeline running from the Powder River Basin to Casper, Wyoming, and a 49.995% ownership interest in Pioneer Investments Corp., the owner of a pipeline running from Sinclair, Wyoming to the North Salt Lake City, Utah Terminal. Revenues from the Midstream segment are earned through transactions with unaffiliated parties for pipeline transportation, rental and terminalling operations as well as revenues relating to pipeline transportation services provided for our refining operations. Beginning in the first quarter of 2024, our Refining segment acquired from our Midstream segment the refinery processing units at our El Dorado and Woods Cross refineries. Additionally, we amended an intercompany agreement between certain of our subsidiaries within the Refining, Lubricants & Specialties and Midstream segments. As a result, we have revised our Refining, Lubricants & Specialties and Midstream segment information for the periods presented. See Part II, Item 5 “Other Information” of this Quarterly Report on Form 10-Q for additional information on the segment recast. The accounting policies for our segments are the same as those described in the summary of significant accounting policies in our Annual Report on Form 10-K for the year ended December 31, 2023. Refining Renewables Marketing Lubricants & Specialties Midstream Corporate, Other Consolidated (In thousands) Three Months Ended March 31, 2024 Sales and other revenues: Revenues from external customers $ 5,373,025 $ 179,669 $ 775,807 $ 675,545 $ 23,099 $ — $ 7,027,145 Intersegment revenues and other (1) 831,220 59,890 — 2,442 131,916 (1,025,468) — $ 6,204,245 $ 239,559 $ 775,807 $ 677,987 $ 155,015 $ (1,025,468) $ 7,027,145 Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment) $ 5,474,522 $ 230,273 $ 752,530 $ 492,846 $ — $ (1,023,671) $ 5,926,500 Lower of cost or market inventory valuation adjustment $ (220,558) $ 1,188 $ — $ — $ — $ — $ (219,370) Operating expenses $ 472,086 $ 26,461 $ — $ 64,000 $ 45,518 $ (953) $ 607,112 Selling, general and administrative expenses $ 48,717 $ 1,402 $ 7,756 $ 34,568 $ 3,929 $ 7,002 $ 103,374 Depreciation and amortization $ 117,370 $ 20,272 $ 6,303 $ 22,511 $ 20,120 $ 12,153 $ 198,729 Income (loss) from operations $ 312,108 $ (40,037) $ 9,218 $ 64,062 $ 85,448 $ (19,999) $ 410,800 Earnings (loss) of equity method investments $ — $ — $ — $ — $ 7,388 $ (42) $ 7,346 Capital expenditures $ 55,025 $ 2,650 $ 7,531 $ 5,311 $ 8,106 $ 10,485 $ 89,108 Three Months Ended March 31, 2023 Sales and other revenues: Revenues from external customers $ 5,665,214 $ 202,413 $ 937,385 $ 733,714 $ 26,416 $ — $ 7,565,142 Intersegment revenues and other (1) 1,053,401 95,603 — 5,796 109,516 (1,264,316) — $ 6,718,615 $ 298,016 $ 937,385 $ 739,510 $ 135,932 $ (1,264,316) $ 7,565,142 Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment) $ 5,641,131 $ 262,738 $ 924,049 $ 538,860 $ — $ (1,262,721) $ 6,104,057 Lower of cost or market inventory valuation adjustment $ — $ 47,597 $ — $ — $ — $ — $ 47,597 Operating expenses $ 501,759 $ 31,371 $ — $ 63,593 $ 41,679 $ 981 $ 639,383 Selling, general and administrative expenses $ 39,078 $ 915 $ 6,963 $ 39,264 $ 4,635 $ 5,058 $ 95,913 Depreciation and amortization $ 100,083 $ 19,974 $ 5,871 $ 19,368 $ 19,762 $ 8,925 $ 173,983 Income (loss) from operations $ 436,564 $ (64,579) $ 502 $ 78,425 $ 69,856 $ (16,559) $ 504,209 Earnings of equity method investments $ — $ — $ — $ — $ 3,882 $ — $ 3,882 Capital expenditures $ 67,774 $ 4,844 $ 5,255 $ 8,649 $ 7,614 $ 5,933 $ 100,069 (1) Includes income earned by certain of our subsidiaries in the Midstream segment related to intercompany transportation agreements with certain of our subsidiaries in the Refining and Lubricants & Specialties segments that represent leases. These transactions eliminate in consolidation.	Segment Information Our operations are organized into five reportable segments: Refining, Renewables, Marketing, Lubricants & Specialties and Midstream. Our operations that are not included in one of these five reportable segments are included in Corporate and Other. Intersegment transactions are eliminated on our consolidated financial statements and are included in Eliminations. Corporate and Other and Eliminations are aggregated and presented under the Corporate, Other and Eliminations column. As a result of the Sinclair Transactions that closed on March 14, 2022, the operations of the Acquired Sinclair Businesses are reported in the Refining, Renewables, Marketing and Midstream segments. The Refining segment represents the operations of our El Dorado, Tulsa, Navajo and Woods Cross refineries and HF Sinclair Asphalt Company LLC (“Asphalt”). Also, effective with our acquisition that closed on November 1, 2021, the Refining segment includes our Puget Sound Refinery, and effective with our acquisition that closed on March 14, 2022, includes our Parco and Casper refineries. Refining activities involve the purchase and refining of crude oil and wholesale marketing of refined products, such as gasoline, diesel fuel and jet fuel. These petroleum products are primarily marketed in the Mid-Continent, Southwest and Rocky Mountains extending into the Pacific Northwest geographic regions of the United States. Asphalt operates various asphalt terminals in Arizona, New Mexico and Oklahoma. The Renewables segment represents the operations of our Cheyenne renewable diesel unit (“RDU”), which was mechanically complete in the fourth quarter of 2021 and operational in the first quarter of 2022, the pre-treatment unit at our Artesia, New Mexico facility, which was completed and operational in the first quarter of 2022 and the Artesia RDU, which was completed and operational in the second quarter of 2022. Also, effective with the Sinclair Transactions that closed on March 14, 2022, the Renewables segment includes the Sinclair RDU. Effective with the Sinclair Transactions that closed on March 14, 2022, the Marketing segment represents branded fuel sales to Sinclair branded sites in the United States and licensing fees for the use of the Sinclair brand at additional locations throughout the country. The Marketing segment also includes branded fuel sales to non-Sinclair branded sites from legacy HollyFrontier agreements and revenues from other marketing activities. Our branded sites are located in several states across the United States with the highest concentration of the sites located in our West and Mid-Continent regions. The Lubricants & Specialties segment represents PCLI production operations, located in Mississauga, Ontario, that includes lubricant products such as base oils, white oils, specialty products and finished lubricants, and the operations of our Petro-Canada Lubricants business that includes the marketing of products to both retail and wholesale outlets through a global sales network with locations in Canada, the United States and Europe. Additionally, the Lubricants & Specialties segment includes specialty lubricant products produced at our Tulsa refineries that are marketed throughout North America and are distributed in Central and South America and the operations of Red Giant Oil Company LLC, one of the largest suppliers of locomotive engine oil in North America. Also, the Lubricants & Specialties segment includes Sonneborn, a producer of specialty hydrocarbon chemicals such as white oils, petrolatums and waxes with manufacturing facilities in the United States and Europe. The Midstream segment includes all of the operations of HEP, which owns and operates logistics and refinery assets consisting of petroleum product and crude oil pipelines, and terminals, tankage and loading rack facilities in the Mid-Continent, Southwest and Rocky Mountains geographic regions of the United States. The Midstream segment also includes 50% ownership interests in each of the Osage Pipeline, the Cheyenne Pipeline and Cushing Connect, and a 25.12% ownership interest in the Saddle Butte Pipeline and a 49.995% ownership interest in the Pioneer Pipeline. Revenues from the Midstream segment are earned through transactions with unaffiliated parties for pipeline transportation, rental and terminalling operations as well as revenues relating to pipeline transportation services provided for our refining operations. The accounting policies for our segments are the same as those described in the summary of significant accounting policies (see Note 1). The following is a summary of the financial information of our reportable segments reconciled to the amounts reported in the consolidated financial statements. Refining Renewables Marketing Lubricants & Specialties Midstream Corporate, Other and Eliminations Consolidated (In thousands) Year Ended December 31, 2023 Sales and other revenues: Revenues from external customers $ 24,156,278 $ 781,309 $ 4,146,292 $ 2,762,767 $ 117,749 $ — $ 31,964,395 Intersegment revenues and other (1) 4,516,326 407,681 — 12,566 466,398 (5,402,971) — $ 28,672,604 $ 1,188,990 $ 4,146,292 $ 2,775,333 $ 584,147 $ (5,402,971) $ 31,964,395 Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment) $ 24,042,807 $ 1,080,919 $ 4,050,759 $ 2,009,281 $ — $ (5,399,317) $ 25,784,449 Lower of cost or market inventory valuation adjustment $ 220,558 $ 49,861 $ — $ — $ — $ — $ 270,419 Operating expenses $ 1,879,656 $ 109,056 $ — $ 258,578 $ 188,625 $ 2,233 $ 2,438,148 Selling, general and administrative expenses $ 199,547 $ 5,117 $ 34,413 $ 164,311 $ 26,453 $ 68,399 $ 498,240 Depreciation and amortization $ 460,962 $ 77,100 $ 24,599 $ 84,928 $ 82,158 $ 40,826 $ 770,573 Income (loss) from operations $ 1,869,074 $ (133,063) $ 36,521 $ 258,235 $ 286,911 $ (115,112) $ 2,202,566 Earnings of equity method investments $ — $ — $ — $ — $ 17,531 $ (162) $ 17,369 Capital expenditures $ 223,495 $ 18,154 $ 27,630 $ 37,431 $ 31,692 $ 47,011 $ 385,413 Refining Renewables Marketing Lubricants & Specialties Midstream Corporate, Other and Eliminations Consolidated (In thousands) Year Ended December 31, 2022 Sales and other revenues: Revenues from external customers $ 30,379,696 $ 654,893 $ 3,911,922 $ 3,149,128 $ 109,200 $ — $ 38,204,839 Intersegment revenues and other (1) 4,033,213 360,606 — 9,472 430,547 (4,833,838) — $ 34,412,909 $ 1,015,499 $ 3,911,922 $ 3,158,600 $ 539,747 $ (4,833,838) $ 38,204,839 Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment) $ 28,350,823 $ 974,167 $ 3,845,625 $ 2,339,031 $ — $ (4,829,633) $ 30,680,013 Lower of cost or market inventory valuation adjustment $ — $ 52,412 — $ — $ — $ — $ 52,412 Operating expenses $ 1,761,445 $ 111,974 — $ 277,522 $ 170,891 $ 13,061 $ 2,334,893 Selling, general and administrative expenses $ 146,660 $ 3,769 $ 2,954 $ 168,207 $ 17,003 $ 87,892 $ 426,485 Depreciation and amortization $ 397,069 $ 52,621 $ 17,819 $ 81,281 $ 76,768 $ 31,229 $ 656,787 Income (loss) from operations $ 3,756,912 $ (179,444) $ 45,524 $ 292,559 $ 275,085 $ (136,387) $ 4,054,249 Loss of equity method investments $ — $ — $ — $ — $ (260) $ — $ (260) Capital expenditures $ 168,173 $ 225,274 $ 9,275 $ 34,887 $ 33,071 $ 53,327 $ 524,007 Refining Renewables Lubricants & Specialties Midstream Corporate, Other and Eliminations Consolidated (In thousands) Year Ended December 31, 2021 Sales and other revenues: Revenues from external customers $ 15,734,870 $ — $ 2,550,624 $ 103,646 $ 2 $ 18,389,142 Intersegment revenues and other (1) 623,688 — 9,988 327,021 (960,697) — $ 16,358,558 $ — $ 2,560,612 $ 430,667 $ (960,695) $ 18,389,142 Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment) $ 14,691,246 $ — $ 1,821,677 $ — $ (945,871) $ 15,567,052 Lower of cost or market inventory valuation adjustment $ (318,353) $ 8,739 $ — $ — $ (509) $ (310,123) Operating expenses $ 1,038,300 $ 55,353 $ 252,456 $ 133,530 $ 37,839 $ 1,517,478 Selling, general and administrative expenses $ 127,563 $ — $ 170,155 $ 12,637 $ 51,655 $ 362,010 Depreciation and amortization $ 325,845 $ 1,672 $ 77,601 $ 73,046 $ 25,375 $ 503,539 Income (loss) from operations $ 493,957 $ (65,764) $ 238,723 $ 211,454 $ (129,184) $ 749,186 Earnings of equity method investments $ — $ — $ — $ 12,432 $ — $ 12,432 Capital expenditures $ 162,670 $ 510,836 $ 30,878 $ 86,097 $ 22,928 $ 813,409 (1) Includes income earned by certain of our subsidiaries in the Midstream segment related to intercompany transportation agreements with certain of our subsidiaries in the Refining and Lubricants & Specialties segments that represent leases. These transactions eliminate in consolidation.

Acquisitions

Acquisitions	12 Months Ended
Acquisitions	Dec. 31, 2023
Business Combination and Asset Acquisition [Abstract]
Acquisitions	Acquisitions On March 14, 2022 (the “Closing Date”), HollyFrontier and HEP announced the establishment of HF Sinclair as the new parent holding company of HollyFrontier and HEP and their subsidiaries, and the completion of their respective acquisitions of Sinclair Oil Corporation (now known as Sinclair Oil LLC) and Sinclair Transportation Company LLC (“STC”) from The Sinclair Companies (now known as REH Company and referred to herein as “REH Company”). On the Closing Date, pursuant to that certain Business Combination Agreement, dated as of August 2, 2021 (as amended on March 14, 2022, the “Business Combination Agreement”), by and among HollyFrontier, HF Sinclair, Hippo Merger Sub, Inc., a wholly owned subsidiary of HF Sinclair (“Parent Merger Sub”), REH Company, and Hippo Holding LLC (now known as Sinclair Holding LLC), a wholly owned subsidiary of REH Company (the “Target Company”), HF Sinclair completed its previously announced acquisition of the Target Company by effecting (a) a holding company merger in accordance with Section 251(g) of the Delaware General Corporation Law whereby HollyFrontier merged with and into Parent Merger Sub, with HollyFrontier surviving such merger as a direct wholly owned subsidiary of HF Sinclair (the “HFC Merger”) and (b) immediately following the HFC Merger, a contribution whereby REH Company contributed all of the equity interests of the Target Company to HF Sinclair in exchange for shares of HF Sinclair, resulting in the Target Company becoming a direct wholly owned subsidiary of HF Sinclair (the “HFC Transactions”). In connection with the closing of the HFC Transactions, HF Sinclair issued 60,230,036 shares of HF Sinclair common stock, par value $0.01 per share, to REH Company, representing 27% of the pro forma equity of HF Sinclair with a value of approximately $2,149 million based on HollyFrontier’s fully diluted shares of common stock outstanding and closing stock price on March 11, 2022. Pursuant to the Business Combination Agreement, REH Company made a $77.5 million cash payment to HF Sinclair, inclusive of final working capital adjustments, which reduced the aggregate transaction value to approximately $2,072 million. Of the 60,230,036 shares of HF Sinclair common stock, 2,570,000 shares were held in escrow to secure REH Company’s RINs credit obligations under Section 6.22 of the Business Combination Agreement. As of December 31, 2023, REH Company had satisfied their RINs credit obligations to HF Sinclair and the corresponding shares were released from escrow in January 2024. Additionally, on the Closing Date, and immediately prior to the consummation of the HFC Transactions, HEP completed its acquisition of STC, REH Company’s integrated crude and refined products midstream business, and issued 21,000,000 HEP common units and paid cash consideration of $329.0 million, inclusive of final working capital adjustments, to REH Company in exchange for all the outstanding equity interests of STC (the “HEP Transaction” and together with the HFC Transactions, the “Sinclair Transactions”). Of these 21,000,000 HEP common units, 5,290,000 units were held in escrow and were released to REH Company in April 2023 upon their satisfaction of the corresponding RINs credit obligations to HF Sinclair under Section 6.22 of the Business Combination Agreement. HollyFrontier’s (now HF Sinclair's) senior management team continues to operate the combined company. Pursuant to that certain stockholders agreement (the “Stockholders Agreement”) by and among HF Sinclair, REH Company and the stockholders of REH Company (together with REH Company and each of their permitted transferees, the “REH Parties”), REH Company was granted the right to nominate, and has nominated, two directors to our Board of Directors at the Closing Date who continued to serve on our Board of Directors as of December 31, 2023. The REH Company stockholders also agreed to certain customary lock up (which expired in June 2023), voting and standstill restrictions, as well as customary registration rights, for the HF Sinclair common stock issued to the stockholders of REH Company. HF Sinclair is headquartered in Dallas, Texas, with combined business offices in Salt Lake City, Utah. Under the terms of the Business Combination Agreement, HF Sinclair acquired REH Company’s refining, branded marketing, renewables, and midstream businesses. At the time of closing, the branded marketing business supplied high-quality fuels to more than 1,300 Sinclair branded stations and licensed the use of the Sinclair brand at more than 300 additional locations throughout the United States. The renewables business includes the operation of a renewable diesel unit located in Sinclair, Wyoming. The refining business includes two Rocky Mountains-based refineries located in Casper, Wyoming and Sinclair, Wyoming. Under the terms of the Contribution Agreement, HEP acquired STC, REH Company’s integrated crude and refined products pipelines and terminal assets, including approximately 1,200 miles of integrated crude and refined product pipeline supporting the Sinclair refineries and third parties, eight product terminals and two crude terminals with approximately 4.5 million barrels of operated storage. In addition, HEP acquired STC’s interests in three pipeline joint ventures for crude gathering and product offtake including: Saddle Butte Pipeline III, LLC (at the time of closing, a 25.06%, and currently, a 25.12% non-operated interest); Pioneer Investments Corp. (49.995% non-operated interest); and UNEV Pipeline (the 25% non-operated interest not already owned by HEP, resulting in UNEV Pipeline, LLC (“UNEV”) becoming a wholly owned subsidiary of HEP). The addition of the Acquired Sinclair Businesses to the HollyFrontier business created a combined company with increased scale and ability to diversify and is expected to drive growth through the expanded refining and renewables business. In addition, the HFC Transactions added an integrated branded wholesale distribution network to our business. The Sinclair Transactions were accounted for as a business combination using the acquisition method of accounting, with the assets acquired and liabilities assumed at their respective acquisition date fair values at the effective date, with the excess consideration recorded as goodwill. The following tables present the purchase consideration and final purchase price allocation of the assets acquired and liabilities assumed on March 14, 2022: Purchase Consideration (in thousands except for per share amounts) Shares of HF Sinclair common stock issued 60,230 Closing price per share of HFC common stock (1) $ 35.68 Purchase consideration paid in HF Sinclair common stock 2,149,008 Shares of HEP common units issued to REH Company 21,000 Closing price per share of HEP common units (2) $ 16.62 Purchase consideration paid in HEP common units 349,020 Total equity consideration 2,498,028 Cash consideration paid by HEP 328,955 Cash consideration received by HF Sinclair (77,507) Total cash consideration 251,448 Total purchase consideration $ 2,749,476 (1) Based on the HollyFrontier closing stock price on March 11, 2022. (2) Based on the HEP closing unit price on March 11, 2022. (In thousands) Assets Acquired Accounts receivable $ 467,530 Inventories: Crude oil and refined products 906,461 Inventories: Materials, supplies and other 39,350 Properties, plants and equipment 1,242,549 Operating lease right-of-use assets 4,585 Other assets: Intangibles and other 495,621 Total assets acquired $ 3,156,096 Liabilities Assumed Accounts payable $ 564,385 Operating lease liabilities 1,030 Accrued liabilities 84,298 Noncurrent operating lease liabilities 3,554 Deferred income taxes 351,189 Other long-term liabilities 88,098 Total liabilities assumed $ 1,092,554 Net assets acquired $ 2,063,542 Goodwill $ 685,934 The final purchase price allocation resulted in the recognition of $685.9 million in goodwill. Our Refining, Renewables, Marketing and Midstream segments recognized $244.0 million, $159.0 million, $163.8 million and $119.1 million of goodwill, respectively. The goodwill recognized was primarily attributable to operating and administrative synergies and net deferred tax liabilities arising from the differences between the estimated fair values of assets and liabilities and the tax basis of these assets and liabilities. There are qualitative assumptions of long-term factors that this acquisition creates for our stockholders, including increased scale and diversification that is expected to drive growth through the expanded refining and renewables businesses and the addition of an integrated branded wholesale distribution network. This goodwill was not deductible for income tax purposes. The fair value measurements for properties, plants and equipment were based on significant inputs that are not observable in the market and, therefore, represent Level 3 measurements. The fair value of properties, plants and equipment was based on the combination of the cost and market approaches. Key assumptions in the cost approach include determining the replacement cost by evaluating recent published data and adjusting replacement cost for physical deterioration, functional, and economic obsolescence. We used the market approach to measure the value of certain assets through an analysis of recent sales or offerings of comparable properties. The fair value of crude oil and refined products inventory was based on market prices as of the acquisition date. Intangibles include the Sinclair trade name, fuel agreements and customer relationships totaling $221.4 million that are being amortized on a straight-line basis over a range of four The fair value of equity method investments totaled $234.3 million and was based on a combination of valuation methods including discounted cash flows and the guideline public company method. Accrued liabilities included $70.6 million of RINs credit obligations, including 2022 obligations through the Closing Date, which were valued based on market prices for RINs at the effective date, a Level 2 input. REH Company is financially responsible for satisfaction of RINs credit obligations for all periods prior to the closing. This receivable totaled $68.4 million and was valued based on market prices for RINs at the effective date. During the year ended December 31, 2023, we purchased RINs for an aggregate amount of $36.0 million, on behalf of REH Company from third parties at applicable market prices in connection with our provision of services to REH Company under the transition services agreement that we and REH Company entered into at the closing of the Sinclair Transactions. We acted as an agent in these RINs transactions and did not recognize sales or cost of products sold as a result. During the year ended December 31, 2023, we recognized sales of $21.2 million related to the sale of RINs to REH Company based on applicable market prices. All other fair values discussed above were based on significant inputs that are not observable in the market and, therefore, represent Level 3 measurements. The fair values of all other current receivable and payables were equivalent to their carrying values due to their short-term nature. Our consolidated financial and operating results reflect the Acquired Sinclair Businesses operations beginning March 14, 2022. Our results of operations included revenue and income from operations of $9,835.0 million and $865.1 million, respectively, for the period from March 14, 2022 through December 31, 2022 related to the Acquired Sinclair Businesses operations. During the years ended December 31, 2023 and 2022, we incurred $15.8 million and $52.9 million, respectively, in incremental direct acquisition and integration costs that principally relate to legal, advisory and other professional fees and are presented as selling, general and administrative expenses in our consolidated statements of income. Puget Sound Refinery On May 4, 2021, HollyFrontier Puget Sound Refining LLC (now known as HF Sinclair Puget Sound Refining LLC), a wholly owned subsidiary of HollyFrontier, entered into a sale and purchase agreement with Shell to acquire the Puget Sound Refinery. The acquisition closed on November 1, 2021 for aggregate cash consideration of $624.3 million, which consists of a base cash purchase price of $350.0 million, hydrocarbon inventory of $277.9 million and other closing adjustments and accrued liabilities of $3.6 million (the “Puget Sound Acquisition”). This transaction was accounted for as a business combination, using the acquisition method, with the aggregate cash consideration allocated to the acquisition date fair value of assets and liabilities acquired. In connection with the Puget Sound Acquisition, we incurred $12.2 million of acquisition and integration costs during the year ended December 31, 2021, which are included in selling, general and administrative expenses on the consolidated statements of income. Our consolidated financial and operating results reflect the Puget Sound Refinery operations beginning November 1, 2021. Our results of operations include revenue and loss from operations of $603.1 million and $8.3 million, respectively, for the period from November 1, 2021 through December 31, 2021 related to these operations.

Leases

Leases	12 Months Ended
Leases	Dec. 31, 2023
Leases [Abstract]
Leases	Leases Lessee We have operating and finance leases for land, buildings, pipelines, storage tanks, transportation and other equipment for our operations. Our leases have remaining terms of one to 56 years, some of which include options to extend the leases for up to 10 years. Certain of our leases for pipeline assets include provisions for variable payments which are based on a measure of throughput and also contain a provision for the lessor to adjust the rate per barrel periodically over the life of the lease. These variable costs are not included in the initial measurement of ROU assets and lease liabilities. The following table presents the amounts and balance sheet locations of our operating and financing leases recorded on our consolidated balance sheets. December 31, 2023 2022 (In thousands) Operating leases: Operating lease right-of-use assets $ 348,006 $ 351,068 Operating lease liabilities 106,973 109,926 Noncurrent operating lease liabilities 249,479 254,215 Total operating lease liabilities $ 356,452 $ 364,141 Finance leases: Properties, plants and equipment, at cost $ 108,746 $ 81,454 Accumulated amortization (25,271) (21,434) Properties, plants and equipment, net $ 83,475 $ 60,020 Accrued liabilities $ 10,842 $ 10,722 Other long-term liabilities 74,860 50,361 Total finance lease liabilities $ 85,702 $ 61,083 Supplemental balance sheet information related to our leases was as follows: December 31, 2023 2022 Weighted average remaining lease term (in years) Operating leases 7.9 7.2 Finance leases 8.7 7.8 Weighted average discount rate Operating leases 5.0 % 4.2 % Finance leases 5.8 % 4.2 % The components of lease expense were as follows: Years Ended December 31, 2023 2022 2021 (In thousands) Operating lease expense $ 120,552 $ 116,769 $ 117,292 Finance lease expense: Amortization of right-of-use assets 13,007 13,003 4,295 Interest on lease liabilities 3,156 2,593 733 Variable lease cost 12,968 4,448 3,645 Total lease expense $ 149,683 $ 136,813 $ 125,965 Supplemental cash flow information related to leases was as follows: Years Ended December 31, 2023 2022 2021 (In thousands) Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 127,923 $ 126,048 $ 129,577 Operating cash flows from finance leases $ 3,156 $ 2,593 $ 733 Financing cash flows from finance leases $ 11,923 $ 11,713 $ 3,990 Right-of-use assets obtained in exchange for lease obligations: Operating leases $ 103,352 $ 61,403 $ 147,718 Finance leases $ 38,061 $ 6,149 $ 64,334 As of December 31, 2023, minimum future lease payments of our operating and finance lease obligations were as follows: Operating Finance (In thousands) 2024 $ 118,006 $ 15,375 2025 65,436 13,650 2026 50,145 12,537 2027 31,644 11,442 2028 24,398 10,766 Thereafter 163,651 46,869 Future minimum lease payments 453,280 110,639 Less: imputed interest 96,828 24,937 Total lease obligations 356,452 85,702 Less: current obligations 106,973 10,842 Long-term lease obligations $ 249,479 $ 74,860 As of December 31, 2023, we entered into certain leases that have not yet commenced. Such leases include a 15-year lease for a manufacturing and distribution facility, with estimated future undiscounted lease payments of $62.8 million, expected to commence in the first quarter of 2024. Lessor Our consolidated statements of income reflect lease revenue recognized by our midstream operations for contracts with third parties in which we are the lessor. Substantially all of the assets supporting contracts meeting the definition of a lease have long useful lives, and we believe these assets will continue to have value when the current agreements expire due to our risk management strategy for protecting the residual fair value of the underlying assets by performing ongoing maintenance during the lease term. Lease income recognized was as follows: Years Ended December 31, 2023 2022 2021 (In thousands) Operating lease revenues $ 16,879 $ 14,346 $ 15,281 Sales-type lease interest income $ 1,634 $ 2,515 $ 2,545 Lease revenues relating to variable lease payments not included in measurement of the sales-type lease receivable $ 1,325 $ 1,782 $ 2,162 For our sales-type leases, we included customer obligations related to minimum volume requirements in guaranteed minimum lease payments. Portions of our minimum guaranteed pipeline tariffs for assets subject to sales-type lease accounting are recorded as interest income with the remaining amounts recorded as a reduction in net investment in leases. We recognized any billings for throughput volumes in excess of minimum volume requirements as variable lease payments, and these variable lease payments were recorded in lease revenues. Annual minimum undiscounted lease payments in which we are a lessor to third-party contracts as of December 31, 2023 were as follows: Operating Sales-type (In thousands) 2024 $ 12,994 $ 2,170 2025 3,441 2,170 2026 — 2,170 2027 — 2,170 2028 — 2,170 Thereafter — 13,560 Total lease payment receipts $ 16,435 24,410 Less: imputed interest (15,945) 8,465 Unguaranteed residual assets at end of leases 25,180 Net investment in leases $ 33,645 Net investment in sales-type leases recorded on our consolidated balance sheets was composed of the following: December 31, 2023 December 31, 2022 (In thousands) Lease receivables $ 18,830 $ 23,797 Unguaranteed residual assets 14,815 10,383 Net investment in leases $ 33,645 $ 34,180
Leases	Leases Lessee We have operating and finance leases for land, buildings, pipelines, storage tanks, transportation and other equipment for our operations. Our leases have remaining terms of one to 56 years, some of which include options to extend the leases for up to 10 years. Certain of our leases for pipeline assets include provisions for variable payments which are based on a measure of throughput and also contain a provision for the lessor to adjust the rate per barrel periodically over the life of the lease. These variable costs are not included in the initial measurement of ROU assets and lease liabilities. The following table presents the amounts and balance sheet locations of our operating and financing leases recorded on our consolidated balance sheets. December 31, 2023 2022 (In thousands) Operating leases: Operating lease right-of-use assets $ 348,006 $ 351,068 Operating lease liabilities 106,973 109,926 Noncurrent operating lease liabilities 249,479 254,215 Total operating lease liabilities $ 356,452 $ 364,141 Finance leases: Properties, plants and equipment, at cost $ 108,746 $ 81,454 Accumulated amortization (25,271) (21,434) Properties, plants and equipment, net $ 83,475 $ 60,020 Accrued liabilities $ 10,842 $ 10,722 Other long-term liabilities 74,860 50,361 Total finance lease liabilities $ 85,702 $ 61,083 Supplemental balance sheet information related to our leases was as follows: December 31, 2023 2022 Weighted average remaining lease term (in years) Operating leases 7.9 7.2 Finance leases 8.7 7.8 Weighted average discount rate Operating leases 5.0 % 4.2 % Finance leases 5.8 % 4.2 % The components of lease expense were as follows: Years Ended December 31, 2023 2022 2021 (In thousands) Operating lease expense $ 120,552 $ 116,769 $ 117,292 Finance lease expense: Amortization of right-of-use assets 13,007 13,003 4,295 Interest on lease liabilities 3,156 2,593 733 Variable lease cost 12,968 4,448 3,645 Total lease expense $ 149,683 $ 136,813 $ 125,965 Supplemental cash flow information related to leases was as follows: Years Ended December 31, 2023 2022 2021 (In thousands) Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 127,923 $ 126,048 $ 129,577 Operating cash flows from finance leases $ 3,156 $ 2,593 $ 733 Financing cash flows from finance leases $ 11,923 $ 11,713 $ 3,990 Right-of-use assets obtained in exchange for lease obligations: Operating leases $ 103,352 $ 61,403 $ 147,718 Finance leases $ 38,061 $ 6,149 $ 64,334 As of December 31, 2023, minimum future lease payments of our operating and finance lease obligations were as follows: Operating Finance (In thousands) 2024 $ 118,006 $ 15,375 2025 65,436 13,650 2026 50,145 12,537 2027 31,644 11,442 2028 24,398 10,766 Thereafter 163,651 46,869 Future minimum lease payments 453,280 110,639 Less: imputed interest 96,828 24,937 Total lease obligations 356,452 85,702 Less: current obligations 106,973 10,842 Long-term lease obligations $ 249,479 $ 74,860 As of December 31, 2023, we entered into certain leases that have not yet commenced. Such leases include a 15-year lease for a manufacturing and distribution facility, with estimated future undiscounted lease payments of $62.8 million, expected to commence in the first quarter of 2024. Lessor Our consolidated statements of income reflect lease revenue recognized by our midstream operations for contracts with third parties in which we are the lessor. Substantially all of the assets supporting contracts meeting the definition of a lease have long useful lives, and we believe these assets will continue to have value when the current agreements expire due to our risk management strategy for protecting the residual fair value of the underlying assets by performing ongoing maintenance during the lease term. Lease income recognized was as follows: Years Ended December 31, 2023 2022 2021 (In thousands) Operating lease revenues $ 16,879 $ 14,346 $ 15,281 Sales-type lease interest income $ 1,634 $ 2,515 $ 2,545 Lease revenues relating to variable lease payments not included in measurement of the sales-type lease receivable $ 1,325 $ 1,782 $ 2,162 For our sales-type leases, we included customer obligations related to minimum volume requirements in guaranteed minimum lease payments. Portions of our minimum guaranteed pipeline tariffs for assets subject to sales-type lease accounting are recorded as interest income with the remaining amounts recorded as a reduction in net investment in leases. We recognized any billings for throughput volumes in excess of minimum volume requirements as variable lease payments, and these variable lease payments were recorded in lease revenues. Annual minimum undiscounted lease payments in which we are a lessor to third-party contracts as of December 31, 2023 were as follows: Operating Sales-type (In thousands) 2024 $ 12,994 $ 2,170 2025 3,441 2,170 2026 — 2,170 2027 — 2,170 2028 — 2,170 Thereafter — 13,560 Total lease payment receipts $ 16,435 24,410 Less: imputed interest (15,945) 8,465 Unguaranteed residual assets at end of leases 25,180 Net investment in leases $ 33,645 Net investment in sales-type leases recorded on our consolidated balance sheets was composed of the following: December 31, 2023 December 31, 2022 (In thousands) Lease receivables $ 18,830 $ 23,797 Unguaranteed residual assets 14,815 10,383 Net investment in leases $ 33,645 $ 34,180
Leases	Leases Lessee We have operating and finance leases for land, buildings, pipelines, storage tanks, transportation and other equipment for our operations. Our leases have remaining terms of one to 56 years, some of which include options to extend the leases for up to 10 years. Certain of our leases for pipeline assets include provisions for variable payments which are based on a measure of throughput and also contain a provision for the lessor to adjust the rate per barrel periodically over the life of the lease. These variable costs are not included in the initial measurement of ROU assets and lease liabilities. The following table presents the amounts and balance sheet locations of our operating and financing leases recorded on our consolidated balance sheets. December 31, 2023 2022 (In thousands) Operating leases: Operating lease right-of-use assets $ 348,006 $ 351,068 Operating lease liabilities 106,973 109,926 Noncurrent operating lease liabilities 249,479 254,215 Total operating lease liabilities $ 356,452 $ 364,141 Finance leases: Properties, plants and equipment, at cost $ 108,746 $ 81,454 Accumulated amortization (25,271) (21,434) Properties, plants and equipment, net $ 83,475 $ 60,020 Accrued liabilities $ 10,842 $ 10,722 Other long-term liabilities 74,860 50,361 Total finance lease liabilities $ 85,702 $ 61,083 Supplemental balance sheet information related to our leases was as follows: December 31, 2023 2022 Weighted average remaining lease term (in years) Operating leases 7.9 7.2 Finance leases 8.7 7.8 Weighted average discount rate Operating leases 5.0 % 4.2 % Finance leases 5.8 % 4.2 % The components of lease expense were as follows: Years Ended December 31, 2023 2022 2021 (In thousands) Operating lease expense $ 120,552 $ 116,769 $ 117,292 Finance lease expense: Amortization of right-of-use assets 13,007 13,003 4,295 Interest on lease liabilities 3,156 2,593 733 Variable lease cost 12,968 4,448 3,645 Total lease expense $ 149,683 $ 136,813 $ 125,965 Supplemental cash flow information related to leases was as follows: Years Ended December 31, 2023 2022 2021 (In thousands) Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 127,923 $ 126,048 $ 129,577 Operating cash flows from finance leases $ 3,156 $ 2,593 $ 733 Financing cash flows from finance leases $ 11,923 $ 11,713 $ 3,990 Right-of-use assets obtained in exchange for lease obligations: Operating leases $ 103,352 $ 61,403 $ 147,718 Finance leases $ 38,061 $ 6,149 $ 64,334 As of December 31, 2023, minimum future lease payments of our operating and finance lease obligations were as follows: Operating Finance (In thousands) 2024 $ 118,006 $ 15,375 2025 65,436 13,650 2026 50,145 12,537 2027 31,644 11,442 2028 24,398 10,766 Thereafter 163,651 46,869 Future minimum lease payments 453,280 110,639 Less: imputed interest 96,828 24,937 Total lease obligations 356,452 85,702 Less: current obligations 106,973 10,842 Long-term lease obligations $ 249,479 $ 74,860 As of December 31, 2023, we entered into certain leases that have not yet commenced. Such leases include a 15-year lease for a manufacturing and distribution facility, with estimated future undiscounted lease payments of $62.8 million, expected to commence in the first quarter of 2024. Lessor Our consolidated statements of income reflect lease revenue recognized by our midstream operations for contracts with third parties in which we are the lessor. Substantially all of the assets supporting contracts meeting the definition of a lease have long useful lives, and we believe these assets will continue to have value when the current agreements expire due to our risk management strategy for protecting the residual fair value of the underlying assets by performing ongoing maintenance during the lease term. Lease income recognized was as follows: Years Ended December 31, 2023 2022 2021 (In thousands) Operating lease revenues $ 16,879 $ 14,346 $ 15,281 Sales-type lease interest income $ 1,634 $ 2,515 $ 2,545 Lease revenues relating to variable lease payments not included in measurement of the sales-type lease receivable $ 1,325 $ 1,782 $ 2,162 For our sales-type leases, we included customer obligations related to minimum volume requirements in guaranteed minimum lease payments. Portions of our minimum guaranteed pipeline tariffs for assets subject to sales-type lease accounting are recorded as interest income with the remaining amounts recorded as a reduction in net investment in leases. We recognized any billings for throughput volumes in excess of minimum volume requirements as variable lease payments, and these variable lease payments were recorded in lease revenues. Annual minimum undiscounted lease payments in which we are a lessor to third-party contracts as of December 31, 2023 were as follows: Operating Sales-type (In thousands) 2024 $ 12,994 $ 2,170 2025 3,441 2,170 2026 — 2,170 2027 — 2,170 2028 — 2,170 Thereafter — 13,560 Total lease payment receipts $ 16,435 24,410 Less: imputed interest (15,945) 8,465 Unguaranteed residual assets at end of leases 25,180 Net investment in leases $ 33,645 Net investment in sales-type leases recorded on our consolidated balance sheets was composed of the following: December 31, 2023 December 31, 2022 (In thousands) Lease receivables $ 18,830 $ 23,797 Unguaranteed residual assets 14,815 10,383 Net investment in leases $ 33,645 $ 34,180
Leases	Leases Lessee We have operating and finance leases for land, buildings, pipelines, storage tanks, transportation and other equipment for our operations. Our leases have remaining terms of one to 56 years, some of which include options to extend the leases for up to 10 years. Certain of our leases for pipeline assets include provisions for variable payments which are based on a measure of throughput and also contain a provision for the lessor to adjust the rate per barrel periodically over the life of the lease. These variable costs are not included in the initial measurement of ROU assets and lease liabilities. The following table presents the amounts and balance sheet locations of our operating and financing leases recorded on our consolidated balance sheets. December 31, 2023 2022 (In thousands) Operating leases: Operating lease right-of-use assets $ 348,006 $ 351,068 Operating lease liabilities 106,973 109,926 Noncurrent operating lease liabilities 249,479 254,215 Total operating lease liabilities $ 356,452 $ 364,141 Finance leases: Properties, plants and equipment, at cost $ 108,746 $ 81,454 Accumulated amortization (25,271) (21,434) Properties, plants and equipment, net $ 83,475 $ 60,020 Accrued liabilities $ 10,842 $ 10,722 Other long-term liabilities 74,860 50,361 Total finance lease liabilities $ 85,702 $ 61,083 Supplemental balance sheet information related to our leases was as follows: December 31, 2023 2022 Weighted average remaining lease term (in years) Operating leases 7.9 7.2 Finance leases 8.7 7.8 Weighted average discount rate Operating leases 5.0 % 4.2 % Finance leases 5.8 % 4.2 % The components of lease expense were as follows: Years Ended December 31, 2023 2022 2021 (In thousands) Operating lease expense $ 120,552 $ 116,769 $ 117,292 Finance lease expense: Amortization of right-of-use assets 13,007 13,003 4,295 Interest on lease liabilities 3,156 2,593 733 Variable lease cost 12,968 4,448 3,645 Total lease expense $ 149,683 $ 136,813 $ 125,965 Supplemental cash flow information related to leases was as follows: Years Ended December 31, 2023 2022 2021 (In thousands) Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 127,923 $ 126,048 $ 129,577 Operating cash flows from finance leases $ 3,156 $ 2,593 $ 733 Financing cash flows from finance leases $ 11,923 $ 11,713 $ 3,990 Right-of-use assets obtained in exchange for lease obligations: Operating leases $ 103,352 $ 61,403 $ 147,718 Finance leases $ 38,061 $ 6,149 $ 64,334 As of December 31, 2023, minimum future lease payments of our operating and finance lease obligations were as follows: Operating Finance (In thousands) 2024 $ 118,006 $ 15,375 2025 65,436 13,650 2026 50,145 12,537 2027 31,644 11,442 2028 24,398 10,766 Thereafter 163,651 46,869 Future minimum lease payments 453,280 110,639 Less: imputed interest 96,828 24,937 Total lease obligations 356,452 85,702 Less: current obligations 106,973 10,842 Long-term lease obligations $ 249,479 $ 74,860 As of December 31, 2023, we entered into certain leases that have not yet commenced. Such leases include a 15-year lease for a manufacturing and distribution facility, with estimated future undiscounted lease payments of $62.8 million, expected to commence in the first quarter of 2024. Lessor Our consolidated statements of income reflect lease revenue recognized by our midstream operations for contracts with third parties in which we are the lessor. Substantially all of the assets supporting contracts meeting the definition of a lease have long useful lives, and we believe these assets will continue to have value when the current agreements expire due to our risk management strategy for protecting the residual fair value of the underlying assets by performing ongoing maintenance during the lease term. Lease income recognized was as follows: Years Ended December 31, 2023 2022 2021 (In thousands) Operating lease revenues $ 16,879 $ 14,346 $ 15,281 Sales-type lease interest income $ 1,634 $ 2,515 $ 2,545 Lease revenues relating to variable lease payments not included in measurement of the sales-type lease receivable $ 1,325 $ 1,782 $ 2,162 For our sales-type leases, we included customer obligations related to minimum volume requirements in guaranteed minimum lease payments. Portions of our minimum guaranteed pipeline tariffs for assets subject to sales-type lease accounting are recorded as interest income with the remaining amounts recorded as a reduction in net investment in leases. We recognized any billings for throughput volumes in excess of minimum volume requirements as variable lease payments, and these variable lease payments were recorded in lease revenues. Annual minimum undiscounted lease payments in which we are a lessor to third-party contracts as of December 31, 2023 were as follows: Operating Sales-type (In thousands) 2024 $ 12,994 $ 2,170 2025 3,441 2,170 2026 — 2,170 2027 — 2,170 2028 — 2,170 Thereafter — 13,560 Total lease payment receipts $ 16,435 24,410 Less: imputed interest (15,945) 8,465 Unguaranteed residual assets at end of leases 25,180 Net investment in leases $ 33,645 Net investment in sales-type leases recorded on our consolidated balance sheets was composed of the following: December 31, 2023 December 31, 2022 (In thousands) Lease receivables $ 18,830 $ 23,797 Unguaranteed residual assets 14,815 10,383 Net investment in leases $ 33,645 $ 34,180

Properties, Plants and Equipmen

Properties, Plants and Equipment	12 Months Ended
Properties, Plants and Equipment	Dec. 31, 2023
Property, Plant and Equipment [Abstract]
Properties, Plants and Equipment	Properties, Plants and Equipment The components of properties, plants and equipment are as follows: December 31, 2023 2022 (In thousands) Land, buildings and improvements $ 765,826 $ 741,874 Refining facilities 6,593,768 6,346,422 Pipelines and terminals 2,300,781 2,267,052 Transportation vehicles 37,870 43,801 Other fixed assets 543,966 422,583 Construction in progress 291,221 324,920 10,533,432 10,146,652 Accumulated depreciation (3,906,600) (3,457,747) $ 6,626,832 $ 6,688,905 We capitalized interest attributable to construction projects of $4.3 million, $6.2 million and $15.2 million for the years ended December 31, 2023, 2022 and 2021, respectively. Depreciation expense was $474.3 million, $442.2 million and $329.4 million for the years ended December 31, 2023, 2022 and 2021, respectively.

Goodwill and Intangibles

Goodwill and Intangibles	12 Months Ended
Goodwill and Intangibles	Dec. 31, 2023
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Intangibles	Goodwill and Intangibles Goodwill As of December 31, 2023, our goodwill balance was $3.0 billion. The carrying amount of our goodwill may fluctuate from period to period due to the effects of foreign currency translation adjustments on goodwill assigned to our Lubricants & Specialties segment. The following is a summary of our goodwill by segment: Refining Renewables Marketing Lubricants & Specialties Midstream Total (In thousands) Balance at December 31, 2022 $ 1,977,435 $ 159,020 $ 163,839 $ 246,036 $ 431,985 $ 2,978,315 Goodwill disposal and other changes — — — (943) — (943) Foreign currency translation adjustment — — — 372 — 372 Balance at December 31, 2023 $ 1,977,435 $ 159,020 $ 163,839 $ 245,465 $ 431,985 $ 2,977,744 Balance at December 31, 2023 Goodwill $ 2,286,753 $ 159,020 $ 163,839 $ 480,044 $ 431,985 $ 3,521,641 Accumulated impairment losses (309,318) — — (234,579) — (543,897) $ 1,977,435 $ 159,020 $ 163,839 $ 245,465 $ 431,985 $ 2,977,744 We performed our annual goodwill impairment testing quantitatively as of July 1, 2023 and determined there was no impairment of goodwill attributable to our reporting units. Furthermore, there was no impairment of goodwill during the years ended December 31, 2022 and 2021. Intangibles The carrying amounts of our intangible assets presented in “Intangibles and other” on our consolidated balance sheets are as follows: December 31 Useful Life 2023 2022 (In thousands) Customer relationships 10 - 20 years $ 347,567 $ 346,354 Transportation agreements 30 years 59,933 59,933 Trademarks, patents and other 10 - 20 years 263,855 261,678 671,355 667,965 Accumulated amortization (260,723) (204,239) Total intangibles, net $ 410,632 $ 463,726 Amortization expense w as $55.1 million, $51.0 million and $35.6 million for the years ended December 31, 2023, 2022 and 2021, respectively. Estimated future amortization expense related to the intangible assets at December 31, 2023 is as follows: (In thousands) 2024 $ 55,261 2025 $ 55,261 2026 $ 46,499 2027 $ 40,753 2028 $ 34,253

Income Taxes

Income Taxes	12 Months Ended
Income Taxes	Dec. 31, 2023
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The provision for income taxes is comprised of the following: Years Ended December 31, 2023 2022 2021 (In thousands) Current Federal $ 179,677 $ 674,977 $ (33,206) State 24,419 108,993 (1,802) Foreign 44,966 57,734 30,336 Deferred Federal 154,996 38,535 94,353 State 31,285 21,121 1,386 Foreign 6,269 (6,488) 32,831 $ 441,612 $ 894,872 $ 123,898 The statutory federal income tax rate applied to pre-tax book income reconciles to income tax expense as follows: Years Ended December 31, 2023 2022 2021 (In thousands) Tax computed at statutory rate $ 452,027 $ 826,570 $ 165,302 State income taxes, net of federal tax benefit 55,734 123,442 13,588 Noncontrolling interest in net income (29,386) (28,726) (25,931) Effect of change in state rate — (15,800) (13,342) Nontaxable permanent differences (49,420) — — CARES Act benefits — — (10,384) Foreign rate differential 5,753 6,608 331 Federal tax credits (5,344) (23,853) (29,777) US tax on non-US operations 7,239 12,920 18,547 Other 5,009 (6,289) 5,564 $ 441,612 $ 894,872 $ 123,898 Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. Our deferred income tax assets and liabilities as of December 31, 2023 and 2022 are as follows: December 31, 2023 Assets Liabilities Total (In thousands) Deferred income taxes Properties, plants, equipment and intangibles (due primarily to tax in excess of book depreciation) $ — $ (1,171,633) $ (1,171,633) Lease obligation 106,161 — 106,161 Accrued employee benefits 20,260 — 20,260 Accrued post-retirement benefits 9,985 — 9,985 Accrued environmental costs 42,916 — 42,916 Hedging instruments 1,791 — 1,791 Inventory differences — (164,178) (164,178) Deferred turnaround costs — (155,833) (155,833) Net operating loss and tax credit carryforwards 35,294 — 35,294 Valuation allowance — (10,614) (10,614) Other — (11,279) (11,279) Total $ 216,407 $ (1,513,537) $ (1,297,130) December 31, 2022 Assets Liabilities Total (In thousands) Deferred income taxes Properties, plants, equipment and intangibles (due primarily to tax in excess of book depreciation) $ — $ (1,032,048) $ (1,032,048) Lease obligation 129,727 — 129,727 Accrued employee benefits 17,665 — 17,665 Accrued post-retirement benefits 9,951 — 9,951 Accrued environmental costs 37,868 — 37,868 Hedging instruments 3,260 — 3,260 Inventory differences — (230,112) (230,112) Deferred turnaround costs — (88,574) (88,574) Net operating loss and tax credit carryforwards 27,963 — 27,963 Investment in HEP — (134,160) (134,160) Valuation allowance — (3,691) (3,691) Other — (14) (14) Total $ 226,434 $ (1,488,599) $ (1,262,165) We have tax benefits attributable to net operating losses of $17.6 million in Luxembourg that can be carried forward 16 years which will begin expiring in 2034. We also have tax benefits attributable to net operating losses of $11.2 million in the Netherlands that can be carried forward indefinitely, and tax benefits attributable to net operating losses in China of $3.5 million which can be carried forward five years. We have reflected a valuation allowance of $10.6 million in 2023 and $3.7 million in 2022, with respect to net operating carryforwards that primarily relate to losses in Luxembourg and China. A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows: Years Ended December 31, 2023 2022 2021 (In thousands) Balance at January 1 $ 1,354 $ 54,605 $ 54,899 Reductions for tax positions of prior years — (53,023) (49) Settlements — — (125) Lapse of statute of limitations (129) (228) (120) Balance at December 31 $ 1,225 $ 1,354 $ 54,605 At December 31, 2023, 2022 and 2021, there were $1.2 million , $1.4 million, and $54.6 million, respectively, of unrecognized tax benefits that, if recognized, would affect our effective tax rate. Unrecognized tax benefits are adjusted in the period in which new information about a tax position becomes available or the final outcome differs from the amount recorded. Approximately $0.7 million of the unrecognized tax benefits relates to claims filed with the U.S. Internal Revenue Service (“IRS”) on the federal income tax treatment of refundable biodiesel/ethanol blending tax credits for prior years. We filed suit related to these claims in the Federal District Court of Dallas in March of 2022; the suit was stayed pending the outcome of controlling cases in the U.S. Court of Appeals for the Fifth Circuit, which were decided in favor of the IRS and were not appealed. As such precedent is controlling for us, we intend to file a motion to dismiss those claims controlled by such precedent in the Federal District Court of Dallas during 2024. We recognize interest and penalties relating to liabilities for unrecognized tax benefits as an element of tax expense. We have not recorded any penalties related to our uncertain tax positions as we believe that it is more likely than not that there will not be any assessment of penalties. We are subject to U.S. and Canadian federal income tax, Oklahoma, Oregon, Kansas, New Mexico, Iowa, Arizona, Utah, Colorado and Nebraska income tax and to income tax of multiple other state and local jurisdictions. We have substantially concluded all state and local income tax matters for tax years through 2019. Other than the federal claim noted above and to the extent of the federal net operating loss carried back to 2015 from 2020, we have materially concluded all U.S. federal income tax matters for tax years through December 31, 2019. We are currently under audit with the Canada Revenue Agency for the 2018, 2019, and 2020 tax years and the IRS for the 2020 and 2021 tax years.

Pension and Post-retirement Pla

Pension and Post-retirement Plans	12 Months Ended
Pension and Post-retirement Plans	Dec. 31, 2023
Retirement Benefits [Abstract]
Pension and Post-retirement Plans	Pension and Post-retirement Plans Certain Petro-Canada Lubricants Inc. (“PCLI”) employees are participants in union and non-union pension plans, which are closed to new entrants. Effective June 30, 2022, we ceased to accrue additional benefits under these plans, at which time the plan was fully frozen. During 2023, we had partial settlements in the union and non-union pension plans. We expect the remaining benefits will be settled by the end of 2024. In addition, Sonneborn employees in the Netherlands have a defined benefit pension plan which was frozen and all plan participants became inactive in 2016. The plan assets are in the form of a third-party insurance contract that is valued based on the assets held by the insurer and insures a value which approximates the accrued benefits related to the plan’s accumulated benefit obligation. At that time, a new plan was established to provide future indexation benefits to participants who had accrued benefits under the expiring arrangements. The following table sets forth the changes in the benefit obligation and plan assets of our PCLI pension plans and Sonneborn Netherlands plans for the years ended December 31, 2023 and 2022. Years Ended December 31, 2023 2022 (In thousands) Change in plans' benefit obligations Pension plans benefit obligation - beginning of period $ 90,443 $ 120,414 Service cost — 1,839 Interest cost 3,781 3,086 Actuarial gain 2,097 (25,605) Benefits paid (5,472) (2,306) Settlements (24,090) — Transfer from other plans 3,849 164 Foreign currency exchange rate changes 2,032 (7,149) Pension plans benefit obligation - end of year $ 72,640 $ 90,443 Change in pension plans assets Fair value of plans assets - beginning of period $ 87,466 $ 119,325 Return on plans assets 7,146 (26,218) Employer contributions 1,324 3,486 Benefits paid (4,697) (2,306) Transfer payments 3,849 164 Settlements (24,090) — Foreign currency exchange rate changes 2,020 (6,985) Fair value of plans assets - end of year $ 73,018 $ 87,466 Funded status Over (Under)-funded balance $ 378 $ (2,977) Amounts recognized in consolidated balance sheets Intangibles and other $ 1,149 $ — Other long-term liabilities (771) (2,977) $ 378 $ (2,977) Amounts recognized in accumulated other comprehensive loss Cumulative actuarial loss $ (607) $ (3,872) The accumulated benefit obligation was $72.6 million and $90.4 million at December 31, 2023 and 2022, respectively, which are also the measurement dates used for our pension plans. The following tables provide information regarding pension plans with a projected benefit obligation and accumulated benefit obligation in excess of the fair value of plan assets: December 31, 2023 2022 (In thousands) Projected benefit obligation $ 24,579 $ 90,443 Fair value of plan assets $ 23,808 $ 87,466 December 31, 2023 2022 (In thousands) Accumulated benefit obligation $ 24,579 $ 90,443 Fair value of plan assets $ 23,808 $ 87,466 The weighted average assumption used to determine the end of period benefit obligation for the PCLI plans for the year ended December 31, 2023 were discount rates of 4.60% to 4.65%. The weighted average assumptions used to determine the end of period benefit obligation for the PCLI plans for the year ended December 31, 2022 were discount rates of 3.70% to 4.44%. For the years ended December 31, 2023 and 2022, the weighted average assumption used to determine end of period benefit obligations for Sonneborn were discount rates of 3.60% and 4.20%, respectively. Net periodic pension expense consisted of the following components: Years Ended December 31, 2023 2022 2021 (In thousands) Service cost - benefit earned during the period $ — $ 1,839 $ 4,455 Interest cost on projected benefit obligations 3,781 3,086 2,740 Expected return on plans assets (3,140) (3,223) (3,031) Amortization of gain — (208) (407) Settlements 1,378 — — Net periodic pension expense $ 2,019 $ 1,494 $ 3,757 The components, other than service cost, of our net periodic pension expense are recorded in Other, net on our consolidated statements of income. The following table presents the fair values of PCLI’s pension plans’ assets, by level within the fair value hierarchy, as of December 31, 2023 and 2022. December 31, 2023 December 31, 2022 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total (In thousands) Fixed income 822 48,387 — 49,209 457 66,295 — 66,752 $ 822 $ 48,387 $ — $ 49,209 $ 457 $ 66,295 $ — $ 66,752 See Note 6 for additional information on Level 1 and 2 inputs. The expected long-term rate of return on plan assets is 4.60% to 4.65% for the PCLI pension plans and is based on a target investment of 100% in fixed income. We expect to contribute $0.2 million to the Sonneborn pension plans in 2024. PCLI and Sonneborn pension plan benefit payments, which reflect expected future service, are expected to be paid as follows: $1.9 million in 2024, $0.8 million in 2025, $0.9 million in 2026, $0.9 million in 2027, $1.0 million in 2028 and $6.0 million in 2029 to 2033. Benefit payments expected to be paid in 2024 include the estimate of the net present value of all expected benefit payments to be paid out once the PCLI union and non-union pension plans windup has been finalized. Post-retirement Healthcare Plans We have post-retirement healthcare and other benefits plans that are available to certain of our employees who satisfy certain age and service requirements. These plans are unfunded and provide differing levels of healthcare benefits dependent upon hire date and work location. Not all of our employees are covered by these plans at December 31, 2023. The following table sets forth the changes in the benefit obligation and plan assets of our post-retirement healthcare plans for the years ended December 31, 2023 and 2022: Years Ended December 31, 2023 2022 (In thousands) Change in plans' benefit obligation Post-retirement plans' benefit obligation - beginning of year $ 28,678 $ 34,816 Service cost 1,604 2,081 Interest cost 1,340 990 Benefits paid (613) (582) Actuarial gain (761) (7,884) Foreign currency exchange rate changes 249 (743) Post-retirement plans' benefit obligation - end of year $ 30,497 $ 28,678 Change in plan assets Fair value of plan assets - beginning of year $ — $ — Employer contributions 603 572 Participant contributions 10 10 Benefits paid (613) (582) Fair value of plan assets - end of year $ — $ — Funded status Under-funded balance $ (30,497) $ (28,678) Amounts recognized in consolidated balance sheets Accrued liabilities $ (1,701) $ (1,706) Other long-term liabilities (28,796) (26,972) $ (30,497) $ (28,678) Amounts recognized in accumulated other comprehensive loss Cumulative actuarial gain $ 8,020 $ 7,603 Prior service credit 8,069 11,550 Total $ 16,089 $ 19,153 Benefit payments, which reflect expected future service, are expected to be paid as follows: $1.7 million in 2024; $2.5 million in 2025; $2.5 million in 2026; $2.5 million in 2027; $2.7 million in 2028; and $13.2 million in 2029 through 2033. The weighted average assumptions used to determine end of period benefit obligations: December 31, 2023 2022 Discount rate 4.60% - 4.81% 4.95% - 5.10% Current health care trend rate 6.00% - 6.75% 6.00% - 7.00% Ultimate health care trend rate 4.00% - 4.00% 4.00% - 4.00% Year rate reaches ultimate trend rate 2035 - 2041 2027 - 2041 Net periodic post-retirement credit consisted of the following components: Years Ended December 31, 2023 2022 2021 (In thousands) Service cost – benefit earned during the year $ 1,604 $ 2,081 $ 2,324 Interest cost on projected benefit obligations 1,340 990 782 Amortization of prior service credit (3,481) (3,472) (3,481) Amortization of (gain) loss (378) 32 153 Net periodic post-retirement credit $ (915) $ (369) $ (222) The components, other than service cost, of our net periodic post-retirement credit are recorded in Other, net on our consolidated statements of income. Prior service credits are amortized over the average remaining effective period to obtain full benefit eligibility for participants. Defined Contribution Plans We have defined contribution plans that cover substantially all qualified employees in the U.S., Canada and the Netherlands. Our contributions are based on an employee's eligible compensation and years of service. We also partially match our employees’ contributions. We expensed $80.8 million, $73.7 million and $45.0 million for the years ended December 31, 2023, 2022 and 2021, respectively, in connection with these plans.

Description of Business and P_2

Description of Business and Presentation of Financial Statements (Policies)	3 Months Ended	12 Months Ended
	Mar. 31, 2024	Dec. 31, 2023
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Description of Business	References herein to HF Sinclair, “we,” “our,” “ours,” and “us” refer only to HF Sinclair and its consolidated subsidiaries or to HF Sinclair or an individual subsidiary and not to any other person, with certain exceptions. References herein to Holly Energy Partners, L.P. (“HEP”) with respect to time periods prior to the closing of the HEP Merger Transaction (as defined below) on December 1, 2023 refer to HEP and its consolidated subsidiaries. We are an independent energy company that produces and markets high-value light products such as gasoline, diesel fuel, jet fuel, renewable diesel and other specialty products. We own and operate refineries located in Kansas, Oklahoma, New Mexico, Wyoming, Washington and Utah. We provide petroleum product and crude oil transportation, terminalling, storage and throughput services to our refineries and the petroleum industry. We market our refined products principally in the Southwest United States, the Rocky Mountains extending into the Pacific Northwest and in other neighboring Plains states and we supply high-quality fuels to more than 1,500 branded stations and license the use of the Sinclair brand at more than 300 additional locations throughout the country. We produce renewable diesel at two of our facilities in Wyoming and our facility in New Mexico. In addition, our subsidiaries produce and market base oils and other specialized lubricants in the United States, Canada and the Netherlands, and export products to more than 80 countries.	Description of Business: References herein to HF Sinclair Corporation (“HF Sinclair”) include HF Sinclair and its consolidated subsidiaries. In these financial statements, the words “we,” “our,” “ours” and “us” refer only to HF Sinclair and its consolidated subsidiaries or to HF Sinclair or an individual subsidiary and not to any other person, with certain exceptions. References herein to HF Sinclair “we,” “our,” “ours” and “us” with respect to time periods prior to March 14, 2022 refer to HollyFrontier Corporation (“HollyFrontier”) and its consolidated subsidiaries and do not include Hippo Holding LLC (now known as Sinclair Holding LLC), the parent company of Sinclair Oil LLC, Sinclair Transportation Company LLC or their respective consolidated subsidiaries (collectively, the “Acquired Sinclair Businesses”). References herein to HF Sinclair “we,” “our,” “ours” and “us” with respect to time periods from and after March 14, 2022 include the operations of the Acquired Sinclair Businesses. Unless otherwise specified, the financial statements included herein include financial information for HF Sinclair, which for the time period from March 14, 2022 to December 31, 2023 includes the combined business operations of HollyFrontier and the Acquired Sinclair Businesses. References herein to Holly Energy Partners, L.P. (“HEP”) with respect to time periods prior to the closing of the HEP Merger Transaction (as defined below) on December 1, 2023 refer to HEP and its consolidated subsidiaries. We are an independent energy company that produces and markets high-value light products such as gasoline, diesel fuel, jet fuel, renewable diesel and other specialty products. We own and operate refineries located in Kansas, Oklahoma, New Mexico, Wyoming, Washington and Utah. We provide petroleum product and crude oil transportation, terminalling, storage and throughput services to our refineries and the petroleum industry. We market our refined products principally in the Southwest United States, the Rocky Mountains extending into the Pacific Northwest and in other neighboring Plains states and we supply high-quality fuels to more than 1,500 branded stations and license the use of the Sinclair brand at more than 300 additional locations throughout the country. We produce renewable diesel at two of our facilities in Wyoming and our facility in New Mexico. In addition, our subsidiaries produce and market base oils and other specialized lubricants in the United States, Canada and the Netherlands, and export products to more than 80 countries.
Basis of Accounting	We have prepared these consolidated financial statements without audit. In management’s opinion, these consolidated financial statements include all normal recurring adjustments necessary for a fair presentation of our consolidated financial position as of March 31, 2024, the consolidated results of income, comprehensive income and statements of equity for the three months ended March 31, 2024 and 2023, and consolidated cash flows for the three months ended March 31, 2024 and 2023 in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”). Although certain notes and other information required by generally accepted accounting principles in the United States (“GAAP”) have been condensed or omitted, we believe that the disclosures in these consolidated financial statements are adequate to make the information presented not misleading. These consolidated financial statements should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2023, and with our audited consolidated financial statements as of and for the year ended December 31, 2023, included in Exhibit 99.1 to this Quarterly Report on Form 10-Q.
Accounts Receivable	Accounts Receivable:	Accounts Receivable: Our accounts receivable primarily consist of amounts due from customers that are primarily from sales of refined products and renewable diesel. Credit is extended based on our evaluation of the customer's financial condition, and in certain circumstances collateral, such as letters of credit or guarantees, is required. We reserve for expected credit losses based on our historical loss experience as well as expected credit losses from current economic conditions and management’s expectations of future economic conditions. Credit losses are charged to the allowance for expected credit losses when an account is deemed uncollectible. Our allowance for expected credit losses was $3.2 million at December 31, 2023 and $7.7 million at December 31, 2022. Accounts receivable attributable to crude oil resales generally represent the sale of excess crude oil to other purchasers and / or users in cases when our crude oil supplies are in excess of our immediate needs as well as certain reciprocal buy / sell exchanges of crude oil. At times we enter into such buy / sell exchanges to facilitate the delivery of quantities to certain locations. In many cases, we enter into net settlement agreements relating to the buy / sell arrangements, which may mitigate credit risk.
Inventories	Inventories: Inventories related to our refining operations are stated at the lower of cost, using the last-in, first-out (“LIFO”) method for crude oil and unfinished and finished refined products or market. Inventories related to our renewables business are stated at the lower of cost, using the LIFO method for feedstock and unfinished and finished renewable products, or market. In periods of rapidly declining prices, LIFO inventories may have to be written down to market value due to the higher costs assigned to LIFO layers in prior periods. In addition, the use of the LIFO inventory method may result in increases or decreases to cost of sales in years that inventory volumes decline as the result of charging cost of sales with LIFO inventory costs generated in prior periods. An actual valuation of inventory under the LIFO method is made at the end of each year based on the inventory levels at that time. Accordingly, interim LIFO calculations are based on management’s estimates of expected year-end inventory levels and are subject to the final year-end LIFO inventory valuation. Inventories of our Petro-Canada Lubricants and Sonneborn businesses are stated at the lower of cost, using the first-in, first-out method or net realizable value. Inventories consisting of process chemicals, materials and maintenance supplies and RINs are stated at the lower of weighted average cost or net realizable value.	Inventories: Inventories related to our refining operations are stated at the lower of cost, using the last-in, first-out (“LIFO”) method for crude oil and unfinished and finished refined products, or market. Inventories related to our renewable business are stated at the lower of cost, using the LIFO method for feedstock and unfinished and finished renewable products, or market. Cost, consisting of raw material, transportation and conversion costs, is determined using the LIFO inventory valuation methodology and market is determined using current replacement costs. Under the LIFO method, the most recently incurred costs are charged to cost of sales and inventories are valued at the earliest acquisition costs. In periods of rapidly declining prices, LIFO inventories may have to be written down to market value due to the higher costs assigned to LIFO layers in prior periods. In addition, the use of the LIFO inventory method may result in increases or decreases to cost of sales in years that inventory volumes decline as the result of charging cost of sales with LIFO inventory costs generated in prior periods. An actual valuation of inventory under the LIFO method is made at the end of each year based on the inventory levels at that time. Accordingly, interim LIFO calculations are based on management’s estimates of expected year-end inventory levels and are subject to the final year-end LIFO inventory valuation. Inventories of our Petro-Canada Lubricants and Sonneborn businesses are stated at the lower of cost, using the first-in, first-out (“FIFO”) method, or net realizable value. Inventories consisting of process chemicals, materials and maintenance supplies and RINs are stated at the lower of weighted-average cost or net realizable value.
Leases	Leases: At inception, we determine if an arrangement is or contains a lease. Right-of-use (“ROU”) assets represent our right to use an underlying asset for the lease term and lease liabilities represent our payment obligation under the leasing arrangement. ROU assets and lease liabilities are recognized at the commencement date based on the present value of lease payments over the lease term. We use our estimated incremental borrowing rate (“IBR”) to determine the present value of lease payments as most of our leases do not contain an implicit rate. Our IBR represents the interest rate that we would pay to borrow, on a collateralized basis, an amount equal to the lease payments over a similar term in a similar economic environment. We use the implicit rate when readily determinable. Operating leases are recorded in “Operating lease right-of-use assets” and current and noncurrent “Operating lease liabilities” on our consolidated balance sheets. Finance leases are included in “Properties, plants and equipment, at cost,” “Accrued liabilities” and “Other long-term liabilities” on our consolidated balance sheets. Our lease term includes an option to extend the lease when it is reasonably certain that we will exercise that option. Leases with a term of 12 months or less are not recorded on our consolidated balance sheets. For certain equipment leases, we apply a portfolio approach for the operating lease ROU assets and liabilities. Also, as a lessee, we separate non-lease components that are identifiable and exclude them from the determination of net present value of lease payment obligations. In addition, as a lessor, we do not separate the non-lease (service) component in contracts in which the lease component is the dominant component. We treat these combined components as an operating lease. We bifurcate the consideration received for sales-type lease contracts between lease and service revenue, with the service component accounted for within the scope of ASC 606, “Revenue from Contracts with Customers.”	Leases: At inception, we determine if an arrangement is or contains a lease. Right-of-use (“ROU”) assets represent our right to use an underlying asset for the lease term and lease liabilities represent our payment obligation under the leasing arrangement. ROU assets and lease liabilities are recognized at the commencement date based on the present value of lease payments over the lease term. We use our estimated incremental borrowing rate (“IBR”) to determine the present value of lease payments as most of our leases do not contain an implicit rate. Our IBR represents the interest rate which we would pay to borrow, on a collateralized basis, an amount equal to the lease payments over a similar term in a similar economic environment. We use the implicit rate when readily determinable. Operating leases are recorded in “Operating lease right-of-use assets” and current and noncurrent “Operating lease liabilities” on our consolidated balance sheets. Finance leases are included in “Properties, plants and equipment, at cost” and “Accrued liabilities” and “Other long-term liabilities” on our consolidated balance sheets. Our lease term includes an option to extend the lease when it is reasonably certain that we will exercise that option. Leases with a term of 12 months or less are not recorded on our balance sheets. For certain equipment leases, we apply a portfolio approach for the operating lease ROU assets and liabilities. Also, as a lessee, we separate non-lease components that are identifiable and exclude them from the determination of net present value of lease payment obligations. In addition, as a lessor, we do not separate the non-lease (service) component in contracts in which the lease component is the dominant component. We treat these combined components as an operating lease. We bifurcate the consideration received for sales-type lease contracts between lease and service revenue, with the service component accounted for within the scope of ASC 606, “Revenue from Contracts with Customers”.
Lessor	Lessor:
Revenue Recognition	Revenue Recognition: Revenues on refined products, branded fuel sales, renewable diesel, and excess crude oil sales are recognized when delivered (via pipeline, in-tank or rack), and the customer obtains control of such inventory, which is typically when title passes and the customer is billed. All revenues are reported inclusive of shipping and handling costs billed and exclusive of any taxes billed to customers. Shipping and handling costs incurred are reported as cost of products sold. Our Lubricants & Specialties business has sales agreements with marketers and distributors that provide certain rights of return or provisions for the repurchase of products previously sold to them. Under these agreements, revenues and cost of revenues are deferred until the products have been sold to end customers. Our Lubricants & Specialties business also has agreements that create an obligation to deliver products at a future date for which consideration has already been received and recorded as deferred revenue. This revenue is recognized when the products are delivered to the customer. Our Midstream business recognizes revenues as products are shipped through its pipelines and terminals and as other services are rendered. Additionally, we have certain throughput agreements that specify minimum volume requirements, whereby we bill a customer for a minimum level of shipments in the event a customer ships below their contractual requirements. If there are no future performance obligations, we recognize these deficiency payments as revenue. In certain of these throughput agreements, a customer may later utilize such shortfall billings as credit towards future volume shipments in excess of its minimum levels within its respective contractual shortfall make-up period. Such amounts represent an obligation to perform future services, which may be initially deferred and later recognized as revenue based on estimated future shipping levels, including the likelihood of a customer’s ability to utilize such amounts prior to the end of the contractual shortfall make-up period. We recognize the service portion of these deficiency payments as revenue when we do not expect it will be required to satisfy these performance obligations in the future based on the pattern of rights exercised by the customer. Payment terms under our contracts with customers are consistent with industry norms and are typically payable within 30 days of the date of invoice.	Revenue Recognition: Revenues on refined product, branded fuel sales, renewable diesel and excess crude oil sales are recognized when delivered (via pipeline, in-tank or rack) and the customer obtains control of such inventory, which is typically when title passes and the customer is billed. All revenues are reported inclusive of shipping and handling costs billed and exclusive of any taxes billed to customers. Shipping and handling costs incurred are reported as cost of products sold. Our lubricants and specialties business has sales agreements with marketers and distributors that provide certain rights of return or provisions for the repurchase of products previously sold to them. Under these agreements, revenues and cost of revenues are deferred until the products have been sold to end customers. Our lubricants and specialties business also has agreements that create an obligation to deliver products at a future date for which consideration has already been received and recorded as deferred revenue. This revenue is recognized when the products are delivered to the customer. Our midstream business recognizes revenues as products are shipped through its pipelines and terminals and as other services are rendered. Additionally, we have certain throughput agreements that specify minimum volume requirements, whereby we bill a customer for a minimum level of shipments in the event a customer ships below their contractual requirements. If there are no future performance obligations, we recognize these deficiency payments as revenue. In certain of these throughput agreements, a customer may later utilize such shortfall billings as credit towards future volume shipments in excess of its minimum levels within its respective contractual shortfall make-up period. Such amounts represent an obligation to perform future services, which may be initially deferred and later recognized as revenue based on estimated future shipping levels, including the likelihood of a customer’s ability to utilize such amounts prior to the end of the contractual shortfall make-up period. We recognize the service portion of these deficiency payments as revenue when we do not expect it will be required to satisfy these performance obligations in the future based on the pattern of rights exercised by the customer. Payment terms under our contracts with customers are consistent with industry norms and are typically payable within 30 days of the date of invoice.
Foreign Currency Translation	Foreign Currency Translation: Assets and liabilities recorded in foreign currencies are translated into U.S. dollars using exchange rates in effect as of the balance sheet date. Revenue and expense accounts are translated using the weighted average exchange rates during the period presented. Foreign currency translation adjustments are recorded as a component of accumulated other comprehensive income. We have intercompany notes that were issued to fund certain of our foreign businesses. Remeasurement adjustments resulting from the conversion of intercompany financing amounts to functional currencies are recorded as gains and losses as a component of other income (expense) in the consolidated statements of income. Such adjustments are not recorded in the Lubricants & Specialties segment operations, but in Corporate and Other. See Note 14 for additional information on our segments.	Foreign Currency Translation: Assets and liabilities recorded in foreign currencies are translated into U.S. dollars using exchange rates in effect as of the balance sheet date. Revenue and expense accounts are translated using the weighted-average exchange rates during the period presented. Foreign currency translation adjustments are recorded as a component of accumulated other comprehensive income. We have intercompany notes that were issued to fund certain of our foreign businesses. Remeasurement adjustments resulting from the conversion of such intercompany financing amounts to functional currencies are recorded as gains or losses as a component of other income (expense) on our consolidated statements of income. Such adjustments are not recorded to the Lubricants & Specialties segment operations, but to Corporate and Other. See Note 20 for additional information on our segments.
Income Taxes	Income Taxes: Provisions for income taxes include deferred taxes resulting from temporary differences in income for financial and tax purposes, using the liability method of accounting for income taxes. The liability method requires the effect of tax rate changes on deferred income taxes to be reflected in the period in which the rate change was enacted. The liability method also requires that deferred tax assets be reduced by a valuation allowance unless it is more likely than not that the assets will be realized. We account for U.S. tax on global intangible low-taxed income in the period in which it is incurred. Potential interest and penalties related to income tax matters are recognized in income tax expense. We believe we have the appropriate support for the income tax positions taken and to be taken on our income tax returns and that our accruals for tax liabilities are adequate for all open years based on an assessment of many factors, including past experience and interpretations of tax law applied to the facts of each matter.	Income Taxes: Provisions for income taxes include deferred taxes resulting from temporary differences in income for financial and tax purposes, using the liability method of accounting for income taxes. The liability method requires the effect of tax rate changes on deferred income taxes to be reflected in the period in which the rate change was enacted. The liability method also requires that deferred tax assets be reduced by a valuation allowance unless it is more likely than not that the assets will be realized. We account for U.S. tax on global intangible low-taxed income in the period in which it is incurred. Potential interest and penalties related to income tax matters are recognized in income tax expense. We believe we have appropriate support for the income tax positions taken and to be taken on our income tax returns and that our accruals for tax liabilities are adequate for all open years based on an assessment of many factors, including past experience and interpretations of tax law applied to the facts of each matter.
Inventory Repurchase Obligations	Inventory Repurchase Obligations: We periodically enter into same-party sell/buy transactions, whereby we sell certain refined product inventory and subsequently repurchase the inventory in order to facilitate delivery to certain locations. Such sell/bu	Inventory Repurchase Obligations:
Accounting Pronouncements - Not Yet Adopted	Accounting Pronouncements - Not Yet Adopted In November 2023, Accounting Standards Update (“ASU”) 2023-07, “Improvements to Reportable Segment Disclosures” was issued. ASU 2023-07 requires, among other updates, enhanced disclosures about significant segment expenses that are regularly provided to the chief operating decision maker, as well as the aggregate amount of other segment items included in the reported measure of segment profit or loss. This aims to provide more decision-useful information to stakeholders by giving a clearer picture of the costs incurred by each reportable segment. ASU 2023-07 is effective for fiscal years beginning after December 15, 2023, and interim periods within fiscal years beginning after December 15, 2024, and requires retrospective adoption. Early adoption is permitted. We are assessing the impact of this guidance on our disclosures.	Accounting Pronouncements - Recently Adopted In October 2021, Accounting Standards Update (“ASU”) 2021-08, “Accounting for Contract Assets and Contract Liabilities from Contracts with Customers,” was issued requiring that an acquiring entity recognize and measure contract assets and contract liabilities acquired in a business combination in accordance with ASC 606, “Revenue from Contracts with Customers.” We adopted this standard effective January 1, 2023, but did not have a business combination under the scope of ASC 805, “Business Combinations” for the year ended December 31, 2023. Accounting Pronouncements - Not Yet Adopted In November 2023, ASU 2023-07, “Improvements to Reportable Segment Disclosures” was issued. ASU 2023-07 requires, among other updates, enhanced disclosures about significant segment expenses that are regularly provided to the chief operating decision maker, as well as the aggregate amount of other segment items included in the reported measure of segment profit or loss. This aims to provide more decision-useful information to stakeholders by giving a clearer picture of the costs incurred by each reportable segment. ASU 2023-07 is effective for fiscal years beginning after December 15, 2023, and interim periods within fiscal years beginning after December 15, 2024, and requires retrospective adoption. Early adoption is permitted. We are assessing the impact of this guidance on our disclosures.
Fair Value Measurements	Fair value measurements are derived using inputs (assumptions that market participants would use in pricing an asset or liability, including assumptions about risk). GAAP categorizes inputs used in fair value measurements into three broad levels as follows: • (Level 1) Quoted prices in active markets for identical assets or liabilities. • (Level 2) Observable inputs other than quoted prices included in Level 1, such as quoted prices for similar assets and liabilities in active markets, similar assets and liabilities in markets that are not active or can be corroborated by observable market data. • (Level 3) Unobservable inputs that are supported by little or no market activity and that are significant to the fair value of the assets or liabilities. This includes valuation techniques that involve significant unobservable inputs.	Fair value measurements are derived using inputs (assumptions that market participants would use in pricing an asset or liability, including assumptions about risk). GAAP categorizes inputs used in fair value measurements into three broad levels as follows: • (Level 1) Quoted prices in active markets for identical assets or liabilities. • (Level 2) Observable inputs other than quoted prices included in Level 1, such as quoted prices for similar assets and liabilities in active markets, similar assets and liabilities in markets that are not active or can be corroborated by observable market data. • (Level 3) Unobservable inputs that are supported by little or no market activity and that are significant to the fair value of the assets or liabilities. This includes valuation techniques that involve significant unobservable inputs.
Consolidation, Policy		Principles of Consolidation:
Consolidation, Variable Interest Entity, Policy		Variable Interest Entities: A variable interest entity ( “ VIE ”
Use of Estimates, Policy		Use of Estimates: The preparation of financial statements in accordance with U.S. generally accepted accounting principles (“GAAP”) requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. Actual results could differ from those estimates.
Cash and Cash Equivalents, Policy		Cash Equivalents: We consider all highly liquid instruments with a maturity of three months or less at the date of purchase to be cash equivalents. Cash equivalents are stated at cost, which approximates market value and are primarily invested in highly-rated instruments issued by government or municipal entities with strong credit standings.
Balance Sheet Offsetting		Balance Sheet Offsetting: We purchase and sell inventories of crude oil with certain same-parties that are net settled in accordance with contractual net settlement provisions. Our policy is to present such balances on a net basis since it presents our accounts receivables and payables consistent with our contractual settlement provisions.
Derivatives, Policy		Derivative Instruments: All derivative instruments are recognized as either assets or liabilities on our consolidated balance sheets and are measured at fair value. Changes in the derivative instrument's fair value are recognized in earnings unless specific hedge accounting criteria are met. Cash flows from all our derivative activity are reported in the operating section on our consolidated statements of cash flows. See Note 14 for additional information.
Property, Plant and Equipment, Policy		Properties, Plants and Equipment: Properties, plants and equipment are stated at cost. Depreciation is provided by the straight-line method over the estimated useful lives of the assets, primarily 15 to 32 years for refining, pipeline and terminal facilities, 10 to 40 years for buildings and improvements, 5 to 30 years for other fixed assets and 5 years for vehicles.
Asset Retirement Obligation		Asset Retirement Obligations: We record legal obligations associated with the retirement of long-lived assets that result from the acquisition, construction, development and / or the normal operation of long-lived assets. The fair value of the estimated cost to retire a tangible long-lived asset is recorded as a liability with the associated retirement costs capitalized as part of the asset's carrying amount in the period in which it is incurred and when a reasonable estimate of the fair value of the liability can be made. If a reasonable estimate cannot be made at the time the liability is incurred, we record the liability when sufficient information is available to estimate the liability's fair value. Certain of our refining assets have no recorded liability for asset retirement obligations since the timing of any retirement and related costs are currently indeterminable.
Goodwill		Intangibles, Goodwill and Long-lived Assets: Intangible assets are assets (other than financial assets) that lack physical substance, and goodwill represents the excess of the cost of an acquired entity over the fair value of the assets acquired and liabilities assumed. Goodwill acquired in a business combination and intangibles with indefinite useful lives are not amortized, whereas intangible assets with finite useful lives are amortized on a straight-line basis. Goodwill and intangible assets that are not subject to amortization are tested for impairment annually or more frequently if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying amount. Our goodwill impairment testing first entails either a quantitative assessment or an optional qualitative assessment to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount. If we determine that based on the qualitative factors that it is more likely than not that the carrying amount of the reporting unit is greater than its fair value, a quantitative test is performed in which we estimate the fair value of the related reporting unit. If the carrying amount of a reporting unit exceeds its fair value, the goodwill of that reporting unit is impaired, and we measure goodwill impairment as the excess of the carrying amount of the reporting unit over the related fair value. The carrying amount of our intangible assets and goodwill may fluctuate from period to period due to the effects of foreign currency translation adjustments on goodwill and intangible assets assigned to our Lubricants & Specialties segment. For purposes of long-lived asset impairment evaluation, we group our long-lived assets as follows: (i) our refinery asset groups, which include certain logistics assets, (ii) our renewables products asset groups, (iii) our Lubricants & Specialties asset groups, (iv) our Marketing assets and (v) our Midstream asset groups, which is comprised of logistics assets not included in our refinery asset groups. These asset groups represent the lowest level for which independent cash flows can be identified. Our long-lived assets are evaluated for impairment by identifying whether indicators of impairment exist and, if so, assessing whether such long-lived assets are recoverable from estimated future undiscounted cash flows. The actual amount of impairment loss measured, if any, is equal to the amount by which the asset group’s carrying value exceeds its fair value. See Note 11 for additional information regarding goodwill and intangible assets.
Equity Method Investments		Equity Method Investments: We account for investments in which we have a noncontrolling interest, yet have significant influence over the entity, using the equity method of accounting, whereby we record our pro-rata share of earnings of these companies and contributions to and distributions from the joint ventures as adjustments to our investment balance.
Cost Classifications, Policy		Cost Classifications: Costs of products sold include the cost of crude oil, other feedstocks, blendstocks and purchased finished products, inclusive of transportation costs. We purchase crude oil that at times exceeds the supply needs of our refineries. Quantities in excess of our needs are sold at market prices to purchasers of crude oil that are recorded on a gross basis with the sales price recorded as revenues and the corresponding acquisition cost as cost of products sold. Additionally, we enter into buy / sell exchanges of crude oil with certain parties to facilitate the delivery of quantities to certain locations that are netted at cost. Operating expenses include direct costs of labor, maintenance materials and services, utilities and other direct operating costs. Selling, general and administrative expenses include compensation, professional services and other support costs.
Maintenance Cost, Policy		Deferred Maintenance Costs:
Environmental Costs, Policy		Environmental Costs: operating expenses
Commitments and Contingencies, Policy		Contingencies: We are subject to proceedings, lawsuits and other claims related to environmental, labor, product and other matters. We are required to assess the likelihood of any adverse judgments or outcomes to these matters as well as potential ranges of probable losses. We accrue for contingencies when it is probable that a loss has occurred and when the amount of that loss is reasonably estimable. A determination of the amount of reserves required, if any, for these contingencies is made after careful analysis of each individual issue. The required reserves may change in the future due to new developments in each matter or changes in approach such as a change in settlement strategy in dealing with these matters.

Description of Business and P_3

Description of Business and Presentation of Financial Statements (Tables)	12 Months Ended
	Dec. 31, 2023
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of Equity Method Investments	The following table summarizes our recorded investment compared to its share of underlying equity for each of its investee. The differences are being amortized as adjustments to our pro-rata share of earnings in the joint ventures. Balance at December 31, 2023 Underlying Equity Recorded Investment Balance Difference (In thousands) Equity Method Investments Osage Pipe Line Company, LLC $ 1,144 $ 27,135 $ (25,991) Cheyenne Pipeline, LLC 30,508 41,985 (11,477) Cushing Connect Terminal Holdings LLC 48,135 32,474 15,661 Pioneer Investments Corp. 24,188 131,244 (107,056) Saddle Butte Pipeline III, LLC 66,436 33,107 33,329 Total $ 170,411 $ 265,945 $ (95,534) Balance at December 31, 2022 Underlying Equity Recorded Investment Balance Difference (In thousands) Equity Method Investments Osage Pipe Line Company, LLC $ 2,901 $ 29,773 $ (26,872) Cheyenne Pipeline, LLC 27,655 40,019 (12,364) Cushing Connect Terminal Holdings LLC 49,915 34,746 15,169 Pioneer Investments Corp. 23,835 133,182 (109,347) Saddle Butte Pipeline III, LLC 67,349 32,884 34,465 Total $ 171,655 $ 270,604 $ (98,949)

Cushing Connect Joint Venture (

Cushing Connect Joint Venture (Tables)	3 Months Ended	12 Months Ended
Cushing Connect Joint Venture (Tables)	Mar. 31, 2024	Dec. 31, 2023
Equity Method Investments and Joint Ventures [Abstract]
Schedule of Variable Interest Entities	The most significant assets of Cushing Connect and Cushing Connect Pipeline that are available to settle only their obligations, along with their most significant liabilities for which their creditors do not have recourse to our general credit, were: March 31, December 31, (In thousands) Cash and cash equivalents $ 916 $ 1,536 Properties, plants and equipment, at cost 102,979 102,936 Less: accumulated depreciation (8,907) (8,022) Intangibles and other 31,674 32,473	The most significant assets of Cushing Connect and Cushing Connect Pipeline that are available to settle only their obligations, along with their most significant liabilities for which their creditors do not have recourse to our general credit, were: Years Ended December 31, 2023 2022 (In thousands) Cash and cash equivalents 1,536 2,147 Properties, plants and equipment, at cost 102,936 102,635 Less accumulated depreciation (8,022) (4,484) Intangibles and other 32,473 34,746

Revenues (Tables)

Revenues (Tables)	3 Months Ended	12 Months Ended
Revenues (Tables)	Mar. 31, 2024	Dec. 31, 2023
Revenue from Contract with Customer [Abstract]
Schedule of Disaggregated Revenues	Disaggregated revenues were as follows: Three Months Ended 2024 2023 (In thousands) Revenues by type Refined product revenues Transportation fuels (1) $ 4,628,631 $ 4,507,894 Specialty lubricant products (2) 614,221 679,862 Asphalt, fuel oil and other products (3) 483,316 440,339 Total refined product revenues 5,726,168 5,628,095 Excess crude oil revenues (4) 267,096 710,897 Renewable diesel revenues (5) 179,669 202,413 Transportation and logistics services 23,099 26,416 Marketing revenues (6) 775,807 937,385 Other revenues (7) 55,306 59,936 Total sales and other revenues $ 7,027,145 $ 7,565,142 Three Months Ended 2024 2023 (In thousands) Refined product revenues by market United States: Mid-Continent $ 2,215,841 $ 2,007,156 Southwest 975,702 832,702 Rocky Mountains 1,988,491 2,197,827 Northeast 219,347 263,904 Canada 255,772 250,724 Europe, Asia and Latin America 71,015 75,782 Total refined product revenues $ 5,726,168 $ 5,628,095 (1) Transportation fuels revenues are attributable to our Refining segment’s wholesale marketing of gasoline, diesel and jet fuel. (2) Specialty lubricant products consist of base oil, waxes, finished lubricants and other specialty fluids. (3) Revenues from asphalt, fuel oil and other products include amounts attributable to our Refining and Lubricants & Specialties segments of $422.0 million and $61.3 million, respectively, for the three months ended March 31, 2024, and $386.8 million and $53.6 million, respectively, for the three months ended March 31, 2023. (4) Excess crude oil revenues represent sales of purchased crude oil inventory that at times exceeds the supply needs of our refineries. (5) Renewable diesel revenues are attributable to our Renewables segment. (6) Marketing revenues consist primarily of branded gasoline and diesel fuel. (7) Other revenues are principally attributable to our Refining segment.	Disaggregated revenues were as follows: Years Ended December 31, 2023 2022 2021 (In thousands) Revenues by type Refined product revenues Transportation fuels (1) $ 19,867,388 $ 25,895,867 $ 13,414,543 Specialty lubricant products (2) 2,521,025 2,826,206 2,322,242 Asphalt, fuel oil and other products (3) 2,167,049 2,147,710 948,581 Total refined product revenues 24,555,462 30,869,783 16,685,366 Excess crude oil revenues (4) 2,147,466 2,342,288 1,547,696 Renewable diesel revenues (5) 781,309 654,893 — Transportation and logistic services 117,749 109,200 103,646 Marketing revenues (6) 4,146,292 3,911,922 — Other revenues (7) 216,117 316,753 52,434 Total sales and other revenues $ 31,964,395 $ 38,204,839 $ 18,389,142 Years Ended December 31, 2023 2022 2021 (In thousands) Refined product revenues by market United States Mid-Continent $ 9,362,688 $ 13,924,566 $ 9,094,885 Southwest 3,814,142 4,965,298 3,477,562 Rocky Mountains 9,131,345 9,533,476 2,118,619 Northeast 959,239 1,037,771 824,900 Canada 1,022,174 1,063,961 836,317 Europe, Asia and Latin America 265,874 344,711 333,083 Total refined product revenues $ 24,555,462 $ 30,869,783 $ 16,685,366 (1) Transportation fuels revenues are attributable to our Refining segment wholesale marketing of gasoline, diesel and jet fuel. (2) Specialty lubricant products consist of base oil, waxes, finished lubricants and other specialty fluids. (3) Asphalt, fuel oil and other products revenue include revenues attributable to our Refining and Lubricants & Specialties segments o f $1,928.6 million and $238.4 million, res pectively, for the year ended December 31, 2023. For the year ended December 31, 2022 such revenues attributable to our Refining and Lubricants & Specialties were $1,827.3 million and $314.8 million, respectively. For the year ended December 31, 2021 such revenue attributable to our Refining and Lubricants & Specialties segments were $724.3 million and $224.3 million, respectively. (4) Excess crude oil revenues represent sales of purchased crude oil inventory that at times exceeds the supply needs of our refineries. (5) Renewable diesel revenues are attributable to our Renewables segment. (6) Marketing segment revenues consist primarily of branded gasoline and diesel fuel. (7) Other revenues are principally attributable to our Refining segment.
Schedule of Changes to Contract Liabilities	The following table present s changes to our contract liabilities: Three Months Ended March 31, 2024 2023 (In thousands) Balance at January 1 $ 7,533 $ 10,722 Increase 5,693 5,159 Recognized as revenue (6,115) (5,744) Balance at March 31 $ 7,111 $ 10,137	The following table presents changes to contract liabilities: Years Ended December 31, 2023 2022 2021 (In thousands) Balance at January 1 $ 10,722 $ 9,278 $ 6,738 Increase 21,381 32,040 32,301 Recognized as revenue (24,570) (30,596) (29,761) Balance at December 31 $ 7,533 $ 10,722 $ 9,278
Schedules of Aggregate Minimum Volumes Expected to Be Sold Under Long-term Sales Contracts	Aggregate minimum volumes expected to be sold (future performance obligations) under our long-term product sales contracts with customers are as follows: Remainder of 2024 2025 2026 Thereafter Total (In thousands) Refined product sales volumes (barrels) 26,099 27,204 19,003 47,888 120,194 Remainder of 2024 2025 2026 Thereafter Total (In thousands) Midstream operations contractual minimum revenues $ 15,534 $ 11,114 $ 7,656 $ 42,592 $ 76,896	Aggregate minimum volumes expected to be sold (future performance obligations) under our long-term product sales contracts with customers are as follows, which include branded sales volumes assumed upon our acquisition of the Acquired Sinclair Businesses: 2024 2025 2026 Thereafter Total (In thousands) Refined product sales volumes (barrels) 35,563 25,506 17,891 47,240 126,200 l minimum revenues attributable to our third-party contracts as of December 31, 2023 are presented below: 2024 2025 2026 Thereafter Total (In thousands) Midstream operations contractual minimum revenues $ 20,656 $ 11,097 $ 7,656 $ 42,592 $ 82,001

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	3 Months Ended	12 Months Ended
Fair Value Measurements (Tables)	Mar. 31, 2024	Dec. 31, 2023
Fair Value Disclosures [Abstract]
Schedule of Fair Value Measurements of Asset and Liability Instruments	The carrying amounts of derivative instruments and RINs credit obligations at March 31, 2024 and December 31, 2023 were as follows: Fair Value by Input Level Carrying Amount Level 1 Level 2 Level 3 (In thousands) March 31, 2024 Assets: Commodity forward contracts $ 8,564 $ — $ 8,564 $ — Foreign currency forward contracts 1,713 — 1,713 — Total assets $ 10,277 $ — $ 10,277 $ — Liabilities: NYMEX futures contracts $ 9,744 $ 9,744 $ — $ — Commodity price swaps 1,310 — 1,310 — Commodity forward contracts 7,336 — 7,336 — Foreign currency forward contracts 691 — 691 — RINs credit obligations (1) 29,553 — 29,553 — Total liabilities $ 48,634 $ 9,744 $ 38,890 $ — Fair Value by Input Level Carrying Amount Level 1 Level 2 Level 3 (In thousands) December 31, 2023 Assets: NYMEX futures contracts $ 836 $ 836 $ — $ — Commodity forward contracts 2,908 — 2,908 — Total assets $ 3,744 $ 836 $ 2,908 $ — Liabilities: Commodity price swaps $ 7,808 $ — $ 7,808 $ — Commodity forward contracts 1,848 — 1,848 — Foreign currency forward contracts 7,893 — 7,893 — Total liabilities $ 17,549 $ — $ 17,549 $ — (1) Represent obligations for RINs credits for which we did not have sufficient quantities at March 31, 2024 to satisfy our Environmental Protection Agency (“EPA”) regulatory blending requirements.	The carrying amounts of derivative instruments and RINs receivable and credit obligations at December 31, 2023 and 2022 were as follows: Carrying Amount Fair Value by Input Level Level 1 Level 2 Level 3 (In thousands) December 31, 2023 Assets: NYMEX futures contracts $ 836 $ 836 $ — $ — Commodity forward contracts 2,908 — 2,908 — Total assets $ 3,744 $ 836 $ 2,908 $ — Liabilities: Commodity price swaps $ 7,808 $ — $ 7,808 $ — Commodity forward contracts 1,848 — 1,848 — Foreign currency forward contracts 7,893 — 7,893 — Total liabilities $ 17,549 $ — $ 17,549 $ — Carrying Amount Fair Value by Input Level Level 1 Level 2 Level 3 (In thousands) December 31, 2022 Assets: Commodity price swaps $ 342 $ — $ 342 $ — Commodity forward contracts 2,949 — 2,949 — RINs receivable (1) 81,232 — 81,232 — Foreign currency forward contracts 15,359 — 15,359 — Total assets $ 99,882 $ — $ 99,882 $ — Liabilities: NYMEX futures contracts $ 2,750 $ 2,750 $ — $ — Commodity collar contracts 6,275 — 6,275 — Commodity forward contracts 2,987 — 2,987 — RINs credit obligations (1) 81,232 — 81,232 — Total liabilities $ 93,244 $ 2,750 $ 90,494 $ — (1) REH Company was financially responsible for satisfaction of RINs credit obligations for all periods prior to the closing of the Sinclair Transactions. See Note 2 for additional information on RINs credit obligations assumed in the Sinclair Transactions.

Earnings Per Share (Tables)

Earnings Per Share (Tables)	3 Months Ended	12 Months Ended
Earnings Per Share (Tables)	Mar. 31, 2024	Dec. 31, 2023
Earnings Per Share [Abstract]
Schedule Of Earnings Per Share	The following is a reconciliation of the denominators of the basic and diluted per share computations for net income attributable to HF Sinclair stockholders: Three Months Ended 2024 2023 (In thousands, except per share data) Net income attributable to HF Sinclair stockholders $ 314,664 $ 353,266 Participating securities’ share in earnings (1) 1,969 2,925 Net income attributable to common shares $ 312,695 $ 350,341 Average number of shares of common stock outstanding 198,710 195,445 Average number of shares of common stock outstanding assuming dilution 198,710 195,445 Basic earnings per share $ 1.57 $ 1.79 Diluted earnings per share $ 1.57 $ 1.79 (1) Unvested restricted stock unit awards and unvested performance share units that settle in HF Sinclair common stock represent participating securities because they participate in nonforfeitable dividends or distributions with the common stockholders of HF Sinclair. Participating earnings represent the distributed and undistributed earnings of HF Sinclair attributable to the participating securities. Unvested restricted stock unit awards and performance share units do not participate in undistributed net losses as they are not contractually obligated to do so.	The following is a reconciliation of the denominators of the basic and diluted per share computations for net income attributable to HF Sinclair stockholders: Years Ended December 31, 2023 2022 2021 (In thousands, except per share data) Net income attributable to HF Sinclair stockholders $ 1,589,666 $ 2,922,668 $ 558,324 Participating securities’ share in earnings (1) 14,045 29,465 7,465 Net income attributable to common shares $ 1,575,621 $ 2,893,203 $ 550,859 Average number of shares of common stock outstanding 190,035 202,566 162,569 Average number of shares of common stock outstanding assuming dilution 190,035 202,566 162,569 Basic earnings per share $ 8.29 $ 14.28 $ 3.39 Diluted earnings per share $ 8.29 $ 14.28 $ 3.39 (1) Unvested restricted stock unit awards and unvested performance share units that settle in HF Sinclair common stock represent participating securities because they participate in nonforfeitable dividends or distributions with the common stockholders of HF Sinclair. Participating earnings represent the distributed and undistributed earnings of HF Sinclair attributable to the participating securities. Unvested restricted stock unit awards and performance share units do not participate in undistributed net losses as they are not contractually obligated to do so.

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	3 Months Ended	12 Months Ended
Stock-Based Compensation (Tables)	Mar. 31, 2024	Dec. 31, 2023
Share-Based Payment Arrangement [Abstract]
Schedule Of Restricted Stock Activity	A summary of restricted stock units and performance share units activity during the three months ended March 31, 2024, is presented below: Restricted Stock Units Performance Share Units Outstanding at January 1, 2024 1,102,755 485,531 Granted (1) 2,020 — Vested (153,811) (1,859) Forfeited (186,799) (49,060) Outstanding at March 31, 2024 764,165 434,612 (1) Weighted average grant date fair value per unit $ 59.52 $ —	A summary of restricted stock unit activity during the year ended December 31, 2023 is presented below: Restricted Stock Units Grants Weighted Average Grant Date Fair Value Outstanding at January 1, 2023 1,055,875 $ 39.46 Granted 529,559 $ 52.59 Vested (641,944) $ 33.17 Forfeited (65,952) $ 38.55 Converted from performance share units 225,217 $ 45.46 Outstanding at December 31, 2023 1,102,755 $ 50.71
Schedule Of Performance Share Activity	A summary of restricted stock units and performance share units activity during the three months ended March 31, 2024, is presented below: Restricted Stock Units Performance Share Units Outstanding at January 1, 2024 1,102,755 485,531 Granted (1) 2,020 — Vested (153,811) (1,859) Forfeited (186,799) (49,060) Outstanding at March 31, 2024 764,165 434,612 (1) Weighted average grant date fair value per unit $ 59.52 $ —	A summary of performance share unit activity and changes during the year ended December 31, 2023 is presented below: Performance Share Units Grants Weighted Average Grant Date Fair Value Outstanding at January 1, 2023 771,197 $ 41.78 Granted 263,881 $ 67.73 Vested (298,978) $ 24.47 Forfeited (25,352) $ 40.76 Converted to restricted stock units (225,217) $ 52.44 Outstanding at December 31, 2023 485,531 $ 61.66
Share-Based Payment Arrangement, Expensed and Capitalized, Amount		The stock-based compensation expense and associated tax benefit were as follows: Years Ended December 31, 2023 2022 2021 (In thousands) Compensation expense: Restricted stock units $ 30,067 $ 27,264 $ 29,453 Performance stock units 12,145 8,683 12,591 Total compensation expense $ 42,212 $ 35,947 $ 42,044 Tax benefit recognized on compensation expense $ 10,203 $ 8,918 $ 10,545

Inventories (Tables)

Inventories (Tables)	3 Months Ended	12 Months Ended
Inventories (Tables)	Mar. 31, 2024	Dec. 31, 2023
Inventory Disclosure [Abstract]
Schedule of Inventory Components	Inventories consist of the following components: March 31, December 31, (In thousands) Crude oil $ 798,070 $ 858,411 Other raw materials and unfinished products (1) 743,302 683,066 Finished products (2) 1,438,867 1,435,817 Lower of cost or market reserve (112,200) (331,570) Process chemicals (3) 38,731 50,917 Repair and maintenance supplies and other (4) 224,115 225,190 Total inventory $ 3,130,885 $ 2,921,831 (1) Other raw materials and unfinished products include feedstocks and blendstocks, other than crude. (2) Finished products include gasolines, jet fuels, diesels, renewable diesels, lubricants, asphalts, LPG’s and residual fuels. (3) Process chemicals include additives and other chemicals. (4) Includes RINs.	Inventories consist of the following components: December 31, 2023 2022 (In thousands) Crude oil $ 858,411 $ 818,737 Other raw materials and unfinished products (1) 683,066 842,855 Finished products (2) 1,435,817 1,252,984 Lower of cost or market reserve (331,570) (61,151) Process chemicals (3) 50,917 53,900 Repairs and maintenance supplies and other (4) 225,190 307,203 Total inventory $ 2,921,831 $ 3,214,528 (1) Other raw materials and unfinished products include feedstocks and blendstocks, other than crude. (2) Finished products include gasolines, jet fuels, diesels, renewable diesels, lubricants, asphalts, LPG’s and residual fuels. (3) Process chemicals include additives and other chemicals. (4) Includes RINs.

Debt (Tables)

Debt (Tables)	3 Months Ended	12 Months Ended
Debt (Tables)	Mar. 31, 2024	Dec. 31, 2023
Debt Disclosure [Abstract]
Schedule of Long-Term Debt Carrying Amounts	The carrying amounts of long-term debt are as follows: March 31, December 31, (In thousands) HollyFrontier 5.875% Senior Notes $ 202,900 $ 202,900 4.500% Senior Notes 74,966 74,966 277,866 277,866 HF Sinclair 5.875% Senior Notes 797,100 797,100 4.500% Senior Notes 325,034 325,034 5.000% Senior Notes 498,879 498,879 6.375% Senior Notes 399,875 399,875 2,020,888 2,020,888 HEP 5.000% Senior Notes 1,121 1,121 6.375% Senior Notes 125 125 1,246 1,246 HEP Credit Agreement 394,000 455,500 Unamortized discount and debt issuance costs (15,355) (16,417) Total long-term debt, net $ 2,678,645 $ 2,739,083 The fair values of the senior notes are as follows: March 31, December 31, (In thousands) HF Sinclair, HollyFrontier and HEP Senior Notes $ 2,268,035 $ 2,271,856	The carrying amounts of outstanding debt are as follows: December 31, 2023 2022 (In thousands) HollyFrontier 2.625% Senior Notes $ — $ 59,637 5.875% Senior Notes 202,900 202,900 4.500% Senior Notes 74,966 74,966 277,866 337,503 HF Sinclair 2.625% Senior Notes $ — $ 248,190 5.875% Senior Notes 797,100 797,100 4.500% Senior Notes 325,034 325,034 5.000% Senior Notes 498,879 — 6.375% Senior Notes 399,875 — 2,020,888 1,370,324 HEP 5.000% Senior Notes 1,121 500,000 6.375% Senior Notes 125 400,000 1,246 900,000 HEP Credit Agreement 455,500 668,000 Less current debt (1) — (306,959) Unamortized discount and debt issuance costs (1) (16,417) (20,355) Total long-term debt (2) $ 2,739,083 $ 2,948,513 (1) The 2.625% HollyFrontier Senior Notes and HF Sinclair 2.625% Senior Notes, inclusive of unamortized discount and debt issuance costs of $0.9 million at December 31, 2022 were due October 2023 and were classified as current debt on our consolidated balance sheets. (2) At December 31, 2022, total HF Sinclair standalone long-term debt, which excluded HEP long-term debt, was $1.4 billion. The fair values of the senior notes are as follows: December 31, 2023 2022 (In thousands) HollyFrontier and HF Sinclair Senior Notes $ 2,270,668 $ 1,655,726 HEP Senior Notes $ 1,188 $ 852,658
Schedule of Maturities of Long-Term Debt		Principal maturities of outstanding debt as of December 31, 2023 are as follows: Years Ending December 31, (In thousands) 2024 $ — 2025 455,500 2026 1,000,000 2027 400,000 2028 500,000 Thereafter 400,000 Total $ 2,755,500

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Tables)	3 Months Ended	12 Months Ended
Derivative Instruments and Hedging Activities (Tables)	Mar. 31, 2024	Dec. 31, 2023
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Net Unrealized Gain (Loss) Recognized in OCI and Gain (Loss) Reclassified into Earnings	The following table presents the pre-tax effect on other comprehensive income (“OCI”) and earnings due to fair value adjustments and maturities of hedging instruments under hedge accounting: Net Unrealized Gain Loss Reclassified Derivatives Designated as Cash Flow Hedging Instruments Three Months Ended Income Statement Location Three Months Ended 2024 2023 2024 2023 (In thousands) (In thousands) Commodity contracts $ — $ 271 Sales and other revenues $ (4,287) $ (1) Total $ — $ 271 $ (4,287) $ (1)	The following table presents the pre-tax effect on other comprehensive income (“OCI”) and earnings due to fair value adjustments and maturities of hedging instruments under hedge accounting: Net Unrealized Gain Recognized in OCI Gain (Loss) Reclassified into Earnings Derivatives Designated as Cash Flow Hedging Instruments Years Ended December 31, Income Statement Location Years Ended December 31, 2023 2022 2021 2023 2022 2021 (In thousands) Commodity contracts $ — $ 326 $ 31 Sales and other revenues $ (3,236) $ (5,288) $ (19,239) Operating expenses — — 1,660 Total $ — $ 326 $ 31 $ (3,236) $ (5,288) $ (17,579)
Schedule of Gain (Loss) Recognized in Earnings	The following table presents the pre-tax effect on income due to maturities and fair value adjustments of our economic hedges: Gain (Loss) Recognized in Earnings Derivatives Not Designated as Hedging Instruments Income Statement Location Three Months Ended 2024 2023 (In thousands) Commodity contracts Cost of products sold $ (20,665) $ 6,748 Operating expenses (213) (14,058) Interest expense 2,763 2,406 Foreign currency contracts Gain on foreign currency transactions 10,131 114 Total $ (7,984) $ (4,790)	The following table presents the pre-tax effect on earnings due to maturities and fair value adjustments of our economic hedges: Gain (Loss) Recognized in Earnings Derivatives Not Designated as Hedging Instruments Years Ended December 31, Income Statement Location 2023 2022 2021 (In thousands) Commodity contracts Cost of products sold $ 10,162 $ (17,189) $ (22,909) Operating expenses (20,783) (13,780) — Interest expense 2,050 (4,420) 11,816 Foreign currency contracts Gain (loss) on foreign currency transactions (7,414) 27,826 (4,013) Total $ (15,985) $ (7,563) $ (15,106)
Schedule of Notional Amounts of Outstanding Derivatives Serving as Economic Hedges	As of March 31, 2024, we have the following notional contract volumes related to outstanding derivative instruments: Notional Contract Volumes by Year of Maturity Derivatives Not Designated as Hedging Instruments Total Outstanding Notional 2024 2025 Unit of Measure NYMEX futures (WTI) - short 2,575,000 2,575,000 — Barrels Forward gasoline and diesel contracts - long 1,190,000 1,190,000 — Barrels Foreign currency forward contracts 386,671,810 281,628,809 105,043,001 U.S. dollar Forward commodity contracts (platinum) 36,969 14,549 22,420 Troy ounces Natural gas price swaps (basis spread) - long 3,300,000 3,300,000 — MMBTU	As of December 31, 2023, we have the following notional contract volumes related to outstanding derivative instruments (all maturing in 2024): Total Outstanding Notional Unit of Measure Derivatives not designated as hedging instruments: NYMEX futures (WTI) - short 640,000 Barrels Forward gasoline contracts - long 800,000 Barrels Foreign currency forward contracts 387,613,367 U. S. dollar Forward commodity contracts (platinum) 36,969 Troy ounces Natural gas price swaps (basis spread) - long 6,667,000 MMBTU
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	The following tables present the fair value and balance sheet locations of our outstanding derivative instruments. These amounts are presented on a gross basis with offsetting balances that reconcile to a net asset or liability position in our consolidated balance sheets. We present on a net basis to reflect the net settlement of these positions in accordance with provisions of our master netting arrangements. Derivatives in Net Asset Position Derivatives in Net Liability Position Gross Assets Gross Liabilities Offset in Balance Sheet Net Assets Recognized in Balance Sheet Gross Liabilities Gross Assets Offset in Balance Sheet Net Liabilities Recognized in Balance Sheet (In thousands) March 31, 2024 Derivatives not designated as cash flow hedging instruments: NYMEX futures contracts $ — $ — $ — $ 9,744 $ — $ 9,744 Commodity price swap contracts — — — 1,310 — 1,310 Commodity forward contracts 8,564 — 8,564 7,336 — 7,336 Foreign currency forward contracts 1,713 — 1,713 1,771 (1,080) 691 $ 10,277 $ — $ 10,277 $ 20,161 $ (1,080) $ 19,081 Total net balance $ 10,277 $ 19,081 Balance sheet classification: Prepayment and other $ 10,277 Accrued liabilities $ 19,081 Derivatives in Net Asset Position Derivatives in Net Liability Position Gross Assets Gross Liabilities Offset in Balance Sheet Net Assets Recognized in Balance Sheet Gross Liabilities Gross Assets Offset in Balance Sheet Net Liabilities Recognized in Balance Sheet (In thousands) December 31, 2023 Derivatives not designated as cash flow hedging instruments: NYMEX futures contracts $ 836 $ — $ 836 $ — $ — $ — Commodity price swap contracts — — — 7,808 — 7,808 Commodity forward contracts 2,908 — 2,908 1,848 — 1,848 Foreign currency forward contracts — — — 7,893 — 7,893 $ 3,744 $ — $ 3,744 $ 17,549 $ — $ 17,549 Total net balance $ 3,744 $ 17,549 Balance sheet classification: Prepayment and other $ 3,744 Accrued liabilities $ 17,549	The following table presents the fair value and balance sheet locations of our outstanding derivative instruments. These amounts are presented on a gross basis with offsetting balances that reconcile to a net asset or liability position on our consolidated balance sheets. We present on a net basis to reflect the net settlement of these positions in accordance with provisions of our master netting arrangements. Derivatives in Net Asset Position Derivatives in Net Liability Position Gross Assets Gross Liabilities Offset in Balance Sheet Net Assets Recognized in Balance Sheet Gross Liabilities Gross Assets Offset in Balance Sheet Net Liabilities Recognized in Balance Sheet (In thousands) December 31, 2023 Derivatives not designated as cash flow hedging instruments: NYMEX futures contracts $ 836 $ — $ 836 $ — $ — $ — Commodity price swap contracts — — — 7,808 — 7,808 Commodity forward contracts 2,908 — 2,908 1,848 — 1,848 Foreign currency forward contracts — — — 7,893 — 7,893 $ 3,744 $ — $ 3,744 $ 17,549 $ — $ 17,549 Total net balance $ 3,744 $ 17,549 Balance sheet classification: Prepayment and other $ 3,744 Accrued liabilities $ 17,549 Derivatives in Net Asset Position Derivatives in Net Liability Position Gross Assets Gross Liabilities Offset in Balance Sheet Net Assets Recognized in Balance Sheet Gross Liabilities Gross Assets Offset in Balance Sheet Net Liabilities Recognized in Balance Sheet (In thousands) December 31, 2022 Derivatives not designated as cash flow hedging instruments: NYMEX futures contracts $ — $ — $ — $ 2,750 $ — $ 2,750 Commodity price swap contracts 342 — 342 — — — Commodity collar contracts — — — 6,275 — 6,275 Commodity forward contracts 2,949 — 2,949 2,987 — 2,987 Foreign currency forward contracts 15,359 — 15,359 — — — $ 18,650 $ — $ 18,650 $ 12,012 $ — $ 12,012 Total net balance $ 18,650 $ 12,012 Balance sheet classification: Prepayments and other $ 18,650 Accrued liabilities $ 12,012

Stockholders' Equity (Tables)

Stockholders' Equity (Tables)	3 Months Ended	12 Months Ended
Stockholders' Equity (Tables)	Mar. 31, 2024	Dec. 31, 2023
Equity [Abstract]
Schedule of Purchases of Shares under Share Repurchase Program	The following table presents the total open market and privately negotiated purchases of shares under our share repurchase programs for the three months ended March 31, 2024 and 2023: Three Months Ended 2024 2023 Number of shares repurchased (1) 2,930,742 4,793,857 Cash paid for shares repurchased (in thousands) $ 166,128 $ 240,323 (1) During the three months ended March 31, 2024, 1,516,326 shares were repurchased for $85.0 million, pursuant to privately negotiated repurchases from REH Company. During the three months ended March 31, 2023, 1,969,279 shares were repurchased for $100.0 million pursuant to privately negotiated repurchases from REH Company.	The following table presents total open market and privately negotiated purchases of shares under our share repurchase programs for the years ended December 31, 2023 and 2022. Years Ended December 31, 2023 2022 Number of shares repurchased (1) 18,779,880 25,716,042 Cash paid for shares repurchased (in thousands) $ 974,474 $ 1,313,006 (1) During the years ended December 31, 2023 and 2022, 15,515,302 and 14,407,274 shares, respectively, were repurchased for $810.6 million and $750.0 million, respectively, pursuant to privately negotiated repurchases from REH Company.

Other Comprehensive Income (L_2

Other Comprehensive Income (Loss) (Tables)	3 Months Ended	12 Months Ended
Other Comprehensive Income (Loss) (Tables)	Mar. 31, 2024	Dec. 31, 2023
Other Comprehensive Income (Loss), before Tax [Abstract]
Schedule of Components and Allocated Tax Effects of OCI	The components and allocated tax effects of other comprehensive income (loss) are as follows: Before-Tax Tax Expense After-Tax (In thousands) Three Months Ended March 31, 2024 Net change in foreign currency translation adjustment $ (12,606) $ (2,643) $ (9,963) Net change in pension and other post-retirement benefit obligations (699) (169) (530) Other comprehensive loss attributable to HF Sinclair stockholders $ (13,305) $ (2,812) $ (10,493) Three Months Ended March 31, 2023 Net change in foreign currency translation adjustment $ 2,926 $ 614 $ 2,312 Net unrealized gain on hedging instruments 271 66 205 Net change in pension and other post-retirement benefit obligations (960) (233) (727) Other comprehensive income attributable to HF Sinclair stockholders $ 2,237 $ 447 $ 1,790	The components and allocated tax effects of other comprehensive income (loss) are as fo llows: Before-Tax Tax Expense After-Tax (In thousands) Year Ended December 31, 2023 Net change in foreign currency translation adjustment $ 13,161 $ 2,760 $ 10,401 Net change in pension and other post-retirement benefit obligations 101 273 (172) Other comprehensive income attributable to HF Sinclair stockholders $ 13,262 $ 3,033 $ 10,229 Year Ended December 31, 2022 Net change in foreign currency translation adjustment $ (32,383) $ (6,817) $ (25,566) Net unrealized gain on hedging instruments 326 67 259 Net change in pension and other post-retirement benefit obligations 789 166 623 Other comprehensive loss attributable to HF Sinclair stockholders $ (31,268) $ (6,584) $ (24,684) Year Ended December 31, 2021 Net change in foreign currency translation adjustment $ (13,336) $ (2,793) $ (10,543) Net unrealized gain on hedging instruments 31 8 23 Net change in pension and other post-retirement benefit obligations (457) (186) (271) Other comprehensive loss attributable to HF Sinclair stockholders $ (13,762) $ (2,971) $ (10,791)
Schedule of Income Statement Line Items Effects Out of AOCI	The following table presents the statements of income line item effects for reclassifications out of accumulated other comprehensive income (“AOCI”): AOCI Component Gain (Loss) Reclassified From AOCI Statement of Income Line Item Three Months Ended March 31, 2024 2023 (In thousands) Hedging instruments: Commodity price swaps $ (4,287) $ (1) Sales and other revenues (1,039) — Income tax benefit (3,248) (1) Net of tax Other post-retirement benefit obligations: Pension obligations (217) 45 Gain on sale of assets and other (53) 11 Income tax expense (benefit) (164) 34 Net of tax Post-retirement healthcare obligations 922 918 Gain on sale of assets and other 223 223 Income tax expense 699 695 Net of tax Retirement restoration plan (6) (3) Gain on sale of assets and other (1) (1) Income tax benefit (5) (2) Net of tax Total reclassifications for the period $ (2,718) $ 726	The following table presents the statement of income line item effects for reclassifications out of accumulated other comprehensive income (“AOCI”): AOCI Component Gain (Loss) Reclassified From AOCI Income Statement Line Item Years Ended December 31, 2023 2022 2021 (In thousands) Hedging instruments: Commodity price swaps $ (3,236) $ (5,288) $ (19,239) Sales and other revenues — — 1,660 Operating expenses (3,236) (5,288) (17,579) (784) (1,282) (4,430) Income tax expense (benefit) (2,452) (4,006) (13,149) Net of tax Other post-retirement benefit obligations: Pension obligations (1,378) 208 407 Other, net (334) 50 103 Income tax expense (benefit) (1,044) 158 304 Net of tax Post-retirement healthcare obligations 3,859 3,440 3,328 Other, net 935 834 839 Income tax expense (benefit) 2,924 2,606 2,489 Net of tax Retirement restoration plan (11) (39) (39) Other, net (3) (9) (10) Income tax expense (benefit) (8) (30) (29) Net of tax Total reclassifications for the period $ (580) $ (1,272) $ (10,385)
Schedule of AOCI in Equity	Accumulated other comprehensive loss in the equity section of our consolidated balance sheets includes: March 31, December 31, (In thousands) Foreign currency translation adjustment $ (32,988) $ (23,026) Unrealized loss on pension obligations 836 619 Unrealized gain on post-retirement benefit obligations 9,875 10,623 Accumulated other comprehensive loss $ (22,277) $ (11,784)	Accumulated other comprehensive loss in the equity section of our consolidated balance sheets includes: Years Ended December 31, 2023 2022 (In thousands) Foreign currency translation adjustment $ (23,026) $ (33,427) Unrealized gain (loss) on pension obligations 619 (2,661) Unrealized gain on post-retirement benefit obligations 10,623 14,075 Accumulated other comprehensive loss $ (11,784) $ (22,013)

Contingencies (Tables)

Contingencies (Tables)	12 Months Ended
Contingencies (Tables)	Dec. 31, 2023
Commitments and Contingencies Disclosure [Abstract]
Schedule of Future Minimum Transportation and Storage Fees Under Agreement	At December 31, 2023 , the minimum future transportation and storage fees under transportation agreements having terms in excess of one year are as follows: (In thousands) 2024 $ 237,534 2025 241,403 2026 203,316 2027 203,484 2028 207,742 Thereafter 1,079,956 Total $ 2,173,435

Segment Information (Tables)

Segment Information (Tables)	3 Months Ended	12 Months Ended
Segment Information (Tables)	Mar. 31, 2024	Dec. 31, 2023
Segment Reporting [Abstract]
Schedule Of Segment Reporting Information	Refining Renewables Marketing Lubricants & Specialties Midstream Corporate, Other Consolidated (In thousands) Three Months Ended March 31, 2024 Sales and other revenues: Revenues from external customers $ 5,373,025 $ 179,669 $ 775,807 $ 675,545 $ 23,099 $ — $ 7,027,145 Intersegment revenues and other (1) 831,220 59,890 — 2,442 131,916 (1,025,468) — $ 6,204,245 $ 239,559 $ 775,807 $ 677,987 $ 155,015 $ (1,025,468) $ 7,027,145 Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment) $ 5,474,522 $ 230,273 $ 752,530 $ 492,846 $ — $ (1,023,671) $ 5,926,500 Lower of cost or market inventory valuation adjustment $ (220,558) $ 1,188 $ — $ — $ — $ — $ (219,370) Operating expenses $ 472,086 $ 26,461 $ — $ 64,000 $ 45,518 $ (953) $ 607,112 Selling, general and administrative expenses $ 48,717 $ 1,402 $ 7,756 $ 34,568 $ 3,929 $ 7,002 $ 103,374 Depreciation and amortization $ 117,370 $ 20,272 $ 6,303 $ 22,511 $ 20,120 $ 12,153 $ 198,729 Income (loss) from operations $ 312,108 $ (40,037) $ 9,218 $ 64,062 $ 85,448 $ (19,999) $ 410,800 Earnings (loss) of equity method investments $ — $ — $ — $ — $ 7,388 $ (42) $ 7,346 Capital expenditures $ 55,025 $ 2,650 $ 7,531 $ 5,311 $ 8,106 $ 10,485 $ 89,108 Three Months Ended March 31, 2023 Sales and other revenues: Revenues from external customers $ 5,665,214 $ 202,413 $ 937,385 $ 733,714 $ 26,416 $ — $ 7,565,142 Intersegment revenues and other (1) 1,053,401 95,603 — 5,796 109,516 (1,264,316) — $ 6,718,615 $ 298,016 $ 937,385 $ 739,510 $ 135,932 $ (1,264,316) $ 7,565,142 Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment) $ 5,641,131 $ 262,738 $ 924,049 $ 538,860 $ — $ (1,262,721) $ 6,104,057 Lower of cost or market inventory valuation adjustment $ — $ 47,597 $ — $ — $ — $ — $ 47,597 Operating expenses $ 501,759 $ 31,371 $ — $ 63,593 $ 41,679 $ 981 $ 639,383 Selling, general and administrative expenses $ 39,078 $ 915 $ 6,963 $ 39,264 $ 4,635 $ 5,058 $ 95,913 Depreciation and amortization $ 100,083 $ 19,974 $ 5,871 $ 19,368 $ 19,762 $ 8,925 $ 173,983 Income (loss) from operations $ 436,564 $ (64,579) $ 502 $ 78,425 $ 69,856 $ (16,559) $ 504,209 Earnings of equity method investments $ — $ — $ — $ — $ 3,882 $ — $ 3,882 Capital expenditures $ 67,774 $ 4,844 $ 5,255 $ 8,649 $ 7,614 $ 5,933 $ 100,069 (1) Includes income earned by certain of our subsidiaries in the Midstream segment related to intercompany transportation agreements with certain of our subsidiaries in the Refining and Lubricants & Specialties segments that represent leases. These transactions eliminate in consolidation.	The following is a summary of the financial information of our reportable segments reconciled to the amounts reported in the consolidated financial statements. Refining Renewables Marketing Lubricants & Specialties Midstream Corporate, Other and Eliminations Consolidated (In thousands) Year Ended December 31, 2023 Sales and other revenues: Revenues from external customers $ 24,156,278 $ 781,309 $ 4,146,292 $ 2,762,767 $ 117,749 $ — $ 31,964,395 Intersegment revenues and other (1) 4,516,326 407,681 — 12,566 466,398 (5,402,971) — $ 28,672,604 $ 1,188,990 $ 4,146,292 $ 2,775,333 $ 584,147 $ (5,402,971) $ 31,964,395 Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment) $ 24,042,807 $ 1,080,919 $ 4,050,759 $ 2,009,281 $ — $ (5,399,317) $ 25,784,449 Lower of cost or market inventory valuation adjustment $ 220,558 $ 49,861 $ — $ — $ — $ — $ 270,419 Operating expenses $ 1,879,656 $ 109,056 $ — $ 258,578 $ 188,625 $ 2,233 $ 2,438,148 Selling, general and administrative expenses $ 199,547 $ 5,117 $ 34,413 $ 164,311 $ 26,453 $ 68,399 $ 498,240 Depreciation and amortization $ 460,962 $ 77,100 $ 24,599 $ 84,928 $ 82,158 $ 40,826 $ 770,573 Income (loss) from operations $ 1,869,074 $ (133,063) $ 36,521 $ 258,235 $ 286,911 $ (115,112) $ 2,202,566 Earnings of equity method investments $ — $ — $ — $ — $ 17,531 $ (162) $ 17,369 Capital expenditures $ 223,495 $ 18,154 $ 27,630 $ 37,431 $ 31,692 $ 47,011 $ 385,413 Refining Renewables Marketing Lubricants & Specialties Midstream Corporate, Other and Eliminations Consolidated (In thousands) Year Ended December 31, 2022 Sales and other revenues: Revenues from external customers $ 30,379,696 $ 654,893 $ 3,911,922 $ 3,149,128 $ 109,200 $ — $ 38,204,839 Intersegment revenues and other (1) 4,033,213 360,606 — 9,472 430,547 (4,833,838) — $ 34,412,909 $ 1,015,499 $ 3,911,922 $ 3,158,600 $ 539,747 $ (4,833,838) $ 38,204,839 Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment) $ 28,350,823 $ 974,167 $ 3,845,625 $ 2,339,031 $ — $ (4,829,633) $ 30,680,013 Lower of cost or market inventory valuation adjustment $ — $ 52,412 — $ — $ — $ — $ 52,412 Operating expenses $ 1,761,445 $ 111,974 — $ 277,522 $ 170,891 $ 13,061 $ 2,334,893 Selling, general and administrative expenses $ 146,660 $ 3,769 $ 2,954 $ 168,207 $ 17,003 $ 87,892 $ 426,485 Depreciation and amortization $ 397,069 $ 52,621 $ 17,819 $ 81,281 $ 76,768 $ 31,229 $ 656,787 Income (loss) from operations $ 3,756,912 $ (179,444) $ 45,524 $ 292,559 $ 275,085 $ (136,387) $ 4,054,249 Loss of equity method investments $ — $ — $ — $ — $ (260) $ — $ (260) Capital expenditures $ 168,173 $ 225,274 $ 9,275 $ 34,887 $ 33,071 $ 53,327 $ 524,007 Refining Renewables Lubricants & Specialties Midstream Corporate, Other and Eliminations Consolidated (In thousands) Year Ended December 31, 2021 Sales and other revenues: Revenues from external customers $ 15,734,870 $ — $ 2,550,624 $ 103,646 $ 2 $ 18,389,142 Intersegment revenues and other (1) 623,688 — 9,988 327,021 (960,697) — $ 16,358,558 $ — $ 2,560,612 $ 430,667 $ (960,695) $ 18,389,142 Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment) $ 14,691,246 $ — $ 1,821,677 $ — $ (945,871) $ 15,567,052 Lower of cost or market inventory valuation adjustment $ (318,353) $ 8,739 $ — $ — $ (509) $ (310,123) Operating expenses $ 1,038,300 $ 55,353 $ 252,456 $ 133,530 $ 37,839 $ 1,517,478 Selling, general and administrative expenses $ 127,563 $ — $ 170,155 $ 12,637 $ 51,655 $ 362,010 Depreciation and amortization $ 325,845 $ 1,672 $ 77,601 $ 73,046 $ 25,375 $ 503,539 Income (loss) from operations $ 493,957 $ (65,764) $ 238,723 $ 211,454 $ (129,184) $ 749,186 Earnings of equity method investments $ — $ — $ — $ 12,432 $ — $ 12,432 Capital expenditures $ 162,670 $ 510,836 $ 30,878 $ 86,097 $ 22,928 $ 813,409 (1) Includes income earned by certain of our subsidiaries in the Midstream segment related to intercompany transportation agreements with certain of our subsidiaries in the Refining and Lubricants & Specialties segments that represent leases. These transactions eliminate in consolidation.

Acquisitions (Tables)

Acquisitions (Tables)	12 Months Ended
Acquisitions (Tables)	Dec. 31, 2023
Business Combination and Asset Acquisition [Abstract]
Schedule of Purchase Price Consideration and Allocation	The following tables present the purchase consideration and final purchase price allocation of the assets acquired and liabilities assumed on March 14, 2022: Purchase Consideration (in thousands except for per share amounts) Shares of HF Sinclair common stock issued 60,230 Closing price per share of HFC common stock (1) $ 35.68 Purchase consideration paid in HF Sinclair common stock 2,149,008 Shares of HEP common units issued to REH Company 21,000 Closing price per share of HEP common units (2) $ 16.62 Purchase consideration paid in HEP common units 349,020 Total equity consideration 2,498,028 Cash consideration paid by HEP 328,955 Cash consideration received by HF Sinclair (77,507) Total cash consideration 251,448 Total purchase consideration $ 2,749,476 (1) Based on the HollyFrontier closing stock price on March 11, 2022. (2) Based on the HEP closing unit price on March 11, 2022.
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	(In thousands) Assets Acquired Accounts receivable $ 467,530 Inventories: Crude oil and refined products 906,461 Inventories: Materials, supplies and other 39,350 Properties, plants and equipment 1,242,549 Operating lease right-of-use assets 4,585 Other assets: Intangibles and other 495,621 Total assets acquired $ 3,156,096 Liabilities Assumed Accounts payable $ 564,385 Operating lease liabilities 1,030 Accrued liabilities 84,298 Noncurrent operating lease liabilities 3,554 Deferred income taxes 351,189 Other long-term liabilities 88,098 Total liabilities assumed $ 1,092,554 Net assets acquired $ 2,063,542 Goodwill $ 685,934

Leases (Tables)

Leases (Tables)	12 Months Ended
Leases (Tables)	Dec. 31, 2023
Leases [Abstract]
Schedule of Supplemental Balance Sheet Information	The following table presents the amounts and balance sheet locations of our operating and financing leases recorded on our consolidated balance sheets. December 31, 2023 2022 (In thousands) Operating leases: Operating lease right-of-use assets $ 348,006 $ 351,068 Operating lease liabilities 106,973 109,926 Noncurrent operating lease liabilities 249,479 254,215 Total operating lease liabilities $ 356,452 $ 364,141 Finance leases: Properties, plants and equipment, at cost $ 108,746 $ 81,454 Accumulated amortization (25,271) (21,434) Properties, plants and equipment, net $ 83,475 $ 60,020 Accrued liabilities $ 10,842 $ 10,722 Other long-term liabilities 74,860 50,361 Total finance lease liabilities $ 85,702 $ 61,083
Schedule of Components of Lease Expense and Supplemental Cash Flow Information	Supplemental balance sheet information related to our leases was as follows: December 31, 2023 2022 Weighted average remaining lease term (in years) Operating leases 7.9 7.2 Finance leases 8.7 7.8 Weighted average discount rate Operating leases 5.0 % 4.2 % Finance leases 5.8 % 4.2 % The components of lease expense were as follows: Years Ended December 31, 2023 2022 2021 (In thousands) Operating lease expense $ 120,552 $ 116,769 $ 117,292 Finance lease expense: Amortization of right-of-use assets 13,007 13,003 4,295 Interest on lease liabilities 3,156 2,593 733 Variable lease cost 12,968 4,448 3,645 Total lease expense $ 149,683 $ 136,813 $ 125,965 Supplemental cash flow information related to leases was as follows: Years Ended December 31, 2023 2022 2021 (In thousands) Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 127,923 $ 126,048 $ 129,577 Operating cash flows from finance leases $ 3,156 $ 2,593 $ 733 Financing cash flows from finance leases $ 11,923 $ 11,713 $ 3,990 Right-of-use assets obtained in exchange for lease obligations: Operating leases $ 103,352 $ 61,403 $ 147,718 Finance leases $ 38,061 $ 6,149 $ 64,334
Schedule of Operating and Finance Lease Maturities	As of December 31, 2023, minimum future lease payments of our operating and finance lease obligations were as follows: Operating Finance (In thousands) 2024 $ 118,006 $ 15,375 2025 65,436 13,650 2026 50,145 12,537 2027 31,644 11,442 2028 24,398 10,766 Thereafter 163,651 46,869 Future minimum lease payments 453,280 110,639 Less: imputed interest 96,828 24,937 Total lease obligations 356,452 85,702 Less: current obligations 106,973 10,842 Long-term lease obligations $ 249,479 $ 74,860
Schedule of Lease Income	Lease income recognized was as follows: Years Ended December 31, 2023 2022 2021 (In thousands) Operating lease revenues $ 16,879 $ 14,346 $ 15,281 Sales-type lease interest income $ 1,634 $ 2,515 $ 2,545 Lease revenues relating to variable lease payments not included in measurement of the sales-type lease receivable $ 1,325 $ 1,782 $ 2,162
Schedule of Minimum Undiscounted Lease Payments	Annual minimum undiscounted lease payments in which we are a lessor to third-party contracts as of December 31, 2023 were as follows: Operating Sales-type (In thousands) 2024 $ 12,994 $ 2,170 2025 3,441 2,170 2026 — 2,170 2027 — 2,170 2028 — 2,170 Thereafter — 13,560 Total lease payment receipts $ 16,435 24,410 Less: imputed interest (15,945) 8,465 Unguaranteed residual assets at end of leases 25,180 Net investment in leases $ 33,645
Schedule of Net Investments in Operating Leases	Net investment in sales-type leases recorded on our consolidated balance sheets was composed of the following: December 31, 2023 December 31, 2022 (In thousands) Lease receivables $ 18,830 $ 23,797 Unguaranteed residual assets 14,815 10,383 Net investment in leases $ 33,645 $ 34,180

Properties, Plants and Equipm_2

Properties, Plants and Equipment (Tables)	12 Months Ended
Properties, Plants and Equipment (Tables)	Dec. 31, 2023
Property, Plant and Equipment [Abstract]
Schedule of Components of Property, Plants and Equipment	The components of properties, plants and equipment are as follows: December 31, 2023 2022 (In thousands) Land, buildings and improvements $ 765,826 $ 741,874 Refining facilities 6,593,768 6,346,422 Pipelines and terminals 2,300,781 2,267,052 Transportation vehicles 37,870 43,801 Other fixed assets 543,966 422,583 Construction in progress 291,221 324,920 10,533,432 10,146,652 Accumulated depreciation (3,906,600) (3,457,747) $ 6,626,832 $ 6,688,905

Goodwill and Intangibles (Table

Goodwill and Intangibles (Tables)	12 Months Ended
Goodwill and Intangibles (Tables)	Dec. 31, 2023
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule of Goodwill by Segment	The following is a summary of our goodwill by segment: Refining Renewables Marketing Lubricants & Specialties Midstream Total (In thousands) Balance at December 31, 2022 $ 1,977,435 $ 159,020 $ 163,839 $ 246,036 $ 431,985 $ 2,978,315 Goodwill disposal and other changes — — — (943) — (943) Foreign currency translation adjustment — — — 372 — 372 Balance at December 31, 2023 $ 1,977,435 $ 159,020 $ 163,839 $ 245,465 $ 431,985 $ 2,977,744 Balance at December 31, 2023 Goodwill $ 2,286,753 $ 159,020 $ 163,839 $ 480,044 $ 431,985 $ 3,521,641 Accumulated impairment losses (309,318) — — (234,579) — (543,897) $ 1,977,435 $ 159,020 $ 163,839 $ 245,465 $ 431,985 $ 2,977,744
Schedule of Intangible Assets	The carrying amounts of our intangible assets presented in “Intangibles and other” on our consolidated balance sheets are as follows: December 31 Useful Life 2023 2022 (In thousands) Customer relationships 10 - 20 years $ 347,567 $ 346,354 Transportation agreements 30 years 59,933 59,933 Trademarks, patents and other 10 - 20 years 263,855 261,678 671,355 667,965 Accumulated amortization (260,723) (204,239) Total intangibles, net $ 410,632 $ 463,726
Schedule of Estimated Future Amortization Expense Related to Intangible Assets	Estimated future amortization expense related to the intangible assets at December 31, 2023 is as follows: (In thousands) 2024 $ 55,261 2025 $ 55,261 2026 $ 46,499 2027 $ 40,753 2028 $ 34,253

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
Income Taxes (Tables)	Dec. 31, 2023
Income Tax Disclosure [Abstract]
Schedule of Provision For Income Taxes	The provision for income taxes is comprised of the following: Years Ended December 31, 2023 2022 2021 (In thousands) Current Federal $ 179,677 $ 674,977 $ (33,206) State 24,419 108,993 (1,802) Foreign 44,966 57,734 30,336 Deferred Federal 154,996 38,535 94,353 State 31,285 21,121 1,386 Foreign 6,269 (6,488) 32,831 $ 441,612 $ 894,872 $ 123,898
Schedule of Effective Tax Rate to Income Tax Expense (Benefit)	The statutory federal income tax rate applied to pre-tax book income reconciles to income tax expense as follows: Years Ended December 31, 2023 2022 2021 (In thousands) Tax computed at statutory rate $ 452,027 $ 826,570 $ 165,302 State income taxes, net of federal tax benefit 55,734 123,442 13,588 Noncontrolling interest in net income (29,386) (28,726) (25,931) Effect of change in state rate — (15,800) (13,342) Nontaxable permanent differences (49,420) — — CARES Act benefits — — (10,384) Foreign rate differential 5,753 6,608 331 Federal tax credits (5,344) (23,853) (29,777) US tax on non-US operations 7,239 12,920 18,547 Other 5,009 (6,289) 5,564 $ 441,612 $ 894,872 $ 123,898
Schedule of Deferred Income Tax Assets And Liabilities	Our deferred income tax assets and liabilities as of December 31, 2023 and 2022 are as follows: December 31, 2023 Assets Liabilities Total (In thousands) Deferred income taxes Properties, plants, equipment and intangibles (due primarily to tax in excess of book depreciation) $ — $ (1,171,633) $ (1,171,633) Lease obligation 106,161 — 106,161 Accrued employee benefits 20,260 — 20,260 Accrued post-retirement benefits 9,985 — 9,985 Accrued environmental costs 42,916 — 42,916 Hedging instruments 1,791 — 1,791 Inventory differences — (164,178) (164,178) Deferred turnaround costs — (155,833) (155,833) Net operating loss and tax credit carryforwards 35,294 — 35,294 Valuation allowance — (10,614) (10,614) Other — (11,279) (11,279) Total $ 216,407 $ (1,513,537) $ (1,297,130) December 31, 2022 Assets Liabilities Total (In thousands) Deferred income taxes Properties, plants, equipment and intangibles (due primarily to tax in excess of book depreciation) $ — $ (1,032,048) $ (1,032,048) Lease obligation 129,727 — 129,727 Accrued employee benefits 17,665 — 17,665 Accrued post-retirement benefits 9,951 — 9,951 Accrued environmental costs 37,868 — 37,868 Hedging instruments 3,260 — 3,260 Inventory differences — (230,112) (230,112) Deferred turnaround costs — (88,574) (88,574) Net operating loss and tax credit carryforwards 27,963 — 27,963 Investment in HEP — (134,160) (134,160) Valuation allowance — (3,691) (3,691) Other — (14) (14) Total $ 226,434 $ (1,488,599) $ (1,262,165)
Schedule of Unrecognized Tax Benefits	A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows: Years Ended December 31, 2023 2022 2021 (In thousands) Balance at January 1 $ 1,354 $ 54,605 $ 54,899 Reductions for tax positions of prior years — (53,023) (49) Settlements — — (125) Lapse of statute of limitations (129) (228) (120) Balance at December 31 $ 1,225 $ 1,354 $ 54,605

Pension and Post-retirement P_2

Pension and Post-retirement Plans (Tables)	12 Months Ended
Pension and Post-retirement Plans (Tables)	Dec. 31, 2023
Retirement Benefits [Abstract]
Schedule of Changes in Benefit Obligation and Plan Assets to PCLI Pension Plans	The following table sets forth the changes in the benefit obligation and plan assets of our PCLI pension plans and Sonneborn Netherlands plans for the years ended December 31, 2023 and 2022. Years Ended December 31, 2023 2022 (In thousands) Change in plans' benefit obligations Pension plans benefit obligation - beginning of period $ 90,443 $ 120,414 Service cost — 1,839 Interest cost 3,781 3,086 Actuarial gain 2,097 (25,605) Benefits paid (5,472) (2,306) Settlements (24,090) — Transfer from other plans 3,849 164 Foreign currency exchange rate changes 2,032 (7,149) Pension plans benefit obligation - end of year $ 72,640 $ 90,443 Change in pension plans assets Fair value of plans assets - beginning of period $ 87,466 $ 119,325 Return on plans assets 7,146 (26,218) Employer contributions 1,324 3,486 Benefits paid (4,697) (2,306) Transfer payments 3,849 164 Settlements (24,090) — Foreign currency exchange rate changes 2,020 (6,985) Fair value of plans assets - end of year $ 73,018 $ 87,466 Funded status Over (Under)-funded balance $ 378 $ (2,977) Amounts recognized in consolidated balance sheets Intangibles and other $ 1,149 $ — Other long-term liabilities (771) (2,977) $ 378 $ (2,977) Amounts recognized in accumulated other comprehensive loss Cumulative actuarial loss $ (607) $ (3,872)
Schedule of Projected Benefit Obligation in Excess of Fair Value	The following tables provide information regarding pension plans with a projected benefit obligation and accumulated benefit obligation in excess of the fair value of plan assets: December 31, 2023 2022 (In thousands) Projected benefit obligation $ 24,579 $ 90,443 Fair value of plan assets $ 23,808 $ 87,466 December 31, 2023 2022 (In thousands) Accumulated benefit obligation $ 24,579 $ 90,443 Fair value of plan assets $ 23,808 $ 87,466
Schedule of Accumulated Benefit Obligation in Excess of Fair Value	The following tables provide information regarding pension plans with a projected benefit obligation and accumulated benefit obligation in excess of the fair value of plan assets: December 31, 2023 2022 (In thousands) Projected benefit obligation $ 24,579 $ 90,443 Fair value of plan assets $ 23,808 $ 87,466 December 31, 2023 2022 (In thousands) Accumulated benefit obligation $ 24,579 $ 90,443 Fair value of plan assets $ 23,808 $ 87,466
Schedule of Net Periodic Pension Expense	Net periodic pension expense consisted of the following components: Years Ended December 31, 2023 2022 2021 (In thousands) Service cost - benefit earned during the period $ — $ 1,839 $ 4,455 Interest cost on projected benefit obligations 3,781 3,086 2,740 Expected return on plans assets (3,140) (3,223) (3,031) Amortization of gain — (208) (407) Settlements 1,378 — — Net periodic pension expense $ 2,019 $ 1,494 $ 3,757
Schedule of Pension Plan Assets	The following table presents the fair values of PCLI’s pension plans’ assets, by level within the fair value hierarchy, as of December 31, 2023 and 2022. December 31, 2023 December 31, 2022 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total (In thousands) Fixed income 822 48,387 — 49,209 457 66,295 — 66,752 $ 822 $ 48,387 $ — $ 49,209 $ 457 $ 66,295 $ — $ 66,752
Schedule of Changes in Benefit Obligation and Plan Assets to Post-Retirement Healthcare Plans	The following table sets forth the changes in the benefit obligation and plan assets of our post-retirement healthcare plans for the years ended December 31, 2023 and 2022: Years Ended December 31, 2023 2022 (In thousands) Change in plans' benefit obligation Post-retirement plans' benefit obligation - beginning of year $ 28,678 $ 34,816 Service cost 1,604 2,081 Interest cost 1,340 990 Benefits paid (613) (582) Actuarial gain (761) (7,884) Foreign currency exchange rate changes 249 (743) Post-retirement plans' benefit obligation - end of year $ 30,497 $ 28,678 Change in plan assets Fair value of plan assets - beginning of year $ — $ — Employer contributions 603 572 Participant contributions 10 10 Benefits paid (613) (582) Fair value of plan assets - end of year $ — $ — Funded status Under-funded balance $ (30,497) $ (28,678) Amounts recognized in consolidated balance sheets Accrued liabilities $ (1,701) $ (1,706) Other long-term liabilities (28,796) (26,972) $ (30,497) $ (28,678) Amounts recognized in accumulated other comprehensive loss Cumulative actuarial gain $ 8,020 $ 7,603 Prior service credit 8,069 11,550 Total $ 16,089 $ 19,153
Schedule of Weighted Average Assumptions Used to Determine Benefit Obligations	The weighted average assumptions used to determine end of period benefit obligations: December 31, 2023 2022 Discount rate 4.60% - 4.81% 4.95% - 5.10% Current health care trend rate 6.00% - 6.75% 6.00% - 7.00% Ultimate health care trend rate 4.00% - 4.00% 4.00% - 4.00% Year rate reaches ultimate trend rate 2035 - 2041 2027 - 2041
Schedule of Net Periodic Post-Retirement Credit	Net periodic post-retirement credit consisted of the following components: Years Ended December 31, 2023 2022 2021 (In thousands) Service cost – benefit earned during the year $ 1,604 $ 2,081 $ 2,324 Interest cost on projected benefit obligations 1,340 990 782 Amortization of prior service credit (3,481) (3,472) (3,481) Amortization of (gain) loss (378) 32 153 Net periodic post-retirement credit $ (915) $ (369) $ (222)

Description of Business and P_4

Description of Business and Presentation of Financial Statements - Narrative (Details) $ in Millions					3 Months Ended			12 Months Ended
	Dec. 01, 2023 USD ($) shares	Mar. 14, 2022 USD ($) branded_station location	Apr. 27, 2021 USD ($)	Apr. 27, 2021 CAD ($)	Mar. 31, 2024 USD ($) country location facility branded_station	Mar. 31, 2023 USD ($)	Mar. 31, 2021 USD ($)	Dec. 31, 2023 USD ($) location facility branded_station country	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)	Nov. 01, 2021 USD ($)
Ownership Interest By Project Type [Line Items]
Number of branded stations \| branded_station					1,500			1,500
Number of locations licensed to use brand \| location					300			300
Number of countries entity licensed to exports products \| country					80			80
Allowance for expected credit losses					$ 2,800,000			$ 3,200,000	$ 7,700,000
Income tax expense (benefit)					$ 85,474,000	$ 99,700,000		441,612,000	894,872,000	$ 123,898,000
Effective income tax rate					21.30%	20.60%
Proceeds from inventory repurchase agreements					$ 6,300,000	$ 6,300,000		25,700,000	42,100,000	43,500,000
Payments under inventory repurchase agreements					$ 6,600,000	$ 7,000,000		$ 27,400,000	$ 42,800,000	$ 45,400,000
Environmental Remediation Expense, Statement of Income or Comprehensive Income [Extensible Enumeration]								Operating expenses	Operating expenses	Operating expenses
Asset Retirement Obligation								$ 64,600,000	$ 61,800,000
Turnaround And Catalyst Amortization Costs								$ 238,700,000	159,300,000	$ 136,900,000
Minimum
Ownership Interest By Project Type [Line Items]
Frequency Of Turnarounds Maintenance								5 years
Cheyenne Refinery
Ownership Interest By Project Type [Line Items]
Severance costs										1,000,000
Decommissioning expense									1,700,000	25,800,000
Refining, Pipeline And Terminal Facilities \| Minimum
Ownership Interest By Project Type [Line Items]
Property, Plant and Equipment, Useful Life								15 years
Refining, Pipeline And Terminal Facilities \| Maximum
Ownership Interest By Project Type [Line Items]
Property, Plant and Equipment, Useful Life								32 years
Building and Building Improvements \| Minimum
Ownership Interest By Project Type [Line Items]
Property, Plant and Equipment, Useful Life								10 years
Building and Building Improvements \| Maximum
Ownership Interest By Project Type [Line Items]
Property, Plant and Equipment, Useful Life								40 years
Other Fixed Assets \| Minimum
Ownership Interest By Project Type [Line Items]
Property, Plant and Equipment, Useful Life								5 years
Other Fixed Assets \| Maximum
Ownership Interest By Project Type [Line Items]
Property, Plant and Equipment, Useful Life								30 years
Transportation vehicles
Ownership Interest By Project Type [Line Items]
Property, Plant and Equipment, Useful Life								5 years
Lubricants & Specialties
Ownership Interest By Project Type [Line Items]
Severance costs							$ 7,800,000
Disposed of by Sale \| Mississauga, Canada Property
Ownership Interest By Project Type [Line Items]
Gain on sale of asset										$ 86,000,000
Disposed of by Sale \| Mississauga, Canada Property \| 7037619 Canada Inc.
Ownership Interest By Project Type [Line Items]
Proceeds from sale of property			$ 98,800,000	$ 125
Midstream
Ownership Interest By Project Type [Line Items]
Conversion ratio	0.315
Common stock in cash	$ 4
Transaction cash consideration transferred	$ 267,600,000
Shares issued (in shares) \| shares	21,072,326
Incremental acquisition and integration costs								$ 23,500,000
Sinclair Merger
Ownership Interest By Project Type [Line Items]
Number of branded stations \| branded_station		1,300
Number of locations licensed to use brand \| location		300
Transaction cash consideration transferred		$ 251,448,000
Incremental acquisition and integration costs								$ 15,800,000	$ 52,900,000
Asset Retirement Obligation											$ 6,200,000
WYOMING
Ownership Interest By Project Type [Line Items]
Number of facilities producing renewable diesel \| facility					2			2

Description of Business and P_5

Description of Business and Presentation of Financial Statements - Schedule of Equity Method Investments (Details) - USD ($) $ in Thousands	Dec. 31, 2023	Dec. 31, 2022
Schedule of Equity Method Investments [Line Items]
Underlying Equity	$ 170,411	$ 171,655
Recorded Investment Balance	265,945	270,604
Difference	(95,534)	(98,949)
Osage Pipeline
Schedule of Equity Method Investments [Line Items]
Underlying Equity	1,144	2,901
Recorded Investment Balance	27,135	29,773
Difference	(25,991)	(26,872)
Cheyenne Pipeline, LLC
Schedule of Equity Method Investments [Line Items]
Underlying Equity	30,508	27,655
Recorded Investment Balance	41,985	40,019
Difference	(11,477)	(12,364)
Cushing Connect Terminal Holdings LLC
Schedule of Equity Method Investments [Line Items]
Underlying Equity	48,135	49,915
Recorded Investment Balance	32,474	34,746
Difference	15,661	15,169
Pioneer Investments Corp.
Schedule of Equity Method Investments [Line Items]
Underlying Equity	24,188	23,835
Recorded Investment Balance	131,244	133,182
Difference	(107,056)	(109,347)
Saddle Butte Pipeline
Schedule of Equity Method Investments [Line Items]
Underlying Equity	66,436	67,349
Recorded Investment Balance	33,107	32,884
Difference	$ 33,329	$ 34,465

Cushing Connect Joint Venture -

Cushing Connect Joint Venture - Narrative (Details) - HEP - Cushing Connect bbl in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2019 USD ($) bbl
Holly Energy Partners Entity [Line Items)
Barrels of crude oil per day	160
Barrels of crude oil, value	1,500
Percent of budget which construction costs payable by HEP	10%
Expected construction costs \| $	$ 74

Cushing Connect Joint Venture_2

Cushing Connect Joint Venture - Schedule of Variable Interest Entities (Details) - USD ($) $ in Thousands	Mar. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Holly Energy Partners Entity [Line Items)
Cash and cash equivalents	$ 1,240,860	$ 1,353,747	$ 1,665,066
Properties, plants and equipment, at cost	10,609,735	10,533,432	10,146,652
Less: accumulated depreciation	(4,021,845)	(3,906,600)	(3,457,747)
Intangibles and other	977,257	972,272	982,718
Variable Interest Entity, Not Primary Beneficiary \| Cushing Connect
Holly Energy Partners Entity [Line Items)
Cash and cash equivalents	916	1,536	2,147
Properties, plants and equipment, at cost	102,979	102,936	102,635
Less: accumulated depreciation	(8,907)	(8,022)	(4,484)
Intangibles and other	$ 31,674	$ 32,473	$ 34,746

Revenues - Schedule of Disaggre

Revenues - Schedule of Disaggregated Revenues (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Disaggregation of Revenue [Line Items]
Sales and other revenues	$ 7,027,145	$ 7,565,142	$ 31,964,395	$ 38,204,839	$ 18,389,142
Refining
Disaggregation of Revenue [Line Items]
Sales and other revenues	5,373,025	5,665,214	24,156,278	30,379,696	15,734,870
Lubricants & Specialties
Disaggregation of Revenue [Line Items]
Sales and other revenues	675,545	733,714	2,762,767	3,149,128	2,550,624
Transportation fuels
Disaggregation of Revenue [Line Items]
Sales and other revenues	4,628,631	4,507,894	19,867,388	25,895,867	13,414,543
Specialty lubricant products
Disaggregation of Revenue [Line Items]
Sales and other revenues	614,221	679,862	2,521,025	2,826,206	2,322,242
Asphalt, fuel oil and other products
Disaggregation of Revenue [Line Items]
Sales and other revenues	483,316	440,339	2,167,049	2,147,710	948,581
Asphalt, fuel oil and other products \| Refining
Disaggregation of Revenue [Line Items]
Sales and other revenues	422,000	386,800	1,928,600	1,827,300	724,300
Asphalt, fuel oil and other products \| Lubricants & Specialties
Disaggregation of Revenue [Line Items]
Sales and other revenues	61,300	53,600	238,400	314,800	224,300
Total refined product revenues
Disaggregation of Revenue [Line Items]
Sales and other revenues	5,726,168	5,628,095	24,555,462	30,869,783	16,685,366
Total refined product revenues \| Mid-Continent
Disaggregation of Revenue [Line Items]
Sales and other revenues	2,215,841	2,007,156	9,362,688	13,924,566	9,094,885
Total refined product revenues \| Southwest
Disaggregation of Revenue [Line Items]
Sales and other revenues	975,702	832,702	3,814,142	4,965,298	3,477,562
Total refined product revenues \| Rocky Mountains
Disaggregation of Revenue [Line Items]
Sales and other revenues	1,988,491	2,197,827	9,131,345	9,533,476	2,118,619
Total refined product revenues \| Northeast
Disaggregation of Revenue [Line Items]
Sales and other revenues	219,347	263,904	959,239	1,037,771	824,900
Total refined product revenues \| Canada
Disaggregation of Revenue [Line Items]
Sales and other revenues	255,772	250,724	1,022,174	1,063,961	836,317
Total refined product revenues \| Europe, Asia and Latin America
Disaggregation of Revenue [Line Items]
Sales and other revenues	71,015	75,782	265,874	344,711	333,083
Excess crude oil revenues
Disaggregation of Revenue [Line Items]
Sales and other revenues	267,096	710,897	2,147,466	2,342,288	1,547,696
Renewable diesel revenues
Disaggregation of Revenue [Line Items]
Sales and other revenues	179,669	202,413	781,309	654,893	0
Transportation and logistics services
Disaggregation of Revenue [Line Items]
Sales and other revenues	23,099	26,416	117,749	109,200	103,646
Marketing revenues
Disaggregation of Revenue [Line Items]
Sales and other revenues	775,807	937,385	4,146,292	3,911,922	0
Other revenues
Disaggregation of Revenue [Line Items]
Sales and other revenues	$ 55,306	$ 59,936	$ 216,117	$ 316,753	$ 52,434

Revenues - Schedule Contract Li

Revenues - Schedule Contract Liabilities (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Change In Contract With Customer, Liability [Roll Forward]
Balance at beginning of period	$ 7,533	$ 10,722	$ 10,722	$ 9,278	$ 6,738
Increase	5,693	5,159	21,381	32,040	32,301
Recognized as revenue	(6,115)	(5,744)	(24,570)	(30,596)	(29,761)
Balance at end of period	$ 7,111	$ 10,137	$ 7,533	$ 10,722	$ 9,278

Revenues - Schedule of Performa

Revenues - Schedule of Performance Obligations (Details) bbl in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2023 USD ($) bbl	Dec. 31, 2022	Dec. 31, 2021	Mar. 31, 2024 USD ($) bbl
Third-Party Customer \| Midstream
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation revenues \| $	$ 82,001			$ 76,896
Equilon Enterprises LLC \| Revenue from Contract with Customer Benchmark \| Customer Concentration Risk
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Concentration risk, percentage of total revenues	12%	15%	13%
Refined product sales volumes (barrels)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, sale of refined product barrels \| bbl	126,200			120,194
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 \| Third-Party Customer \| Midstream
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation revenues \| $	$ 20,656
Satisfaction period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 \| Refined product sales volumes (barrels)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, sale of refined product barrels \| bbl	35,563
Satisfaction period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-04-01 \| Third-Party Customer \| Midstream
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation revenues \| $				$ 15,534
Satisfaction period				9 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-04-01 \| Refined product sales volumes (barrels)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, sale of refined product barrels \| bbl				26,099
Satisfaction period				9 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 \| Third-Party Customer \| Midstream
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation revenues \| $	$ 11,097			$ 11,114
Satisfaction period	1 year			1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 \| Refined product sales volumes (barrels)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, sale of refined product barrels \| bbl	25,506			27,204
Satisfaction period	1 year			1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01 \| Third-Party Customer \| Midstream
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation revenues \| $	$ 7,656			$ 7,656
Satisfaction period	1 year			1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01 \| Refined product sales volumes (barrels)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, sale of refined product barrels \| bbl	17,891			19,003
Satisfaction period	1 year			1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01 \| Third-Party Customer \| Midstream
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation revenues \| $	$ 42,592			$ 42,592
Satisfaction period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01 \| Refined product sales volumes (barrels)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation, sale of refined product barrels \| bbl	47,240			47,888
Satisfaction period

Fair Value Measurements (Detail

Fair Value Measurements (Details) - USD ($) $ in Thousands	Mar. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Assets:
Derivative assets	$ 10,277	$ 3,744	$ 18,650
Liabilities:
Derivative liabilities	19,081	17,549	12,012
Level 1
Assets:
Total assets	0	836	0
Liabilities:
RINs credit obligations	0		0
Total liabilities	9,744	0	2,750
RINs receivable			0
Level 1 \| Commodity forward contracts
Assets:
Derivative assets	0	0	0
Liabilities:
Derivative liabilities	0	0	0
Level 1 \| Foreign currency forward contracts
Assets:
Derivative assets	0		0
Liabilities:
Derivative liabilities	0	0
Total liabilities		0
Level 1 \| NYMEX futures contracts
Assets:
Derivative assets		836
Liabilities:
Derivative liabilities	9,744		2,750
Level 1 \| Commodity price swaps
Assets:
Derivative assets			0
Liabilities:
Derivative liabilities	0	0
Total liabilities		0
Level 1 \| Commodity collar contracts
Liabilities:
Derivative liabilities			0
Level 2
Assets:
Total assets	10,277	2,908	99,882
Liabilities:
RINs credit obligations	29,553		81,232
Total liabilities	38,890	17,549	90,494
RINs receivable			81,232
Level 2 \| Commodity forward contracts
Assets:
Derivative assets	8,564	2,908	2,949
Liabilities:
Derivative liabilities	7,336	1,848	2,987
Level 2 \| Foreign currency forward contracts
Assets:
Derivative assets	1,713		15,359
Liabilities:
Derivative liabilities	691	7,893
Total liabilities		7,893
Level 2 \| NYMEX futures contracts
Assets:
Derivative assets		0
Liabilities:
Derivative liabilities	0		0
Level 2 \| Commodity price swaps
Assets:
Derivative assets			342
Liabilities:
Derivative liabilities	1,310	7,808
Total liabilities		7,808
Level 2 \| Commodity collar contracts
Liabilities:
Derivative liabilities			6,275
Level 3
Assets:
Total assets	0	0	0
Liabilities:
RINs credit obligations	0		0
Total liabilities	0	0	0
RINs receivable			0
Level 3 \| Commodity forward contracts
Assets:
Derivative assets	0	0	0
Liabilities:
Derivative liabilities	0	0	0
Level 3 \| Foreign currency forward contracts
Assets:
Derivative assets	0		0
Liabilities:
Derivative liabilities	0	0
Total liabilities		0
Level 3 \| NYMEX futures contracts
Assets:
Derivative assets		0
Liabilities:
Derivative liabilities	0		0
Level 3 \| Commodity price swaps
Assets:
Derivative assets			0
Liabilities:
Derivative liabilities	0	0
Total liabilities		0
Level 3 \| Commodity collar contracts
Liabilities:
Derivative liabilities			0
Carrying Amount
Assets:
Total assets	10,277	3,744	99,882
Liabilities:
RINs credit obligations	29,553		81,232
Total liabilities	48,634	17,549	93,244
RINs receivable			81,232
Carrying Amount \| Commodity forward contracts
Assets:
Derivative assets	8,564	2,908	2,949
Liabilities:
Derivative liabilities	7,336	1,848	2,987
Carrying Amount \| Foreign currency forward contracts
Assets:
Derivative assets	1,713		15,359
Liabilities:
Derivative liabilities	691	7,893
Total liabilities		7,893
Carrying Amount \| NYMEX futures contracts
Assets:
Derivative assets		836
Liabilities:
Derivative liabilities	9,744		2,750
Carrying Amount \| Commodity price swaps
Assets:
Derivative assets			342
Liabilities:
Derivative liabilities	$ 1,310	7,808
Total liabilities		$ 7,808
Carrying Amount \| Commodity collar contracts
Liabilities:
Derivative liabilities			$ 6,275

Earnings Per Share (Details)

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Earnings Per Share [Abstract]
Net income attributable to HF Sinclair stockholders	$ 314,664	$ 353,266	$ 1,589,666	$ 2,922,668	$ 558,324
Participating securities' share in earnings	1,969	2,925	14,045	29,465	7,465
Net income attributable to common shares	$ 312,695	$ 350,341	$ 1,575,621	$ 2,893,203	$ 550,859
Average number of shares of common stock outstanding (in shares)	198,710	195,445	190,035	202,566	162,569
Average number of shares of common stock outstanding assuming dilution (in shares)	198,710	195,445	190,035	202,566	162,569
Basic earnings per share (in USD per share)	$ 1.57	$ 1.79	$ 8.29	$ 14.28	$ 3.39
Diluted earnings per share (in USD per share)	$ 1.57	$ 1.79	$ 8.29	$ 14.28	$ 3.39

Stock-Based Compensation - Narr

Stock-Based Compensation - Narrative (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation cost attributable to share-based compensation plans	$ 5,800	$ 3,300	$ 42,212	$ 35,947	$ 42,044
Issuance of common shares under incentive compensation plans	$ 0	0	$ 0	0	0
Share-Based Compensation Arrangement by Share-Based Payment Award, Number of Shares Authorized			6,368,930
HEP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation cost attributable to share-based compensation plans		$ 400	$ 1,500	1,900	2,600
Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation cost attributable to share-based compensation plans			30,067	27,264	29,453
Grant date fair value of restricted stock vested			$ 21,300	$ 26,500	$ 28,400
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value			$ 33.17	$ 59.41	$ 33.95
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Amount			$ 28,900
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Period for Recognition			1 year 6 months
Share-Based Payment Arrangement, Cash Used to Settle Award			$ 3,900	$ 5,800	$ 3,400
Share-Based Compensation Arrangement by Share-Based Payment Award, Shares Purchased for Award			71,589	96,005	105,459
Restricted Stock Units \| Non-Employee Directors
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock vesting period			1 year
Restricted Stock Units \| Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock vesting period	1 year		1 year
Restricted Stock Units \| Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock vesting period	3 years		3 years
Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock vesting period	3 years		3 years
Compensation cost attributable to share-based compensation plans			$ 12,145	$ 8,683	$ 12,591
Issuance of common shares under incentive compensation plans			$ 7,300
Grant date fair value of restricted stock vested				6,200	$ 4,500
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value			$ 24.47
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Amount			$ 20,100
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Period for Recognition			2 years 2 months 12 days
Share-Based Payment Arrangement, Cash Used to Settle Award			$ 1,200	$ 700
Common stock issued (in shares)			375,376
Share-Based Compensation Arrangement By Share-Based Payment Award, Equity Instruments Other Than Options, Settlements In Period			23,587	12,108
Performance Share Units \| Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage of target	0%		0%
Performance Share Units \| Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage of target	200%		200%
Share-Based Compensation Arrangement By Share-Based Payment Award, Equity Instruments Other Than Options, Vested In Period, Percentage Payout			125%

Stock-Based Compensation - Sche

Stock-Based Compensation - Schedule Of Restricted Stock and Performance Share Activity (Details) - $ / shares	3 Months Ended	12 Months Ended
	Mar. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Restricted Stock Units
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Outstanding at beginning of period (in shares)	1,102,755	1,055,875
Granted (in shares)	2,020	529,559
Vested (in shares)	(153,811)	(641,944)
Forfeited (in shares)	(186,799)	(65,952)
Outstanding at end of period (in shares)	764,165	1,102,755	1,055,875
Weighted average grant date fair value per unit (in USD per share)	$ 59.52	$ 52.59
Grant date fair value (in USD per share)		50.71	$ 39.46
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value		33.17	$ 59.41	$ 33.95
Weighted average grant date fair value of units forfeited (in USD per share)		$ 38.55
Performance share units converted to restricted stock units (in shares)		225,217
Share-Based Compensation Arrangement By Share-Based Payment Award, Equity Instruments Other Than Options, Units Converted, Weighted Average Grant Date Fair Value		$ 45.46
Performance Share Units
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Outstanding at beginning of period (in shares)	485,531	771,197
Granted (in shares)	0	263,881
Vested (in shares)	(1,859)	(298,978)
Forfeited (in shares)	(49,060)	(25,352)
Outstanding at end of period (in shares)	434,612	485,531	771,197
Weighted average grant date fair value per unit (in USD per share)	$ 0	$ 67.73
Grant date fair value (in USD per share)		61.66	$ 41.78
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value		24.47
Weighted average grant date fair value of units forfeited (in USD per share)		$ 40.76
Performance share units converted to restricted stock units (in shares)		225,217
Share-Based Compensation Arrangement By Share-Based Payment Award, Equity Instruments Other Than Options, Units Converted, Weighted Average Grant Date Fair Value		$ 52.44

Stock-Based Compensation - Sc_2

Stock-Based Compensation - Schedule of Stock-Based Compensation Expense (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Compensation cost attributable to share-based compensation plans	$ 5,800	$ 3,300	$ 42,212	$ 35,947	$ 42,044
Tax benefit recognized on compensation expense			10,203	8,918	10,545
Restricted Stock Units
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Compensation cost attributable to share-based compensation plans			30,067	27,264	29,453
Performance Share Units
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Compensation cost attributable to share-based compensation plans			$ 12,145	$ 8,683	$ 12,591

Inventories - Schedule of Inven

Inventories - Schedule of Inventories (Details) - USD ($) $ in Thousands	Mar. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Inventories
Crude oil	$ 798,070	$ 858,411	$ 818,737
Other raw materials and unfinished products	743,302	683,066	842,855
Finished products	1,438,867	1,435,817	1,252,984
Lower of cost or market reserve	(112,200)	(331,570)	(61,151)
Process chemicals	38,731	50,917	53,900
Repair and maintenance supplies and other	224,115	225,190	307,203
Total inventory	$ 3,130,885	$ 2,921,831	$ 3,214,528

Inventories - Narrative (Detail

Inventories - Narrative (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
Inventories - Narrative (Details) - USD ($) $ in Thousands	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Inventory [Line Items]
Inventory valuation reserves	$ 112,200		$ 331,570	$ 61,151
Refining
Inventory [Line Items]
Inventory valuation reserves			220,600
Increase (decrease) to cost of products sold	(220,600)		220,600		$ (318,900)
Excess of replacement cost over LIFO value of inventory				39,000
Renewables
Inventory [Line Items]
Inventory valuation reserves	112,200		111,000	61,200
Increase (decrease) to cost of products sold	$ 1,200	$ 47,600	$ 49,900	$ 52,400

Environmental (Details)

Environmental (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
Environmental (Details) - USD ($) $ in Millions	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Mar. 14, 2022
Loss Contingencies [Line Items]
Environmental remediation costs	$ 1.8	$ 13.3	$ 26.5	$ 13.4	$ 7.8
Accrued environmental liability	191.6		195.4	192.3
Sinclair Merger
Loss Contingencies [Line Items]
Third party receivable associated with environmental liabilities assumed in transaction						$ 21.5
Accrued environmental liabilities assumed in transaction						$ 72.2
Other Noncurrent Liabilities
Loss Contingencies [Line Items]
Accrued environmental liability	$ 164.4		$ 161.4	$ 170

Debt - Narrative (Details)

Debt - Narrative (Details) - USD ($)		1 Months Ended	3 Months Ended			12 Months Ended
Debt - Narrative (Details) - USD ($)	Apr. 27, 2022	Oct. 31, 2023	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2022	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Fair value of financing arrangements			$ 34,300,000		$ 39,800,000	$ 37,000,000	$ 39,800,000
Debt outstanding						2,755,500,000
Capitalized interest			700,000	$ 1,200,000		4,300,000	6,200,000	$ 15,200,000
Loss on early extinguishment of debt						0	604,000	$ 0
Letter of Credit
Debt Instrument [Line Items]
Debt outstanding			0			0
HEP
Debt Instrument [Line Items]
Maximum borrowing capacity under revolving credit agreement			1,200,000,000			1,200,000,000
HEP Credit Agreement			394,000,000		$ 668,000,000	455,500,000	$ 668,000,000
Letters of credit amount outstanding			0			0
Maximum borrowing capacity with accordion feature			$ 1,700,000,000			$ 1,700,000,000
Line of Credit \| HEP
Debt Instrument [Line Items]
Effective interest rate on debt			7.05%		6.32%	7.08%	6.32%
HF Sinclair Credit Agreement
Debt Instrument [Line Items]
Maximum borrowing capacity under revolving credit agreement			$ 1,650,000,000			$ 1,650,000,000
HEP Credit Agreement			0			0
Letters of credit amount outstanding			$ 300,000			300,000
HF Sinclair Credit Agreement \| Fed Funds Effective Rate
Debt Instrument [Line Items]
Variable rate spread	0.50%
HF Sinclair Credit Agreement \| Line of Credit \| Fed Funds Effective Rate
Debt Instrument [Line Items]
Variable rate spread	0.50%
HF Sinclair Credit Agreement \| Line of Credit \| Secured Overnight Financing Rate (SOFR)
Debt Instrument [Line Items]
Variable rate spread	1%
HF Sinclair Credit Agreement \| Line of Credit \| Base Rate \| Minimum
Debt Instrument [Line Items]
Variable rate spread	0.25%
HF Sinclair Credit Agreement \| Line of Credit \| Base Rate \| Minimum \| HEP
Debt Instrument [Line Items]
Variable rate spread	0.75%		0.75%
HF Sinclair Credit Agreement \| Line of Credit \| Base Rate \| Maximum
Debt Instrument [Line Items]
Variable rate spread	1.125%
HF Sinclair Credit Agreement \| Line of Credit \| Base Rate \| Maximum \| HEP
Debt Instrument [Line Items]
Variable rate spread	1.75%		1.75%
HF Sinclair Credit Agreement \| Line of Credit \| CDOR Rate \| Minimum
Debt Instrument [Line Items]
Variable rate spread	1.25%
HF Sinclair Credit Agreement \| Line of Credit \| CDOR Rate \| Maximum
Debt Instrument [Line Items]
Variable rate spread	2.125%
HF Sinclair Credit Agreement \| Line of Credit \| Adjusted Secured Overnight Financing Rate (SOFR) \| Minimum
Debt Instrument [Line Items]
Variable rate spread	1.25%
HF Sinclair Credit Agreement \| Line of Credit \| Adjusted Secured Overnight Financing Rate (SOFR) \| Minimum \| HEP
Debt Instrument [Line Items]
Variable rate spread	1.75%		1.75%
HF Sinclair Credit Agreement \| Line of Credit \| Adjusted Secured Overnight Financing Rate (SOFR) \| Maximum
Debt Instrument [Line Items]
Variable rate spread	2.125%
HF Sinclair Credit Agreement \| Line of Credit \| Adjusted Secured Overnight Financing Rate (SOFR) \| Maximum \| HEP
Debt Instrument [Line Items]
Variable rate spread	2.75%		2.75%
Letter of Credit \| HEP
Debt Instrument [Line Items]
Line of credit, maximum capacity available			$ 50,000,000			50,000,000
5.875% Senior Notes \| Senior Notes
Debt Instrument [Line Items]
Aggregate principal amount of senior note			$ 202,900,000			$ 202,900,000
Stated interest rate			5.875%			5.875%
4.500% Senior Notes \| Senior Notes
Debt Instrument [Line Items]
Aggregate principal amount of senior note			$ 74,966,000			$ 74,966,000
Stated interest rate			4.50%			4.50%
5.875% Senior Notes \| Senior Notes
Debt Instrument [Line Items]
Aggregate principal amount of senior note			$ 797,100,000			$ 797,100,000
Stated interest rate			5.875%			5.875%
4.500% Senior Notes \| Senior Notes
Debt Instrument [Line Items]
Aggregate principal amount of senior note			$ 325,034,000			$ 325,034,000
Stated interest rate			4.50%			4.50%
$5.000% Senior Notes \| Senior Notes
Debt Instrument [Line Items]
Aggregate principal amount of senior note			$ 498,879,000			$ 498,879,000
Stated interest rate			5%			5%
$6.375% Senior Notes \| Senior Notes
Debt Instrument [Line Items]
Aggregate principal amount of senior note			$ 399,875,000			$ 399,875,000
Stated interest rate			6.375%			6.375%
HEP 5.000% Senior Notes Due 2028 \| Senior Notes \| HEP
Debt Instrument [Line Items]
Aggregate principal amount of senior note			$ 1,121,000			$ 1,121,000
Stated interest rate			5%			5%
HEP 6.375% Senior Notes Due 2027 \| Senior Notes
Debt Instrument [Line Items]
Stated interest rate						6.375%
HEP 6.375% Senior Notes Due 2027 \| Senior Notes \| HEP
Debt Instrument [Line Items]
Aggregate principal amount of senior note			$ 125,000			$ 125,000
Stated interest rate			6.375%			6.375%
HollyFrontier 2.625% Senior Notes Due 2023 \| Senior Notes
Debt Instrument [Line Items]
Stated interest rate						2.625%
Debt repaid at maturity		$ 59,600,000
Redemption cost					$ 15,000,000
HF Sinclair 2.625% Senior Notes \| Senior Notes
Debt Instrument [Line Items]
Stated interest rate					2.625%	2.625%	2.625%
Debt repaid at maturity		$ 248,200,000
Redemption cost					$ 42,200,000
HF Sinclair 2.625% Senior Notes Due 2023 And HollyFrontier 2.625% Senior Notes Due 2023
Debt Instrument [Line Items]
Payment for Debt Extinguishment or Debt Prepayment Cost							$ 41,400,000
Loss on early extinguishment of debt							$ 600,000

Debt - Carrying Amounts Of Long

Debt - Carrying Amounts Of Long-Term Debt (Details) - USD ($) $ in Thousands	Mar. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Debt Instrument [Line Items]
Unamortized discount and debt issuance costs	$ (15,355)	$ (16,417)	$ (20,355)
Total long-term debt, net	2,678,645	2,739,083	2,948,513
Less current debt		0	(306,959)
Level 2
Debt Instrument [Line Items]
HF Sinclair, HollyFrontier and HEP Senior Notes	2,268,035	2,271,856
HEP
Debt Instrument [Line Items]
Carrying amounts of long-term debt	1,246	1,246	900,000
HEP Credit Agreement	394,000	455,500	668,000
Total long-term debt, net			1,400,000
HEP \| Level 2
Debt Instrument [Line Items]
HF Sinclair, HollyFrontier and HEP Senior Notes		1,188	852,658
HollyFrontier
Debt Instrument [Line Items]
Carrying amounts of long-term debt	277,866	277,866	337,503
5.875% Senior Notes
Debt Instrument [Line Items]
Carrying amounts of long-term debt	202,900	202,900	202,900
4.500% Senior Notes
Debt Instrument [Line Items]
Carrying amounts of long-term debt	74,966	74,966	74,966
HF Sinclair
Debt Instrument [Line Items]
Carrying amounts of long-term debt	2,020,888	2,020,888	1,370,324
5.875% Senior Notes
Debt Instrument [Line Items]
Carrying amounts of long-term debt	797,100	797,100	797,100
4.500% Senior Notes
Debt Instrument [Line Items]
Carrying amounts of long-term debt	325,034	325,034	325,034
$5.000% Senior Notes
Debt Instrument [Line Items]
Carrying amounts of long-term debt	498,879	498,879	0
$6.375% Senior Notes
Debt Instrument [Line Items]
Carrying amounts of long-term debt	399,875	399,875	0
HEP 5.000% Senior Notes \| HEP
Debt Instrument [Line Items]
Carrying amounts of long-term debt	1,121	1,121
HEP 6.375% Senior Notes \| HEP
Debt Instrument [Line Items]
Carrying amounts of long-term debt	$ 125	125
HollyFrontier 2.625% Senior Notes Due 2023
Debt Instrument [Line Items]
Carrying amounts of long-term debt		0	59,637
HF Sinclair 2.625% Senior Notes
Debt Instrument [Line Items]
Carrying amounts of long-term debt		0	248,190
HEP 5.000% Senior Notes Due 2028 \| HEP
Debt Instrument [Line Items]
Carrying amounts of long-term debt		1,121	500,000
HEP 6.375% Senior Notes Due 2027 \| HEP
Debt Instrument [Line Items]
Carrying amounts of long-term debt		125	400,000
HF Sinclair 2.625% Senior Notes Due 2023 And HollyFrontier 2.625% Senior Notes Due 2023
Debt Instrument [Line Items]
Unamortized discount and debt issuance costs			(900)
Senior Notes \| Level 2
Debt Instrument [Line Items]
HF Sinclair, HollyFrontier and HEP Senior Notes		$ 2,270,668	$ 1,655,726
Senior Notes \| 5.875% Senior Notes
Debt Instrument [Line Items]
Stated interest rate	5.875%	5.875%
Senior Notes \| 4.500% Senior Notes
Debt Instrument [Line Items]
Stated interest rate	4.50%	4.50%
Senior Notes \| 5.875% Senior Notes
Debt Instrument [Line Items]
Stated interest rate	5.875%	5.875%
Senior Notes \| 4.500% Senior Notes
Debt Instrument [Line Items]
Stated interest rate	4.50%	4.50%
Senior Notes \| $5.000% Senior Notes
Debt Instrument [Line Items]
Stated interest rate	5%	5%
Senior Notes \| $6.375% Senior Notes
Debt Instrument [Line Items]
Stated interest rate	6.375%	6.375%
Senior Notes \| HEP 5.000% Senior Notes \| HEP
Debt Instrument [Line Items]
Stated interest rate	5%
Senior Notes \| HEP 6.375% Senior Notes \| HEP
Debt Instrument [Line Items]
Stated interest rate	6.375%
Senior Notes \| HollyFrontier 2.625% Senior Notes Due 2023
Debt Instrument [Line Items]
Stated interest rate		2.625%
Senior Notes \| HF Sinclair 2.625% Senior Notes
Debt Instrument [Line Items]
Stated interest rate		2.625%	2.625%
Senior Notes \| HEP 5.000% Senior Notes Due 2028 \| HEP
Debt Instrument [Line Items]
Stated interest rate	5%	5%
Senior Notes \| HEP 6.375% Senior Notes Due 2027
Debt Instrument [Line Items]
Stated interest rate		6.375%
Senior Notes \| HEP 6.375% Senior Notes Due 2027 \| HEP
Debt Instrument [Line Items]
Stated interest rate	6.375%	6.375%

Debt - Principal Maturities of

Debt - Principal Maturities of Outstanding Debt (Details) $ in Thousands	Dec. 31, 2023 USD ($)
Debt Disclosure [Abstract]
2024	$ 0
2025	455,500
2026	1,000,000
2027	400,000
2028	500,000
Thereafter	400,000
Total long-term debt (2)	$ 2,755,500

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities - Location of Gain (Loss) in Income Statement (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Trading Activity, Gains and Losses, Net [Line Items]
Net Unrealized Gain Recognized in OCI	$ 0	$ 271	$ 0	$ 326	$ 31
Loss Reclassified into Earnings	(4,287)	(1)	(3,236)	(5,288)	(17,579)
Commodity contracts
Trading Activity, Gains and Losses, Net [Line Items]
Net Unrealized Gain Recognized in OCI	0	271	0	326	31
Commodity contracts \| Sales and other revenues
Trading Activity, Gains and Losses, Net [Line Items]
Loss Reclassified into Earnings	$ (4,287)	$ (1)	(3,236)	(5,288)	(19,239)
Commodity contracts \| Operating expenses
Trading Activity, Gains and Losses, Net [Line Items]
Loss Reclassified into Earnings			$ 0	$ 0	$ 1,660

Derivative Instruments and He_4

Derivative Instruments and Hedging Activities - Pre-tax effect on Income Due to Maturities and Fair Value Adjustments of Economic Hedges (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives Not Designated as Hedging Instruments	$ (7,984)	$ (4,790)	$ (15,985)	$ (7,563)	$ (15,106)
Commodity contracts \| Cost of products sold
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives Not Designated as Hedging Instruments	(20,665)	6,748	10,162	(17,189)	(22,909)
Commodity contracts \| Operating expenses
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives Not Designated as Hedging Instruments	(213)	(14,058)	(20,783)	(13,780)	0
Commodity contracts \| Interest expense
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives Not Designated as Hedging Instruments	2,763	2,406	2,050	(4,420)	11,816
Foreign currency contracts \| Gain on foreign currency transactions
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives Not Designated as Hedging Instruments	$ 10,131	$ 114	$ (7,414)	$ 27,826	$ (4,013)

Derivative Instruments and He_5

Derivative Instruments and Hedging Activities - Notional Contracts by Derivative Type (Details) - Not Designated as Hedging Instrument [Member] bbl in Thousands	3 Months Ended	12 Months Ended
	Mar. 31, 2024 USD ($) MMBTU ozt bbl	Dec. 31, 2023 USD ($) MMBTU ozt bbl
NYMEX futures (WTI) - short
Economic hedges by derivative type [Line Items]
Derivative nonmonetary notional amount (in barrels)	2,575	640
NYMEX futures (WTI) - short \| 2024
Economic hedges by derivative type [Line Items]
Derivative nonmonetary notional amount (in barrels)	2,575
NYMEX futures (WTI) - short \| 2025
Economic hedges by derivative type [Line Items]
Derivative nonmonetary notional amount (in barrels)	0
Forward gasoline and diesel contracts - long
Economic hedges by derivative type [Line Items]
Derivative nonmonetary notional amount (in barrels)	1,190	800
Forward gasoline and diesel contracts - long \| 2024
Economic hedges by derivative type [Line Items]
Derivative nonmonetary notional amount (in barrels)	1,190
Forward gasoline and diesel contracts - long \| 2025
Economic hedges by derivative type [Line Items]
Derivative nonmonetary notional amount (in barrels)	0
Foreign currency forward contracts
Economic hedges by derivative type [Line Items]
Derivative notional amount \| $	$ 386,671,810	$ 387,613,367
Foreign currency forward contracts \| 2024
Economic hedges by derivative type [Line Items]
Derivative notional amount \| $	281,628,809
Foreign currency forward contracts \| 2025
Economic hedges by derivative type [Line Items]
Derivative notional amount \| $	$ 105,043,001
Forward commodity contracts (platinum)
Economic hedges by derivative type [Line Items]
Derivative notional amount (in troy ounce) \| ozt	36,969	36,969
Forward commodity contracts (platinum) \| 2024
Economic hedges by derivative type [Line Items]
Derivative notional amount (in troy ounce) \| ozt	14,549
Forward commodity contracts (platinum) \| 2025
Economic hedges by derivative type [Line Items]
Derivative notional amount (in troy ounce) \| ozt	22,420
Natural gas price swaps (basis spread) - long
Economic hedges by derivative type [Line Items]
Derivative nonmonetary notional amount (in MMBTUs) \| MMBTU	3,300,000	6,667,000
Natural gas price swaps (basis spread) - long \| 2024
Economic hedges by derivative type [Line Items]
Derivative nonmonetary notional amount (in MMBTUs) \| MMBTU	3,300,000
Natural gas price swaps (basis spread) - long \| 2025
Economic hedges by derivative type [Line Items]
Derivative nonmonetary notional amount (in MMBTUs) \| MMBTU	0

Derivative Instruments and He_6

Derivative Instruments and Hedging Activities - Summary Of Balance Sheet Locations And Related Fair Values Of Outstanding Derivative Instruments (Details) - USD ($) $ in Thousands	Mar. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Derivative [Line Items]
Net Assets Recognized in Balance Sheet	$ 10,277	$ 3,744	$ 18,650
Derivative Asset, Statement of Financial Position [Extensible Enumeration]	Prepayments and other	Prepayments and other	Prepayments and other
Net Liabilities Recognized in Balance Sheet	$ 19,081	$ 17,549	$ 12,012
Derivative Liability, Statement of Financial Position [Extensible Enumeration]	Accrued liabilities	Accrued liabilities	Accrued liabilities
Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Gross Assets	$ 10,277	$ 3,744	$ 18,650
Gross Liabilities Offset in Balance Sheet	0	0	0
Net Assets Recognized in Balance Sheet	10,277	3,744	18,650
Gross Liabilities	20,161	17,549	12,012
Gross Assets Offset in Balance Sheet	(1,080)	0	0
Net Liabilities Recognized in Balance Sheet	19,081	17,549	12,012
Not Designated as Hedging Instrument [Member] \| NYMEX futures contracts
Derivative [Line Items]
Gross Assets	0	836	0
Gross Liabilities Offset in Balance Sheet	0	0	0
Net Assets Recognized in Balance Sheet	0	836	0
Gross Liabilities	9,744	0	2,750
Gross Assets Offset in Balance Sheet	0	0	0
Net Liabilities Recognized in Balance Sheet	9,744	0	2,750
Not Designated as Hedging Instrument [Member] \| Commodity price swap contracts
Derivative [Line Items]
Gross Assets	0	0	342
Gross Liabilities Offset in Balance Sheet	0	0	0
Net Assets Recognized in Balance Sheet	0	0	342
Gross Liabilities	1,310	7,808	0
Gross Assets Offset in Balance Sheet	0	0	0
Net Liabilities Recognized in Balance Sheet	1,310	7,808	0
Not Designated as Hedging Instrument [Member] \| Commodity forward contracts
Derivative [Line Items]
Gross Assets	8,564	2,908	2,949
Gross Liabilities Offset in Balance Sheet	0	0	0
Net Assets Recognized in Balance Sheet	8,564	2,908	2,949
Gross Liabilities	7,336	1,848	2,987
Gross Assets Offset in Balance Sheet	0	0	0
Net Liabilities Recognized in Balance Sheet	7,336	1,848	2,987
Not Designated as Hedging Instrument [Member] \| Foreign currency forward contracts
Derivative [Line Items]
Gross Assets	1,713	0	15,359
Gross Liabilities Offset in Balance Sheet	0	0	0
Net Assets Recognized in Balance Sheet	1,713	0	15,359
Gross Liabilities	1,771	7,893	0
Gross Assets Offset in Balance Sheet	(1,080)	0	0
Net Liabilities Recognized in Balance Sheet	$ 691	$ 7,893	0
Not Designated as Hedging Instrument [Member] \| Commodity collar contracts
Derivative [Line Items]
Gross Assets			0
Gross Liabilities Offset in Balance Sheet			0
Net Assets Recognized in Balance Sheet			0
Gross Liabilities			6,275
Gross Assets Offset in Balance Sheet			0
Net Liabilities Recognized in Balance Sheet			$ 6,275

Stockholders' Equity - Narrativ

Stockholders' Equity - Narrative (Details) - USD ($) $ / shares in Units, $ in Thousands						3 Months Ended		9 Months Ended	11 Months Ended	12 Months Ended
	May 08, 2024	Apr. 01, 2024	Feb. 08, 2024	Jan. 03, 2024	Dec. 14, 2022	Mar. 31, 2024	Mar. 31, 2023	May 07, 2024	Aug. 15, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Feb. 15, 2024	Aug. 31, 2023	Sep. 30, 2022
Class of Stock [Line Items]
Shares purchased under share repurchase program (in shares)						2,930,742	4,793,857			18,779,880	25,716,042
Cash paid for shares repurchased						$ 170,970	$ 243,192			$ 992,592	$ 1,378,390	$ 7,058
Common stock withheld under stock-based compensation agreements (in shares)						58,082	16,200			332,741	278,025	217,151
Shares withheld under terms of agreements (in shares)						$ 0.50	$ 0.45			$ 1.80	$ 1.20	$ 0.35
Payment, Tax Withholding, Share-Based Payment Arrangement										$ 18,100	$ 16,500	$ 7,100
Unregistered Block Trade \| REH Company
Class of Stock [Line Items]
Sale of Stock, Number of Shares Issued in Transaction					5,000,000
Subsequent Event
Class of Stock [Line Items]
Shares withheld under terms of agreements (in shares)	$ 0.50
REH Company
Class of Stock [Line Items]
Shares purchased under share repurchase program (in shares)						1,516,326	1,969,279			15,515,302	14,407,274
REH Company
Class of Stock [Line Items]
Shares purchased under share repurchase program (in shares)					1,000,000
Stock Repurchase Program Expiration Period					60 days
August 2023 Share Repurchase Program
Class of Stock [Line Items]
Authorized share repurchase amount									$ 1,000,000					$ 1,000,000
Remaining authorized share repurchase amount						$ 510,300							$ 591,400
Shares purchased under share repurchase program (in shares)			1,061,946	454,380
Price per share of stock repurchased (in USD per share)			$ 56.50	$ 55.02
Cash paid for shares repurchased			$ 60,000	$ 25,000
August 2023 Share Repurchase Program \| Subsequent Event
Class of Stock [Line Items]
Remaining authorized share repurchase amount								$ 214,200
Cash paid for shares repurchased								785,800
August 2023 Share Repurchase Program \| REH Company \| Subsequent Event
Class of Stock [Line Items]
Shares purchased under share repurchase program (in shares)		5,000,000
Price per share of stock repurchased (in USD per share)		$ 59.22
Cash paid for shares repurchased		$ 296,100
May 2024 Share Repurchase Program \| Subsequent Event
Class of Stock [Line Items]
Authorized share repurchase amount								$ 1,000,000
September 2022 Share Repurchase Program
Class of Stock [Line Items]
Authorized share repurchase amount															$ 1,000,000
Remaining authorized share repurchase amount									5,000
Cash paid for shares repurchased									$ 995,000
December 2022 Share Repurchase Program \| Registered Broker
Class of Stock [Line Items]
Shares purchased under share repurchase program (in shares)					1,000,000
Cash paid for shares repurchased					$ 48,600

Stockholders' Equity - Schedule

Stockholders' Equity - Schedule of Share Repurchases (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022
Class of Stock [Line Items]
Number of shares repurchased (in shares)	2,930,742	4,793,857	18,779,880	25,716,042
Cash paid for shares repurchased	$ 166,128	$ 240,323	$ 974,474	$ 1,313,006
REH Company
Class of Stock [Line Items]
Number of shares repurchased (in shares)	1,516,326	1,969,279	15,515,302	14,407,274
Cash paid for shares repurchased	$ 85,000	$ 100,000	$ 810,600	$ 750,000

Other Comprehensive Income (L_3

Other Comprehensive Income (Loss) - Components And Allocated Tax Effects Of Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Before-Tax	$ (13,305)	$ 2,237	$ 13,262	$ (31,268)	$ (13,762)
Tax Expense (Benefit)	(2,812)	447	3,033	(6,584)	(2,971)
Other comprehensive income (loss)	(10,493)	1,790	10,229	(24,684)	(10,791)
Net change in foreign currency translation adjustment
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Before-Tax	(12,606)	2,926	13,161	(32,383)	(13,336)
Tax Expense (Benefit)	(2,643)	614	2,760	(6,817)	(2,793)
Other comprehensive income (loss)	(9,963)	2,312	10,401	(25,566)	(10,543)
Net unrealized gain on hedging instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Before-Tax		271		326	31
Tax Expense (Benefit)		66		67	8
Other comprehensive income (loss)		205		259	23
Net change in pension and other post-retirement benefit obligations
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Before-Tax	(699)	(960)	101	789	(457)
Tax Expense (Benefit)	(169)	(233)	273	166	(186)
Other comprehensive income (loss)	$ (530)	$ (727)	$ (172)	$ 623	$ (271)

Other Comprehensive Income (L_4

Other Comprehensive Income (Loss) - Other Comprehensive Income Amounts Reclassified to Income Statement (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Gain on sale of assets and other	$ 2,019	$ 1,631	$ 27,370	$ 13,337	$ 98,128
Income tax expense (benefit)	85,474	99,700	441,612	894,872	123,898
Net of tax	316,622	385,005	1,710,895	3,041,174	663,254
Operating expenses	607,112	639,383	2,438,148	2,334,893	1,517,478
Net income (loss), before tax	402,096	484,705	2,152,507	3,936,046	787,152
Reclassification out of Accumulated Other Comprehensive Income (Loss)
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net of tax	(2,718)	726	(580)	(1,272)	(10,385)
Reclassification out of Accumulated Other Comprehensive Income (Loss) \| Hedging instruments:
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income tax expense (benefit)	(1,039)	0	(784)	(1,282)	(4,430)
Net of tax	(3,248)	(1)	(2,452)	(4,006)	(13,149)
Net income (loss), before tax			(3,236)	(5,288)	(17,579)
Reclassification out of Accumulated Other Comprehensive Income (Loss) \| Hedging instruments: \| Commodity price swap contracts
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Sales and other revenues	(4,287)	(1)	(3,236)	(5,288)	(19,239)
Operating expenses			0	0	1,660
Reclassification out of Accumulated Other Comprehensive Income (Loss) \| Other post-retirement benefit obligations: \| Pension obligations
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Gain on sale of assets and other	(217)	45
Income tax expense (benefit)	(53)	11	(334)	50	103
Net of tax	(164)	34	(1,044)	158	304
Gain on sale of assets and other			(1,378)	208	407
Reclassification out of Accumulated Other Comprehensive Income (Loss) \| Other post-retirement benefit obligations: \| Post-retirement healthcare obligations
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Gain on sale of assets and other	922	918
Income tax expense (benefit)	223	223	935	834	839
Net of tax	699	695	2,924	2,606	2,489
Gain on sale of assets and other			3,859	3,440	3,328
Reclassification out of Accumulated Other Comprehensive Income (Loss) \| Other post-retirement benefit obligations: \| Retirement restoration plan
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Gain on sale of assets and other	(6)	(3)
Income tax expense (benefit)	(1)	(1)	(3)	(9)	(10)
Net of tax	$ (5)	$ (2)	(8)	(30)	(29)
Gain on sale of assets and other			$ (11)	$ (39)	$ (39)

Other Comprehensive Income (L_5

Other Comprehensive Income (Loss) - Accumulated Other Comprehensive Income (Loss) In Equity (Details) - USD ($) $ in Thousands	Mar. 31, 2024	Dec. 31, 2023	Mar. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Stockholders' equity	$ 10,276,089	$ 10,237,298	$ 10,050,527	$ 10,017,572	$ 6,294,465	$ 5,722,203
Accumulated other comprehensive loss
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Stockholders' equity	(22,277)	(11,784)	$ (20,223)	(22,013)	$ 2,671	$ 13,462
Foreign currency translation adjustment
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Stockholders' equity	(32,988)	(23,026)		(33,427)
Unrealized gain (loss) on defined benefit plans \| Unrealized loss on pension obligations
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Stockholders' equity	836	619		(2,661)
Unrealized gain (loss) on defined benefit plans \| Unrealized gain on post-retirement benefit obligations
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Stockholders' equity	$ 9,875	$ 10,623		$ 14,075

Contingencies - Narrative (Deta

Contingencies - Narrative (Details) $ in Thousands				1 Months Ended	3 Months Ended		12 Months Ended
Contingencies - Narrative (Details) $ in Thousands	Jun. 24, 2022 lawsuit	Mar. 14, 2022 shares	Feb. 10, 2021 USD ($)	Apr. 30, 2023 shares	Mar. 31, 2024 USD ($)	Mar. 31, 2023 USD ($)	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)
Commitments And Contingencies [Line Items]
Gain on sale of assets and other \| $					$ 2,019	$ 1,631	$ 27,370	$ 13,337	$ 98,128
Gain on business interruption insurance settlement \| $							0	$ 15,202	0
Gain on Business Interruption Insurance Recovery, Statement of Income or Comprehensive Income [Extensible Enumeration]								Gain on business interruption insurance settlement
Proceeds from legal settlements \| $			$ 51,500
Results of Operations, Transportation Costs \| $							200,500	$ 180,200	$ 160,500
Sinclair Merger
Commitments And Contingencies [Line Items]
Period following delivery of invoice requirement acquiree payment		5 days
Shares held in escrow (in shares)		2,570,000
Sinclair Merger \| REH Company
Commitments And Contingencies [Line Items]
Shares held in escrow (in shares)		2,570,000
Shares issued (in shares)		60,230,036
Sinclair Merger \| HEP
Commitments And Contingencies [Line Items]
Shares held in escrow (in shares)		5,290,000
Shares issued (in shares)		21,000,000
Sinclair Merger \| HEP \| REH Company
Commitments And Contingencies [Line Items]
Shares issued (in shares)		21,000,000		5,290,000
Refining
Commitments And Contingencies [Line Items]
Gain on sale of assets and other \| $							$ 15,000
Growth Energy
Commitments And Contingencies [Line Items]
Number of lawsuit \| lawsuit	2

Contingencies - Schedule of Min

Contingencies - Schedule of Minimum Future Fees Under Agreement (Details) $ in Thousands	Dec. 31, 2023 USD ($)
Commitments and Contingencies Disclosure [Abstract]
2024	$ 237,534
2025	241,403
2026	203,316
2027	203,484
2028	207,742
Thereafter	1,079,956
Total	$ 2,173,435

Segment Information - Narrative

Segment Information - Narrative (Details) - segment	3 Months Ended	12 Months Ended
Segment Information - Narrative (Details) - segment	Mar. 31, 2024	Dec. 31, 2023	Mar. 14, 2022
Segment Reporting Information [Line Items]
Number of reportable segments	5	5
HEP \| Osage Pipeline
Segment Reporting Information [Line Items]
Equity method investment, ownership percentage	50%	50%
HEP \| Cheyenne Pipeline
Segment Reporting Information [Line Items]
Equity method investment, ownership percentage	50%	50%
HEP \| Cushing Connect
Segment Reporting Information [Line Items]
Equity method investment, ownership percentage	50%	50%
HEP \| Saddle Butte Pipeline
Segment Reporting Information [Line Items]
Equity method investment, ownership percentage	25.12%	25.12%	25.06%
HEP \| Pioneer Pipeline
Segment Reporting Information [Line Items]
Equity method investment, ownership percentage	49.995%	49.995%	49.995%

Segment Information - Schedule

Segment Information - Schedule Of Segment Reporting Information (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Segment Reporting Information [Line Items]
Sales and other revenues	$ 7,027,145	$ 7,565,142	$ 31,964,395	$ 38,204,839	$ 18,389,142
Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment)	5,926,500	6,104,057	25,784,449	30,680,013	15,567,052
Lower of cost or market inventory valuation adjustment	(219,370)	47,597	270,419	52,412	(310,123)
Operating expenses	607,112	639,383	2,438,148	2,334,893	1,517,478
Selling, general and administrative expenses	103,374	95,913	498,240	426,485	362,010
Depreciation and amortization	198,729	173,983	770,573	656,787	503,539
Income (loss) from operations	410,800	504,209	2,202,566	4,054,249	749,186
Earnings of equity method investments	7,346	3,882	17,369	(260)	12,432
Capital expenditures	89,108	100,069	385,413	524,007	813,409
Corporate, Other and Eliminations
Segment Reporting Information [Line Items]
Sales and other revenues	(1,025,468)	(1,264,316)	(5,402,971)	(4,833,838)	(960,695)
Intersegment Eliminations
Segment Reporting Information [Line Items]
Sales and other revenues	(1,025,468)	(1,264,316)	(5,402,971)	(4,833,838)	960,697
Corporate, Non-Segment
Segment Reporting Information [Line Items]
Sales and other revenues	0	0	0	0	2
Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment)	(1,023,671)	(1,262,721)	(5,399,317)	(4,829,633)	(945,871)
Lower of cost or market inventory valuation adjustment	0	0	0	0	(509)
Operating expenses	(953)	981	2,233	13,061	37,839
Selling, general and administrative expenses	7,002	5,058	68,399	87,892	51,655
Depreciation and amortization	12,153	8,925	40,826	31,229	25,375
Income (loss) from operations	(19,999)	(16,559)	(115,112)	(136,387)	(129,184)
Earnings of equity method investments	(42)	0	(162)	0	0
Capital expenditures	10,485	5,933	47,011	53,327	22,928
Refining
Segment Reporting Information [Line Items]
Sales and other revenues	5,373,025	5,665,214	24,156,278	30,379,696	15,734,870
Refining \| Operating Segments
Segment Reporting Information [Line Items]
Sales and other revenues	6,204,245	6,718,615	28,672,604	34,412,909	16,358,558
Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment)	5,474,522	5,641,131	24,042,807	28,350,823	14,691,246
Lower of cost or market inventory valuation adjustment	(220,558)	0	220,558	0	(318,353)
Operating expenses	472,086	501,759	1,879,656	1,761,445	1,038,300
Selling, general and administrative expenses	48,717	39,078	199,547	146,660	127,563
Depreciation and amortization	117,370	100,083	460,962	397,069	325,845
Income (loss) from operations	312,108	436,564	1,869,074	3,756,912	493,957
Earnings of equity method investments	0	0	0	0	0
Capital expenditures	55,025	67,774	223,495	168,173	162,670
Refining \| Intersegment Eliminations
Segment Reporting Information [Line Items]
Sales and other revenues	(831,220)	(1,053,401)	(4,516,326)	(4,033,213)	(623,688)
Renewables
Segment Reporting Information [Line Items]
Sales and other revenues	179,669	202,413	781,309	654,893	0
Renewables \| Operating Segments
Segment Reporting Information [Line Items]
Sales and other revenues	239,559	298,016	1,188,990	1,015,499	0
Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment)	230,273	262,738	1,080,919	974,167	0
Lower of cost or market inventory valuation adjustment	1,188	47,597	49,861	52,412	8,739
Operating expenses	26,461	31,371	109,056	111,974	55,353
Selling, general and administrative expenses	1,402	915	5,117	3,769	0
Depreciation and amortization	20,272	19,974	77,100	52,621	1,672
Income (loss) from operations	(40,037)	(64,579)	(133,063)	(179,444)	(65,764)
Earnings of equity method investments	0	0	0	0	0
Capital expenditures	2,650	4,844	18,154	225,274	510,836
Renewables \| Intersegment Eliminations
Segment Reporting Information [Line Items]
Sales and other revenues	(59,890)	(95,603)	(407,681)	(360,606)	0
Marketing
Segment Reporting Information [Line Items]
Sales and other revenues	775,807	937,385	4,146,292	3,911,922
Marketing \| Operating Segments
Segment Reporting Information [Line Items]
Sales and other revenues	775,807	937,385	4,146,292	3,911,922
Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment)	752,530	924,049	4,050,759	3,845,625
Lower of cost or market inventory valuation adjustment	0	0	0	0
Operating expenses	0	0	0	0
Selling, general and administrative expenses	7,756	6,963	34,413	2,954
Depreciation and amortization	6,303	5,871	24,599	17,819
Income (loss) from operations	9,218	502	36,521	45,524
Earnings of equity method investments	0	0	0	0
Capital expenditures	7,531	5,255	27,630	9,275
Marketing \| Intersegment Eliminations
Segment Reporting Information [Line Items]
Sales and other revenues	0	0	0	0
Lubricants & Specialties
Segment Reporting Information [Line Items]
Sales and other revenues	675,545	733,714	2,762,767	3,149,128	2,550,624
Lubricants & Specialties \| Operating Segments
Segment Reporting Information [Line Items]
Sales and other revenues	677,987	739,510	2,775,333	3,158,600	2,560,612
Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment)	492,846	538,860	2,009,281	2,339,031	1,821,677
Lower of cost or market inventory valuation adjustment	0	0	0	0	0
Operating expenses	64,000	63,593	258,578	277,522	252,456
Selling, general and administrative expenses	34,568	39,264	164,311	168,207	170,155
Depreciation and amortization	22,511	19,368	84,928	81,281	77,601
Income (loss) from operations	64,062	78,425	258,235	292,559	238,723
Earnings of equity method investments	0	0	0	0	0
Capital expenditures	5,311	8,649	37,431	34,887	30,878
Lubricants & Specialties \| Intersegment Eliminations
Segment Reporting Information [Line Items]
Sales and other revenues	(2,442)	(5,796)	(12,566)	(9,472)	(9,988)
Midstream
Segment Reporting Information [Line Items]
Sales and other revenues	23,099	26,416	117,749	109,200	103,646
Midstream \| Operating Segments
Segment Reporting Information [Line Items]
Sales and other revenues	155,015	135,932	584,147	539,747	430,667
Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment)	0	0	0	0	0
Lower of cost or market inventory valuation adjustment	0	0	0	0	0
Operating expenses	45,518	41,679	188,625	170,891	133,530
Selling, general and administrative expenses	3,929	4,635	26,453	17,003	12,637
Depreciation and amortization	20,120	19,762	82,158	76,768	73,046
Income (loss) from operations	85,448	69,856	286,911	275,085	211,454
Earnings of equity method investments	7,388	3,882	17,531	(260)	12,432
Capital expenditures	8,106	7,614	31,692	33,071	86,097
Midstream \| Intersegment Eliminations
Segment Reporting Information [Line Items]
Sales and other revenues	$ (131,916)	$ (109,516)	$ (466,398)	$ (430,547)	$ (327,021)

Acquisitions - Narrative (Detai

Acquisitions - Narrative (Details) $ / shares in Units, $ in Thousands, bbl in Millions			1 Months Ended	2 Months Ended	3 Months Ended	10 Months Ended	12 Months Ended
	Mar. 14, 2022 USD ($) terminal jointVenturePipeline refinery location nomination branded_station mi $ / shares shares bbl	Nov. 01, 2021 USD ($)	Apr. 30, 2023 shares	Dec. 31, 2021 USD ($)	Mar. 31, 2024 USD ($) location branded_station $ / shares	Dec. 31, 2022 USD ($) $ / shares	Dec. 31, 2023 USD ($) location branded_station $ / shares	Dec. 31, 2022 USD ($) $ / shares
Business Acquisition [Line Items]
Common stock par value (in USD per share) \| $ / shares	$ 0.01				$ 0.01	$ 0.01	$ 0.01	$ 0.01
Number of branded stations \| branded_station					1,500		1,500
Number of locations licensed to use brand \| location					300		300
Goodwill					$ 2,977,511	$ 2,978,315	$ 2,977,744	$ 2,978,315
Refining
Business Acquisition [Line Items]
Goodwill						1,977,435	1,977,435	1,977,435
Renewables
Business Acquisition [Line Items]
Goodwill						159,020	159,020	159,020
Marketing
Business Acquisition [Line Items]
Goodwill						163,839	163,839	163,839
Midstream
Business Acquisition [Line Items]
Goodwill						431,985	$ 431,985	431,985
HEP \| Saddle Butte Pipeline III, LLC
Business Acquisition [Line Items]
Equity method investment, ownership percentage	25.06%				25.12%		25.12%
HEP \| Pioneer Pipeline
Business Acquisition [Line Items]
Equity method investment, ownership percentage	49.995%				49.995%		49.995%
HEP \| UNEV
Business Acquisition [Line Items]
Remaining ownership interest acquired	0.25
REH Company
Business Acquisition [Line Items]
Number Of Director Nominations To Board Of Directors \| nomination	2
REH Company \| RINs credit obligations
Business Acquisition [Line Items]
Total liabilities	$ 68,400
Sinclair Merger
Business Acquisition [Line Items]
Transaction cash consideration transferred	251,448
Value of shares issued in transaction	2,498,028
Business Combination, Consideration Transferred	$ 2,749,476
Shares held in escrow (in shares) \| shares	2,570,000
Number of branded stations \| branded_station	1,300
Number of locations licensed to use brand \| location	300
Goodwill	$ 685,934
Intangible assets acquired	221,400
Fair value of equity method investments acquired	234,300
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Accrued Liabilities	84,298
Revenue from acquiree						9,835,000
Business Combination, Pro Forma Information, Earnings or Loss of Acquiree since Acquisition Date, Actual						$ (865,100)
Incremental acquisition and integration costs							$ 15,800	52,900
Sinclair Merger \| Crude Oil and Refined Products
Business Acquisition [Line Items]
Inventories	906,461
Sinclair Merger \| RINs credit obligations
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Accrued Liabilities	$ 70,600
Sinclair Merger \| Minimum
Business Acquisition [Line Items]
Amortization period of intangible assets acquired	4 years
Sinclair Merger \| Maximum
Business Acquisition [Line Items]
Amortization period of intangible assets acquired	20 years
Sinclair Merger \| Refining
Business Acquisition [Line Items]
Goodwill	$ 244,000
Sinclair Merger \| Renewables
Business Acquisition [Line Items]
Goodwill	159,000
Sinclair Merger \| Marketing
Business Acquisition [Line Items]
Goodwill	163,800
Sinclair Merger \| Midstream
Business Acquisition [Line Items]
Goodwill	$ 119,100
Sinclair Merger \| Casper And Sinclair, Wyoming
Business Acquisition [Line Items]
Number Of Refineries \| refinery	2
Sinclair Merger \| HEP
Business Acquisition [Line Items]
Transaction cash consideration transferred	$ 328,955
Shares issued (in shares) \| shares	21,000,000
Value of shares issued in transaction	$ 349,020
Shares held in escrow (in shares) \| shares	5,290,000
Pipeline Size \| mi	1,200
Number Of Terminals, Product \| terminal	8
Number Of Terminals, Crude \| terminal	2
Barrels of crude oil, value \| bbl	4.5
Number Of Equity Method Investments Acquired \| jointVenturePipeline	3
Puget Sound Refinery
Business Acquisition [Line Items]
Business Combination, Consideration Transferred		$ 624,300
Revenue from acquiree				$ 603,100
Business Combination, Pro Forma Information, Earnings or Loss of Acquiree since Acquisition Date, Actual				$ 8,300
Incremental acquisition and integration costs								$ 12,200
Business Combination, Base Purchase Price		350,000
Business Combination, Recognized Identifiable Assets Acquired And Liabilities Assumed, Closing Adjustments And Accrued Liabilities		3,600
Puget Sound Refinery \| Crude Oil and Refined Products
Business Acquisition [Line Items]
Inventories		$ 277,900
REH Company \| Sinclair Merger
Business Acquisition [Line Items]
Shares issued (in shares) \| shares	60,230,036
Percentage of pro forma equity representing shares issued in transaction	0.27
Value of shares issued in transaction	$ 2,149,000
Shares held in escrow (in shares) \| shares	2,570,000
REH Company \| Sinclair Merger \| HEP
Business Acquisition [Line Items]
Transaction cash consideration transferred	$ 329,000
Shares issued (in shares) \| shares	21,000,000		5,290,000
REH Company \| Disposed of by Sale \| Renewable Identification Numbers
Business Acquisition [Line Items]
RINs sold							21,200
HF Sinclair \| Sinclair Merger \| REH Company
Business Acquisition [Line Items]
Transaction cash consideration transferred	$ 77,500
Business Combination, Consideration Transferred	$ 2,072,000
Renewable Identification Numbers
Business Acquisition [Line Items]
Aggregate purchase amount							$ 36,000

Acquisitions - Schedule of Reco

Acquisitions - Schedule of Recognized Identified Assets Acquired and Liabilities Assumed (Details) - Sinclair Merger - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	Mar. 14, 2022	Mar. 11, 2022
Business Acquisition [Line Items]
Business Acquisition, Equity Interest Issued or Issuable, Value Assigned	$ 2,498,028
Payments to Acquire Businesses, Gross	251,448
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Working Capital	(77,507)
Business Combination, Consideration Transferred	$ 2,749,476
HF Sinclair
Business Acquisition [Line Items]
Shares issued in transaction (in shares)	60,230
Closing price per share (in USD per share)		$ 35.68
Business Acquisition, Equity Interest Issued or Issuable, Value Assigned	$ 2,149,008
HEP
Business Acquisition [Line Items]
Shares issued in transaction (in shares)	21,000
Closing price per share (in USD per share)		$ 16.62
Business Acquisition, Equity Interest Issued or Issuable, Value Assigned	$ 349,020
Payments to Acquire Businesses, Gross	$ 328,955

Acquisitions - Schedule of Prel

Acquisitions - Schedule of Preliminary Purchase Consideration (Details) - USD ($) $ in Thousands	Mar. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Mar. 14, 2022
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities [Abstract]
Goodwill	$ 2,977,511	$ 2,977,744	$ 2,978,315
Sinclair Merger
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets [Abstract]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Receivables				$ 467,530
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment				1,242,549
Business Combination, Recognized Identifiable Assets Acquired And Liabilities Assumed, Operating Lease Right-Of-Use Assets				4,585
Business Combination, Recognized Identifiable Assets Acquired And Liabilities Assumed, Intangibles And Other Assets				495,621
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets, Total				3,156,096
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities [Abstract]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Accounts Payable				564,385
Business Combination, Recognized Identifiable Assets Acquired And Liabilities Assumed, Current Liabilities, Operating Lease Liabilities				1,030
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Accrued Liabilities				84,298
Business Combination, Recognized Identifiable Assets Acquired And Liabilities Assumed, Noncurrent Liabilities, Operating Lease Liabilities				3,554
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Deferred Tax Liabilities				351,189
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other				88,098
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities, Total				1,092,554
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net, Total				2,063,542
Goodwill				685,934
Sinclair Merger \| Crude Oil and Refined Products
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets [Abstract]
Inventories				906,461
Sinclair Merger \| Materials, Supplies and Other
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets [Abstract]
Inventories				$ 39,350

Leases - Narrative (Details)

Leases - Narrative (Details) $ in Millions	Dec. 31, 2023 USD ($)
Lessee, Lease, Description [Line Items]
Future undiscounted lease payments under leases	$ 62.8
Lease not yet commenced, term	15 years
Minimum
Lessee, Lease, Description [Line Items]
Operating lease term	1 year
Maximum
Lessee, Lease, Description [Line Items]
Operating lease term	56 years
Operating lease renewal term	10 years

Leases - Supplemental Balance S

Leases - Supplemental Balance Sheet Schedule (Details) - USD ($) $ in Thousands	Mar. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Operating leases:
Operating lease right-of-use assets	$ 390,566	$ 348,006	$ 351,068
Operating lease liabilities	97,973	106,973	109,926
Noncurrent operating lease liabilities	$ 309,370	249,479	254,215
Total operating lease liabilities		356,452	364,141
Finance leases:
Properties, plants and equipment, at cost		108,746	81,454
Accumulated amortization		(25,271)	(21,434)
Properties, plants and equipment, net		$ 83,475	$ 60,020
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]		Property, Plant, and Equipment and Finance Lease Right-of-Use Asset, after Accumulated Depreciation and Amortization	Property, Plant, and Equipment and Finance Lease Right-of-Use Asset, after Accumulated Depreciation and Amortization
Accrued liabilities		$ 10,842	$ 10,722
Finance Lease, Liability, Current, Statement of Financial Position [Extensible List]		Accrued liabilities	Accrued liabilities
Other long-term liabilities		$ 74,860	$ 50,361
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]		Other long-term liabilities	Other long-term liabilities
Total finance lease liabilities		$ 85,702	$ 61,083
Weighted average remaining lease term (in years)
Operating leases		7 years 10 months 24 days	7 years 2 months 12 days
Finance leases		8 years 8 months 12 days	7 years 9 months 18 days
Weighted average discount rate
Operating leases		5%	4.20%
Finance leases		5.80%	4.20%

Leases - Components of Lease Ex

Leases - Components of Lease Expense Schedule (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Leases [Abstract]
Operating lease expense	$ 120,552	$ 116,769	$ 117,292
Finance lease expense:
Amortization of right-of-use assets	13,007	13,003	4,295
Interest on lease liabilities	3,156	2,593	733
Variable lease cost	12,968	4,448	3,645
Total lease expense	$ 149,683	$ 136,813	$ 125,965

Leases - Supplemental Cash Flow

Leases - Supplemental Cash Flow Information (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases			$ 127,923	$ 126,048	$ 129,577
Operating cash flows from finance leases			3,156	2,593	733
Financing cash flows from finance leases	$ 2,600	$ 3,071	11,923	11,713	3,990
Right-of-use assets obtained in exchange for lease obligations:
Operating leases			103,352	61,403	147,718
Finance leases			$ 38,061	$ 6,149	$ 64,334

Leases - Schedule of Operating

Leases - Schedule of Operating and Finance Lease Maturities (Details) - USD ($) $ in Thousands	Mar. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Operating
2024		$ 118,006
2025		65,436
2026		50,145
2027		31,644
2028		24,398
Thereafter		163,651
Future minimum lease payments		453,280
Less: imputed interest		96,828
Total operating lease liabilities		356,452	$ 364,141
Less: current obligations	$ 97,973	106,973	109,926
Noncurrent operating lease liabilities	$ 309,370	249,479	254,215
Finance
2024		15,375
2025		13,650
2026		12,537
2027		11,442
2028		10,766
Thereafter		46,869
Future minimum lease payments		110,639
Less: imputed interest		24,937
Total finance lease liabilities		85,702	61,083
Less: current obligations		10,842	10,722
Long-term lease obligations		$ 74,860	$ 50,361

Leases - Schedule of Lease Inco

Leases - Schedule of Lease Income (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Leases [Abstract]
Operating lease revenues	$ 16,879	$ 14,346	$ 15,281
Sales-type lease interest income	1,634	2,515	2,545
Lease revenues relating to variable lease payments not included in measurement of the sales-type lease receivable	$ 1,325	$ 1,782	$ 2,162

Leases - Schedule of Minimum Un

Leases - Schedule of Minimum Undiscounted Lease Payments (Details) $ in Thousands	Dec. 31, 2023 USD ($)
Operating
2024	$ 12,994
2025	3,441
2026	0
2027	0
2028	0
Thereafter	0
Total lease payment receipts	16,435
Sales-type
2024	2,170
2025	2,170
2026	2,170
2027	2,170
2028	2,170
Thereafter	13,560
Total lease payment receipts	24,410
Less: imputed interest	(15,945)
Total lease receivable	8,465
Unguaranteed residual assets at end of leases	25,180
Net investment in leases	$ 33,645

Leases - Schedule of Net Invest

Leases - Schedule of Net Investments (Details) - USD ($) $ in Thousands	Dec. 31, 2023	Dec. 31, 2022
Leases [Abstract]
Lease receivables	$ 18,830	$ 23,797
Unguaranteed residual assets	14,815	10,383
Net investment in leases	$ 33,645	$ 34,180

Properties, Plants and Equipm_3

Properties, Plants and Equipment - Components Of Property, Plants And Equipment (Details) - USD ($) $ in Thousands	Mar. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Property, Plant and Equipment [Line Items]
Properties, plants and equipment, at cost	$ 10,609,735	$ 10,533,432	$ 10,146,652
Less: accumulated depreciation	(4,021,845)	(3,906,600)	(3,457,747)
Properties, plants and equipment, net	$ 6,587,890	6,626,832	6,688,905
Land, buildings and improvements
Property, Plant and Equipment [Line Items]
Properties, plants and equipment, at cost		765,826	741,874
Refining facilities
Property, Plant and Equipment [Line Items]
Properties, plants and equipment, at cost		6,593,768	6,346,422
Pipelines and terminals
Property, Plant and Equipment [Line Items]
Properties, plants and equipment, at cost		2,300,781	2,267,052
Transportation vehicles
Property, Plant and Equipment [Line Items]
Properties, plants and equipment, at cost		37,870	43,801
Other fixed assets
Property, Plant and Equipment [Line Items]
Properties, plants and equipment, at cost		543,966	422,583
Construction in progress
Property, Plant and Equipment [Line Items]
Properties, plants and equipment, at cost		$ 291,221	$ 324,920

Properties, Plants and Equipm_4

Properties, Plants and Equipment - Narrative (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Property, Plant and Equipment [Abstract]
Capitalized interest	$ 0.7	$ 1.2	$ 4.3	$ 6.2	$ 15.2
Depreciation expense			$ 474.3	$ 442.2	$ 329.4

Goodwill and Intangibles - Narr

Goodwill and Intangibles - Narrative (Details) - USD ($)		12 Months Ended
Goodwill and Intangibles - Narrative (Details) - USD ($)	Jul. 01, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Mar. 31, 2024
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill		$ 2,977,744,000	$ 2,978,315,000		$ 2,977,511,000
Impairment of goodwill	$ 0		0	$ 0
Amortization expense		$ 55,100,000	$ 51,000,000	$ 35,600,000

Goodwill and Intangibles - Sche

Goodwill and Intangibles - Schedule Goodwill by Segment (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Mar. 31, 2024
Goodwill [Roll Forward]
Goodwill at beginning of period	$ 2,978,315
Goodwill disposal and other changes	(943)
Foreign currency translation adjustment	372
Goodwill at end of period	2,977,744
Goodwill	3,521,641
Accumulated impairment losses	(543,897)
Total goodwill	2,977,744	$ 2,977,511
Refining
Goodwill [Roll Forward]
Goodwill at beginning of period	1,977,435
Goodwill disposal and other changes	0
Foreign currency translation adjustment	0
Goodwill at end of period	1,977,435
Goodwill	2,286,753
Accumulated impairment losses	(309,318)
Total goodwill	1,977,435
Renewables
Goodwill [Roll Forward]
Goodwill at beginning of period	159,020
Goodwill disposal and other changes	0
Foreign currency translation adjustment	0
Goodwill at end of period	159,020
Goodwill	159,020
Accumulated impairment losses	0
Total goodwill	159,020
Marketing
Goodwill [Roll Forward]
Goodwill at beginning of period	163,839
Goodwill disposal and other changes	0
Foreign currency translation adjustment	0
Goodwill at end of period	163,839
Goodwill	163,839
Accumulated impairment losses	0
Total goodwill	163,839
Lubricants & Specialties
Goodwill [Roll Forward]
Goodwill at beginning of period	246,036
Goodwill disposal and other changes	(943)
Foreign currency translation adjustment	372
Goodwill at end of period	245,465
Goodwill	480,044
Accumulated impairment losses	(234,579)
Total goodwill	245,465
Midstream
Goodwill [Roll Forward]
Goodwill at beginning of period	431,985
Goodwill disposal and other changes	0
Foreign currency translation adjustment	0
Goodwill at end of period	431,985
Goodwill	431,985
Accumulated impairment losses	0
Total goodwill	$ 431,985

Goodwill and Intangibles - Sc_2

Goodwill and Intangibles - Schedule of Intangible Assets (Details) - USD ($) $ in Thousands	Dec. 31, 2023	Dec. 31, 2022
Finite-Lived Intangible Assets [Line Items]
Intangible assets	$ 671,355	$ 667,965
Accumulated amortization	(260,723)	(204,239)
Total intangibles, net	410,632	463,726
Customer relationships
Finite-Lived Intangible Assets [Line Items]
Intangible assets	$ 347,567	346,354
Customer relationships \| Minimum
Finite-Lived Intangible Assets [Line Items]
Useful Life	10 years
Customer relationships \| Maximum
Finite-Lived Intangible Assets [Line Items]
Useful Life	20 years
Transportation agreements
Finite-Lived Intangible Assets [Line Items]
Useful Life	30 years
Intangible assets	$ 59,933	59,933
Trademarks, patents and other
Finite-Lived Intangible Assets [Line Items]
Intangible assets	$ 263,855	$ 261,678
Trademarks, patents and other \| Minimum
Finite-Lived Intangible Assets [Line Items]
Useful Life	10 years
Trademarks, patents and other \| Maximum
Finite-Lived Intangible Assets [Line Items]
Useful Life	20 years

Goodwill and Intangibles - Sc_3

Goodwill and Intangibles - Schedule of Estimated Future Amortization Expense for Intangible Assets (Details) $ in Thousands	Dec. 31, 2023 USD ($)
Goodwill and Intangible Assets Disclosure [Abstract]
2024	$ 55,261
2025	55,261
2026	46,499
2027	40,753
2028	$ 34,253

Income Taxes - Provision For In

Income Taxes - Provision For Income Taxes (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Current
Federal			$ 179,677	$ 674,977	$ (33,206)
State			24,419	108,993	(1,802)
Foreign			44,966	57,734	30,336
Deferred
Federal			154,996	38,535	94,353
State			31,285	21,121	1,386
Foreign			6,269	(6,488)	32,831
Income tax expense (benefit) total	$ 85,474	$ 99,700	$ 441,612	$ 894,872	$ 123,898

Income Taxes - Reconciliation O

Income Taxes - Reconciliation Of Effective Tax Rate (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Income Tax Disclosure [Abstract]
Tax computed at statutory rate			$ 452,027	$ 826,570	$ 165,302
State income taxes, net of federal tax benefit			55,734	123,442	13,588
Noncontrolling interest in net income			(29,386)	(28,726)	(25,931)
Effect of change in state rate			0	(15,800)	(13,342)
Nontaxable permanent differences			(49,420)	0	0
CARES Act benefits			0	0	(10,384)
Foreign rate differential			5,753	6,608	331
Federal tax credits			(5,344)	(23,853)	(29,777)
US tax on non-US operations			7,239	12,920	18,547
Other			5,009	(6,289)	5,564
Income tax expense (benefit) total	$ 85,474	$ 99,700	$ 441,612	$ 894,872	$ 123,898

Income Taxes - Deferred Tax Ass

Income Taxes - Deferred Tax Assets And Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2023	Dec. 31, 2022
Income Tax Disclosure [Abstract]
Properties, plants, equipment and intangibles (due primarily to tax in excess of book depreciation)	$ (1,171,633)	$ (1,032,048)
Lease obligation	106,161	129,727
Accrued employee benefits	20,260	17,665
Accrued post-retirement benefits	9,985	9,951
Accrued environmental costs	42,916	37,868
Hedging instruments	1,791	3,260
Inventory differences	(164,178)	(230,112)
Deferred turnaround costs	(155,833)	(88,574)
Net operating loss and tax credit carryforwards	35,294	27,963
Investment in HEP		(134,160)
Deferred Tax Assets, Valuation Allowance	(10,614)	(3,691)
Other	(11,279)	(14)
Total deferred income tax assets	216,407	226,434
Total deferred income tax liabilities	(1,513,537)	(1,488,599)
Total deferred income tax assets and liabilities, net	$ (1,297,130)	$ (1,262,165)

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) - USD ($) $ in Thousands	12 Months Ended
Income Taxes - Narrative (Details) - USD ($) $ in Thousands	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Operating Loss Carryforwards [Line Items]
Valuation allowance	$ 10,614	$ 3,691
Unrecognized tax benefits	1,225	$ 1,354	$ 54,605	$ 54,899
Unrecognized tax benefit from claims filed with IRS	700
Foreign Tax Authority \| Luxembourg
Operating Loss Carryforwards [Line Items]
Net operating losses	17,600
Foreign Tax Authority \| Netherlands
Operating Loss Carryforwards [Line Items]
Net operating losses	11,200
Foreign Tax Authority \| China
Operating Loss Carryforwards [Line Items]
Net operating losses	$ 3,500

Income Taxes - Reconciliation_2

Income Taxes - Reconciliation Of Unrecognized Tax Benefits (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Reconciliation of Unrecognized Tax Benefits [Roll Forward]
Unrecognized tax benefits, balance at beginning of Period	$ 1,354	$ 54,605	$ 54,899
Reductions for tax positions of prior years	0	(53,023)	(49)
Settlements	0	0	(125)
Lapse of statute of limitations	(129)	(228)	(120)
Unrecognized tax benefits, balance at end of Period	$ 1,225	$ 1,354	$ 54,605

Pension and Post-retirement P_3

Pension and Post-retirement Plans - Changes in Benefit Obligation and Plan Assets (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Unrealized loss on pension obligations
Change in plans' benefit obligations
Pension plan's benefit obligation at beginning of period	$ 90,443	$ 120,414
Service cost	0	1,839	$ 4,455
Interest cost	3,781	3,086	2,740
Actuarial gain	2,097	(25,605)
Benefits paid	(5,472)	(2,306)
Settlements	(24,090)	0
Transfer from other plans	3,849	164
Foreign currency exchange rate changes	2,032	(7,149)
Pension plan's benefit obligation at end of period	72,640	90,443	120,414
Change in pension plans assets
Fair value of plan assets at beginning of period	87,466	119,325
Return on plans assets	7,146	(26,218)
Employer contributions	1,324	3,486
Benefits paid	(4,697)	(2,306)
Transfer payments	3,849	164
Settlements	(24,090)	0
Foreign currency exchange rate changes	2,020	(6,985)
Fair value of plan assets at end of period	73,018	87,466	119,325
Over (Under)-funded balance	378	(2,977)
Intangibles and other	1,149	0
Other long-term liabilities	(771)	(2,977)
Amounts recognized in consolidated balance sheets	378	(2,977)
Cumulative actuarial gain (loss)	(607)	(3,872)
Unrealized gain on post-retirement benefit obligations
Change in plans' benefit obligations
Pension plan's benefit obligation at beginning of period	28,678	34,816
Service cost	1,604	2,081	2,324
Interest cost	1,340	990	782
Actuarial gain	(761)	(7,884)
Benefits paid	(613)	(582)
Foreign currency exchange rate changes	249	(743)
Pension plan's benefit obligation at end of period	30,497	28,678	34,816
Change in pension plans assets
Fair value of plan assets at beginning of period	0	0
Employer contributions	603	572
Participant contributions	10	10
Fair value of plan assets at end of period	0	0	$ 0
Over (Under)-funded balance	(30,497)	(28,678)
Accrued liabilities	(1,701)	(1,706)
Other long-term liabilities	(28,796)	(26,972)
Amounts recognized in consolidated balance sheets	(30,497)	(28,678)
Cumulative actuarial gain (loss)	8,020	7,603
Prior service credit	8,069	11,550
Total	$ 16,089	$ 19,153

Pension and Post-retirement P_4

Pension and Post-retirement Plans - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Defined Benefit Plan Disclosure [Line Items]
Employee contribution expense	$ 80.8	$ 73.7	$ 45
Unrealized loss on pension obligations
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	72.6	$ 90.4
Expected contribution in pension plan	0.2
Expected benefit payment in 2024	1.9
Expected benefit payment in 2025	0.8
Expected benefit payment in 2026	0.9
Expected benefit payment in 2027	0.9
Expected benefit payment in 2028	1
Expected benefit payment from 2029 to 2032	$ 6
Unrealized loss on pension obligations \| Fixed income
Defined Benefit Plan Disclosure [Line Items]
Target investment rates	100%
Unrealized loss on pension obligations \| Minimum
Defined Benefit Plan Disclosure [Line Items]
Discount rate	4.60%	3.70%
Expected long-term rate of return on assets	4.60%
Unrealized loss on pension obligations \| Maximum
Defined Benefit Plan Disclosure [Line Items]
Discount rate	4.65%	4.44%
Expected long-term rate of return on assets	4.65%
Unrealized gain on post-retirement benefit obligations
Defined Benefit Plan Disclosure [Line Items]
Discount rate	3.60%	4.20%
Expected benefit payment in 2024	$ 1.7
Expected benefit payment in 2025	2.5
Expected benefit payment in 2026	2.5
Expected benefit payment in 2027	2.5
Expected benefit payment in 2028	2.7
Expected benefit payment from 2029 to 2032	$ 13.2
Unrealized gain on post-retirement benefit obligations \| Minimum
Defined Benefit Plan Disclosure [Line Items]
Discount rate	4.60%	4.95%
Unrealized gain on post-retirement benefit obligations \| Maximum
Defined Benefit Plan Disclosure [Line Items]
Discount rate	4.81%	5.10%

Pension and Post-retirement P_5

Pension and Post-retirement Plans - Projected and Accumulated Benefit Obligations (Details) - Unrealized loss on pension obligations - USD ($) $ in Thousands	Dec. 31, 2023	Dec. 31, 2022
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	$ 24,579	$ 90,443
Fair value of plan assets	23,808	87,466
Accumulated benefit obligation	24,579	90,443
Fair value of plan assets	$ 23,808	$ 87,466

Pension and Post-retirement P_6

Pension and Post-retirement Plans - Net Periodic Expense (Details) - Unrealized loss on pension obligations - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefit earned during the period	$ 0	$ 1,839	$ 4,455
Interest cost on projected benefit obligations	3,781	3,086	2,740
Expected return on plans assets	(3,140)	(3,223)	(3,031)
Amortization of (gain) loss	0	(208)	(407)
Settlements	1,378	0	0
Net periodic pension expense	$ 2,019	$ 1,494	$ 3,757

Pension and Post-retirement P_7

Pension and Post-retirement Plans - Defined Benefit plan, Allocation of Investment Funds (Details) - Unrealized loss on pension obligations - USD ($) $ in Thousands	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Defined Benefit Plan, Plan Assets, Allocation [Line Items]
Fair values of pension plan assets	$ 73,018	$ 87,466	$ 119,325
Fair Value, Recurring
Defined Benefit Plan, Plan Assets, Allocation [Line Items]
Fair values of pension plan assets	49,209	66,752
Fair Value, Recurring \| Fixed income
Defined Benefit Plan, Plan Assets, Allocation [Line Items]
Fair values of pension plan assets	49,209	66,752
Fair Value, Recurring \| Level 1
Defined Benefit Plan, Plan Assets, Allocation [Line Items]
Fair values of pension plan assets	822	457
Fair Value, Recurring \| Level 1 \| Fixed income
Defined Benefit Plan, Plan Assets, Allocation [Line Items]
Fair values of pension plan assets	822	457
Fair Value, Recurring \| Level 2
Defined Benefit Plan, Plan Assets, Allocation [Line Items]
Fair values of pension plan assets	48,387	66,295
Fair Value, Recurring \| Level 2 \| Fixed income
Defined Benefit Plan, Plan Assets, Allocation [Line Items]
Fair values of pension plan assets	48,387	66,295
Fair Value, Recurring \| Level 3
Defined Benefit Plan, Plan Assets, Allocation [Line Items]
Fair values of pension plan assets	0	0
Fair Value, Recurring \| Level 3 \| Fixed income
Defined Benefit Plan, Plan Assets, Allocation [Line Items]
Fair values of pension plan assets	$ 0	$ 0

Pension and Post-retirement P_8

Pension and Post-retirement Plans - Weighted Average Assumptions Used to Determine End of Period Benefit Obligations (Details) - Unrealized gain on post-retirement benefit obligations	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Defined Benefit Plan Disclosure [Line Items]
Discount rate	3.60%	4.20%
Minimum
Defined Benefit Plan Disclosure [Line Items]
Discount rate	4.60%	4.95%
Current health care trend rate	6%	6%
Ultimate health care trend rate	4%	4%
Year rate reaches ultimate trend rate	2035	2027
Maximum
Defined Benefit Plan Disclosure [Line Items]
Discount rate	4.81%	5.10%
Current health care trend rate	6.75%	7%
Ultimate health care trend rate	4%	4%
Year rate reaches ultimate trend rate	2041	2041

Pension and Post-retirement P_9

Pension and Post-retirement Plans - Net Periodic Credit (Details) - Unrealized gain on post-retirement benefit obligations - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefit earned during the period	$ 1,604	$ 2,081	$ 2,324
Interest cost on projected benefit obligations	1,340	990	782
Amortization of prior service credit	(3,481)	(3,472)	(3,481)
Amortization of (gain) loss	(378)	32	153
Net periodic post-retirement credit	$ (915)	$ (369)	$ (222)