~~Table of Contents~~

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, DC 20549


FORM			10-Q


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

For the quarterly period ended ~~March 31,~~September 30, 2023





OR
☐						TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from to

Commission file number 001-32597

CF INDUSTRIES HOLDINGS, INC.

(Exact name of registrant as specified in its charter)

Delaware

20-2697511

(State or other jurisdiction of
incorporation or organization)

(I.R.S. Employer
Identification No.)

4 Parkway North

60015

Deerfield, Illinois

(Zip Code)

(Address of principal executive offices)

(Registrant’s telephone number, including area code): (847) 405-2400

Securities registered pursuant to Section 12(b) of the Act:

Title of each class

Trading symbol(s)

Name of each exchange on which registered

common stock, par value $0.01 per share

New York Stock Exchange

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

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

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

Large accelerated filer

☒

Accelerated filer

☐

Non-accelerated filer

☐

Smaller reporting company

☐

Emerging growth company

☐

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

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

~~194,919,933~~191,056,501 shares of the registrant’s common stock, par value $0.01 per share, were outstanding at ~~April 28,~~October 31, 2023.

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CF INDUSTRIES HOLDINGS, INC.

TABLE OF CONTENTS

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CF INDUSTRIES HOLDINGS, INC.

PART I—FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS.

CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)


		Three months ended March 31,			Three months ended September 30,						Nine months ended September 30,
			2023			2022			2023		2022		2023		2022
			(in millions, except per share amounts)						(in millions, except per share amounts)
Net sales	Net sales		$	2,012		$	2,868	Net sales	$	1,273	$	2,321	$	5,060	$	8,578
Cost of sales	Cost of sales		1,149			1,170		Cost of sales	896		1,405		3,016		3,973
Gross margin	Gross margin		863			1,698		Gross margin	377		916		2,044		4,605
Selling, general and administrative expenses	Selling, general and administrative expenses		74			64		Selling, general and administrative expenses	68		66		213		203

U.K. long-lived and intangible asset impairment								U.K. long-lived and intangible asset impairment	—		87		—		239

U.K. operations restructuring	U.K. operations restructuring		2			—		U.K. operations restructuring	5		8		7		18
Transaction costs	Transaction costs		13			—		Transaction costs	11		—		27		—
Other operating—net	Other operating—net		(35)			2		Other operating—net	13		25		(19)		33
Total other operating costs and expenses	Total other operating costs and expenses		54			66		Total other operating costs and expenses	97		186		228		493

Equity in earnings of operating affiliate			17			26
Equity in (losses) earnings of operating affiliate								Equity in (losses) earnings of operating affiliate	(36)		20		(12)		74
Operating earnings	Operating earnings		826			1,658		Operating earnings	244		750		1,804		4,186
Interest expense	Interest expense		40			241		Interest expense	39		46		115		369
Interest income	Interest income		(30)			(36)		Interest income	(45)		(12)		(115)		(56)

Loss on debt extinguishment								Loss on debt extinguishment	—		—		—		8
Other non-operating—net	Other non-operating—net		(3)			1		Other non-operating—net	(3)		23		(8)		24
Earnings before income taxes	Earnings before income taxes		819			1,452		Earnings before income taxes	253		693		1,812		3,841
Income tax provision	Income tax provision		169			401		Income tax provision	23		155		326		913

Net earnings	Net earnings		650			1,051		Net earnings	230		538		1,486		2,928
Less: Net earnings attributable to noncontrolling interest	Less: Net earnings attributable to noncontrolling interest		90			168		Less: Net earnings attributable to noncontrolling interest	66		100		235		442
Net earnings attributable to common stockholders	Net earnings attributable to common stockholders		$	560		$	883	Net earnings attributable to common stockholders	$	164	$	438	$	1,251	$	2,486
Net earnings per share attributable to common stockholders:	Net earnings per share attributable to common stockholders:							Net earnings per share attributable to common stockholders:
Basic	Basic		$	2.86		$	4.23	Basic	$	0.85	$	2.19	$	6.44	$	12.09
Diluted	Diluted		$	2.85		$	4.21	Diluted	$	0.85	$	2.18	$	6.42	$	12.04
Weighted-average common shares outstanding:	Weighted-average common shares outstanding:							Weighted-average common shares outstanding:
Basic	Basic		196.2			208.6		Basic	192.4		200.2		194.4		205.6
Diluted	Diluted		196.9			209.9		Diluted	192.9		200.9		194.9		206.5
Dividends declared per common share	Dividends declared per common share		$	0.40		$	0.30	Dividends declared per common share	$	0.40	$	0.40	$	1.20	$	1.10

See accompanying Notes to Unaudited Consolidated Financial Statements.

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CF INDUSTRIES HOLDINGS, INC.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)


		Three months ended March 31,			Three months ended September 30,						Nine months ended September 30,
			2023			2022			2023		2022		2023		2022
			(in millions)						(in millions)
Net earnings	Net earnings		$	650		$	1,051	Net earnings	$	230	$	538	$	1,486	$	2,928
Other comprehensive income (loss):
Other comprehensive (loss) income:								Other comprehensive (loss) income:
Foreign currency translation adjustment—net of taxes	Foreign currency translation adjustment—net of taxes		7			(13)		Foreign currency translation adjustment—net of taxes	(27)		(9)		3		(49)

Defined benefit plans—net of taxes	Defined benefit plans—net of taxes		(1)			4		Defined benefit plans—net of taxes	1		24		2		36
			6			(9)			(26)		15		5		(13)
Comprehensive income	Comprehensive income		656			1,042		Comprehensive income	204		553		1,491		2,915
Less: Comprehensive income attributable to noncontrolling interest	Less: Comprehensive income attributable to noncontrolling interest		90			168		Less: Comprehensive income attributable to noncontrolling interest	66		100		235		442
Comprehensive income attributable to common stockholders	Comprehensive income attributable to common stockholders		$	566		$	874	Comprehensive income attributable to common stockholders	$	138	$	453	$	1,256	$	2,473

See accompanying Notes to Unaudited Consolidated Financial Statements.

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CF INDUSTRIES HOLDINGS, INC.

CONSOLIDATED BALANCE SHEETS


		(Unaudited)					(Unaudited)
		March 31, 2023		December 31, 2022			September 30, 2023		December 31, 2022
		(in millions, except share and per share amounts)					(in millions, except share and per share amounts)
Assets	Assets					Assets
Current assets:	Current assets:					Current assets:
Cash and cash equivalents	Cash and cash equivalents	$	2,825	$	2,323	Cash and cash equivalents	$	3,254	$	2,323

Accounts receivable—net	Accounts receivable—net	482		582		Accounts receivable—net	417		582
Inventories	Inventories	430		474		Inventories	318		474

Prepaid income taxes	Prepaid income taxes	69		215		Prepaid income taxes	147		215
Other current assets	Other current assets	42		79		Other current assets	54		79
Total current assets	Total current assets	3,848		3,673		Total current assets	4,190		3,673
Property, plant and equipment—net	Property, plant and equipment—net	6,294		6,437		Property, plant and equipment—net	6,156		6,437
Investment in affiliate	Investment in affiliate	81		74		Investment in affiliate	32		74
Goodwill	Goodwill	2,089		2,089		Goodwill	2,089		2,089
Operating lease right-of-use assets	Operating lease right-of-use assets	288		254		Operating lease right-of-use assets	277		254
Other assets	Other assets	798		786		Other assets	799		786
Total assets	Total assets	$	13,398	$	13,313	Total assets	$	13,543	$	13,313
Liabilities and Equity	Liabilities and Equity					Liabilities and Equity
Current liabilities:	Current liabilities:					Current liabilities:

Accounts payable and accrued expenses	Accounts payable and accrued expenses	$	452	$	575	Accounts payable and accrued expenses	$	497	$	575
Income taxes payable	Income taxes payable	10		3		Income taxes payable	20		3
Customer advances	Customer advances	284		229		Customer advances	282		229
Current operating lease liabilities	Current operating lease liabilities	104		93		Current operating lease liabilities	101		93

Other current liabilities	Other current liabilities	12		95		Other current liabilities	26		95
Total current liabilities	Total current liabilities	862		995		Total current liabilities	926		995
Long-term debt	Long-term debt	2,966		2,965		Long-term debt	2,967		2,965
Deferred income taxes	Deferred income taxes	933		958		Deferred income taxes	882		958
Operating lease liabilities	Operating lease liabilities	182		167		Operating lease liabilities	179		167
Other liabilities	Other liabilities	365		375		Other liabilities	288		375
Equity:	Equity:					Equity:
Stockholders’ equity:	Stockholders’ equity:					Stockholders’ equity:
Preferred stock—$0.01 par value, 50,000,000 shares authorized	Preferred stock—$0.01 par value, 50,000,000 shares authorized	—		—		Preferred stock—$0.01 par value, 50,000,000 shares authorized	—		—
Common stock—$0.01 par value, 500,000,000 shares authorized, 2023—196,237,302 shares issued and 2022—195,604,404 shares issued		2		2
Common stock—$0.01 par value, 500,000,000 shares authorized, 2023—192,963,252 shares issued and 2022—195,604,404 shares issued						Common stock—$0.01 par value, 500,000,000 shares authorized, 2023—192,963,252 shares issued and 2022—195,604,404 shares issued	2		2
Paid-in capital	Paid-in capital	1,424		1,412		Paid-in capital	1,416		1,412
Retained earnings	Retained earnings	4,348		3,867		Retained earnings	4,681		3,867
Treasury stock—at cost, 2023—1,319,380 shares and 2022—0 shares		(97)		—
Treasury stock—at cost, 2023—1,911,732 shares and 2022—0 shares						Treasury stock—at cost, 2023—1,911,732 shares and 2022—0 shares	(151)		—
Accumulated other comprehensive loss	Accumulated other comprehensive loss	(224)		(230)		Accumulated other comprehensive loss	(225)		(230)
Total stockholders’ equity	Total stockholders’ equity	5,453		5,051		Total stockholders’ equity	5,723		5,051
Noncontrolling interest	Noncontrolling interest	2,637		2,802		Noncontrolling interest	2,578		2,802
Total equity	Total equity	8,090		7,853		Total equity	8,301		7,853
Total liabilities and equity	Total liabilities and equity	$	13,398	$	13,313	Total liabilities and equity	$	13,543	$	13,313

See accompanying Notes to Unaudited Consolidated Financial Statements.

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CF INDUSTRIES HOLDINGS, INC.

CONSOLIDATED STATEMENTS OF EQUITY

(Unaudited)


																		Common Stockholders
																		$0.01 Par Value Common Stock		Treasury Stock		Paid-In Capital		Retained Earnings		Accumulated Other Comprehensive Loss		Total Stockholders’ Equity		Noncontrolling Interest		Total Equity
																		(in millions, except per share amounts)
Balance as of June 30, 2023																	Balance as of June 30, 2023	$	2	$	(226)	$	1,430	$	4,797	$	(199)	$	5,804	$	2,716	$	8,520
Net earnings																	Net earnings	—		—		—		164		—		164		66		230
Other comprehensive loss																	Other comprehensive loss	—		—		—		—		(26)		(26)		—		(26)
Purchases of treasury stock																	Purchases of treasury stock	—		(151)		—		—		—		(151)		—		(151)
Retirement of treasury stock																	Retirement of treasury stock	—		226		(24)		(202)		—		—		—		—

Stock-based compensation expense																	Stock-based compensation expense	—		—		10		—		—		10		—		10

Dividends and dividend equivalents ($0.40 per share)																	Dividends and dividend equivalents ($0.40 per share)	—		—		—		(78)		—		(78)		—		(78)

Distribution declared to noncontrolling interest																	Distribution declared to noncontrolling interest	—		—		—		—		—		—		(204)		(204)

Balance as of September 30, 2023																	Balance as of September 30, 2023	$	2	$	(151)	$	1,416	$	4,681	$	(225)	$	5,723	$	2,578	$	8,301

	Common Stockholders
	$0.01 Par Value Common Stock		Treasury Stock		Paid-In Capital		Retained Earnings		Accumulated Other Comprehensive Loss		Total Stockholders’ Equity		Noncontrolling Interest		Total Equity
	(in millions, except per share amounts)

Balance as of December 31, 2022	$	2	$	—	$	1,412	$	3,867	$	(230)	$	5,051	$	2,802	$	7,853
Net earnings	—		—		—		560		—		560		90		650
Other comprehensive income	—		—		—		—		6		6		—		6
Purchases of treasury stock	—		(75)		—		—		—		(75)		—		(75)

Acquisition of treasury stock under employee stock plans	—		(22)		—		—		—		(22)		—		(22)

Stock-based compensation expense	—		—		12		—		—		12		—		12

Dividends and dividend equivalents ($0.40 per share)	—		—		—		(79)		—		(79)		—		(79)

Distribution declared to noncontrolling interest	—		—		—		—		—		—		(255)		(255)

Balance as of March 31, 2023	$	2	$	(97)	$	1,424	$	4,348	$	(224)	$	5,453	$	2,637	$	8,090

























Balance as of December 31, 2022	$	2	$	—	$	1,412	$	3,867	$	(230)	$	5,051	$	2,802	$	7,853
Net earnings	—		—		—		1,251		—		1,251		235		1,486
Other comprehensive income	—		—		—		—		5		5		—		5
Purchases of treasury stock	—		(357)		—		—		—		(357)		—		(357)
Retirement of treasury stock	—		226		(24)		(202)		—		—		—		—
Acquisition of treasury stock under employee stock plans	—		(22)		—		—		—		(22)		—		(22)
Issuance of $0.01 par value common stock under employee stock plans	—		2		(1)		—		—		1		—		1

Stock-based compensation expense	—		—		29		—		—		29		—		29

Dividends and dividend equivalents ($1.20 per share)	—		—		—		(235)		—		(235)		—		(235)



Distributions declared to noncontrolling interest	—		—		—		—		—		—		(459)		(459)

Balance as of September 30, 2023	$	2	$	(151)	$	1,416	$	4,681	$	(225)	$	5,723	$	2,578	$	8,301

(Continued)

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CF INDUSTRIES HOLDINGS, INC.

CONSOLIDATED STATEMENTS OF EQUITY

(Continued) (Unaudited)


									Common Stockholders
																					$0.01 Par Value Common Stock		Treasury Stock		Paid-In Capital		Retained Earnings		Accumulated Other Comprehensive Loss		Total Stockholders’ Equity		Noncontrolling Interest		Total Equity
				(in millions, except per share amounts)
Balance as of June 30, 2022																				Balance as of June 30, 2022	$	2	$	(331)	$	1,474	$	3,729	$	(285)	$	4,589	$	2,925	$	7,514

Net earnings																				Net earnings	—		—		—		438		—		438		100		538
Other comprehensive income																				Other comprehensive income	—		—		—		—		15		15		—		15
Purchases of treasury stock																				Purchases of treasury stock	—		(532)		—		—		—		(532)		—		(532)

Issuance of $0.01 par value common stock under employee stock plans																				Issuance of $0.01 par value common stock under employee stock plans	—		—		4		—		—		4		—		4

Stock-based compensation expense																				Stock-based compensation expense	—		—		10		—		—		10		—		10

Cash dividends ($0.40 per share)																				Cash dividends ($0.40 per share)	—		—		—		(80)		—		(80)		—		(80)

Distribution declared to noncontrolling interest																				Distribution declared to noncontrolling interest	—		—		—		—		—		—		(372)		(372)

Balance as of September 30, 2022																				Balance as of September 30, 2022	$	2	$	(863)	$	1,488	$	4,087	$	(270)	$	4,444	$	2,653	$	7,097

Balance as of December 31, 2021	Balance as of December 31, 2021	$	2		$	(2)	$	1,375		$	2,088	$	(257)	$	3,206	$	2,830	$	6,036	Balance as of December 31, 2021	$	2	$	(2)	$	1,375	$	2,088	$	(257)	$	3,206	$	2,830	$	6,036

Net earnings	Net earnings	—			—		—			883		—		883		168		1,051		Net earnings	—		—		—		2,486		—		2,486		442		2,928
Other comprehensive loss	Other comprehensive loss	—			—		—			—		(9)		(9)		—		(9)		Other comprehensive loss	—		—		—		—		(13)		(13)		—		(13)
Purchases of treasury stock	Purchases of treasury stock	—			(100)		—			—		—		(100)		—		(100)		Purchases of treasury stock	—		(1,122)		—		—		—		(1,122)		—		(1,122)
Retirement of treasury stock	Retirement of treasury stock	—			2		—			—		—		2		—		2		Retirement of treasury stock	—		283		(23)		(260)		—		—		—		—
Acquisition of treasury stock under employee stock plans	Acquisition of treasury stock under employee stock plans	—			(23)		—			—		—		(23)		—		(23)		Acquisition of treasury stock under employee stock plans	—		(23)		—		—		—		(23)		—		(23)
Issuance of $0.01 par value common stock under employee stock plans	Issuance of $0.01 par value common stock under employee stock plans	—			—		97			—		—		97		—		97		Issuance of $0.01 par value common stock under employee stock plans	—		1		104		—		—		105		—		105

Stock-based compensation expense	Stock-based compensation expense	—			—		10			—		—		10		—		10		Stock-based compensation expense	—		—		32		—		—		32		—		32

Dividends and dividend equivalents ($0.30 per share)		—			—		—			(64)		—		(64)		—		(64)
Cash dividends ($1.10 per share)																				Cash dividends ($1.10 per share)	—		—		—		(227)		—		(227)		—		(227)

Distribution declared to noncontrolling interest		—			—		—			—		—		—		(247)		(247)
Distributions declared to noncontrolling interest																				Distributions declared to noncontrolling interest	—		—		—		—		—		—		(619)		(619)

Balance as of March 31, 2022		$	2		$	(123)	$	1,482		$	2,907	$	(266)	$	4,002	$	2,751	$	6,753
Balance as of September 30, 2022																				Balance as of September 30, 2022	$	2	$	(863)	$	1,488	$	4,087	$	(270)	$	4,444	$	2,653	$	7,097

See accompanying Notes to Unaudited Consolidated Financial Statements.

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CF INDUSTRIES HOLDINGS, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


		Three months ended March 31,					Nine months ended September 30,
		2023		2022			2023		2022
		(in millions)					(in millions)
Operating Activities:	Operating Activities:					Operating Activities:
Net earnings	Net earnings	$	650	$	1,051	Net earnings	$	1,486	$	2,928
Adjustments to reconcile net earnings to net cash provided by operating activities:	Adjustments to reconcile net earnings to net cash provided by operating activities:					Adjustments to reconcile net earnings to net cash provided by operating activities:
Depreciation and amortization	Depreciation and amortization	206		208		Depreciation and amortization	640		652
Deferred income taxes	Deferred income taxes	(26)		(2)		Deferred income taxes	(73)		(7)
Stock-based compensation expense	Stock-based compensation expense	12		10		Stock-based compensation expense	29		32

Loss on debt extinguishment						Loss on debt extinguishment	—		8
Unrealized net gain on natural gas derivatives	Unrealized net gain on natural gas derivatives	(72)		(33)		Unrealized net gain on natural gas derivatives	(65)		(39)

Impairment of equity method investment in PLNL						Impairment of equity method investment in PLNL	43		—
U.K. long-lived and intangible asset impairment						U.K. long-lived and intangible asset impairment	—		239
Pension settlement loss						Pension settlement loss	—		24
Gain on sale of emission credits	Gain on sale of emission credits	(35)		—		Gain on sale of emission credits	(39)		(6)

Loss on disposal of property, plant and equipment						Loss on disposal of property, plant and equipment	4		1
Undistributed earnings of affiliate—net of taxes	Undistributed earnings of affiliate—net of taxes	(7)		(2)		Undistributed earnings of affiliate—net of taxes	(2)		(10)
Changes in:	Changes in:					Changes in:
Accounts receivable—net	Accounts receivable—net	101		(185)		Accounts receivable—net	165		(245)
Inventories	Inventories	39		(66)		Inventories	130		(131)
Accrued and prepaid income taxes	Accrued and prepaid income taxes	153		387		Accrued and prepaid income taxes	57		(168)
Accounts payable and accrued expenses	Accounts payable and accrued expenses	(135)		76		Accounts payable and accrued expenses	(116)		111
Customer advances	Customer advances	55		(102)		Customer advances	53		(188)
Other—net	Other—net	6		49		Other—net	(35)		69
Net cash provided by operating activities	Net cash provided by operating activities	947		1,391		Net cash provided by operating activities	2,277		3,270
Investing Activities:	Investing Activities:					Investing Activities:
Additions to property, plant and equipment	Additions to property, plant and equipment	(69)		(63)		Additions to property, plant and equipment	(311)		(319)
Proceeds from sale of property, plant and equipment	Proceeds from sale of property, plant and equipment	—		1		Proceeds from sale of property, plant and equipment	1		1

Distributions received from unconsolidated affiliate						Distributions received from unconsolidated affiliate	—		4

Purchase of investments held in nonqualified employee benefit trust						Purchase of investments held in nonqualified employee benefit trust	—		(1)
Proceeds from sale of investments held in nonqualified employee benefit trust						Proceeds from sale of investments held in nonqualified employee benefit trust	—		1
Purchase of emission credits	Purchase of emission credits	—		(9)		Purchase of emission credits	—		(9)
Proceeds from sale of emission credits	Proceeds from sale of emission credits	35		9		Proceeds from sale of emission credits	39		15

Net cash used in investing activities	Net cash used in investing activities	(34)		(62)		Net cash used in investing activities	(271)		(308)
Financing Activities:	Financing Activities:					Financing Activities:

Payments of long-term borrowings						Payments of long-term borrowings	—		(507)
Financing fees	Financing fees	—		(4)		Financing fees	—		(4)
Dividends paid	Dividends paid	(79)		(64)		Dividends paid	(235)		(227)

Distributions to noncontrolling interest	Distributions to noncontrolling interest	(255)		(247)		Distributions to noncontrolling interest	(459)		(619)
Purchases of treasury stock	Purchases of treasury stock	(54)		(98)		Purchases of treasury stock	(355)		(1,096)
Proceeds from issuances of common stock under employee stock plans	Proceeds from issuances of common stock under employee stock plans	—		97		Proceeds from issuances of common stock under employee stock plans	1		106
Cash paid for shares withheld for taxes	Cash paid for shares withheld for taxes	(22)		(23)		Cash paid for shares withheld for taxes	(22)		(23)

Net cash used in financing activities	Net cash used in financing activities	(410)		(339)		Net cash used in financing activities	(1,070)		(2,370)
Effect of exchange rate changes on cash and cash equivalents	Effect of exchange rate changes on cash and cash equivalents	(1)		(1)		Effect of exchange rate changes on cash and cash equivalents	(5)		(28)
Increase in cash and cash equivalents	Increase in cash and cash equivalents	502		989		Increase in cash and cash equivalents	931		564
Cash and cash equivalents at beginning of period	Cash and cash equivalents at beginning of period	2,323		1,628		Cash and cash equivalents at beginning of period	2,323		1,628
Cash and cash equivalents at end of period	Cash and cash equivalents at end of period	$	2,825	$	2,617	Cash and cash equivalents at end of period	$	3,254	$	2,192

See accompanying Notes to Unaudited Consolidated Financial Statements.

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NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

1. Background and Basis of Presentation

Our mission is to provide clean energy to feed and fuel the world sustainably. With our employees focused on safe and reliable operations, environmental stewardship, and disciplined capital and corporate management, we are on a path to decarbonize our ammonia production network – the world’s largest – to enable green and blue hydrogen and nitrogen products for energy, fertilizer, emissions abatement and other industrial activities. Our nitrogen manufacturing complexes in the United States, Canada and the United Kingdom, an extensive storage, transportation and distribution network in North America, and logistics capabilities enabling a global reach underpin our strategy to leverage our unique capabilities to accelerate the world’s transition to clean energy. Our principal customers are cooperatives, independent fertilizer distributors, traders, wholesalers and industrial users. Our core product is anhydrous ammonia (ammonia), which contains 82% nitrogen and 18% hydrogen. Our nitrogen products that are upgraded from ammonia are granular urea, urea ammonium nitrate solution (UAN) and ammonium nitrate (AN). Our other nitrogen products include diesel exhaust fluid (DEF), urea liquor, nitric acid and aqua ammonia, which are sold primarily to our industrial customers.

All references to “CF Holdings,” “the Company,” “we,” “us” and “our” refer to CF Industries Holdings, Inc. and its subsidiaries, except where the context makes clear that the reference is only to CF Industries Holdings, Inc. itself and not its subsidiaries. All references to “CF Industries” refer to CF Industries, Inc., a 100% owned subsidiary of CF Industries Holdings, Inc.

The accompanying unaudited interim consolidated financial statements have been prepared on the same basis as our audited consolidated financial statements for the year ended December 31, 2022, in accordance with U.S. generally accepted accounting principles (GAAP) for interim financial reporting. In the opinion of management, these statements reflect all adjustments, consisting only of normal and recurring adjustments, that are necessary for the fair representation of the information for the periods presented. The accompanying unaudited interim consolidated financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (SEC). Certain information and disclosures normally included in financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to such rules and regulations. Operating results for any period presented apply to that period only and are not necessarily indicative of results for any future period.

The accompanying unaudited interim consolidated financial statements should be read in conjunction with our audited consolidated financial statements and related disclosures included in our Annual Report on Form 10-K for the fiscal year ended December 31, 2022, filed with the SEC on February 23, 2023. The preparation of the unaudited interim consolidated financial statements requires us to make use of estimates and assumptions that may significantly affect the reported amounts of assets and liabilities and disclosure of contingent liabilities at the date of the unaudited interim consolidated financial statements and the reported revenues and expenses for the periods presented. Such estimates and assumptions are used for, but are not limited to, net realizable value of inventories, environmental remediation liabilities, environmental and litigation contingencies, plant closure and asset retirement obligations, the cost of emission credits required to meet environmental regulations, the cost of customer incentives, useful lives of property and identifiable intangible assets, the evaluation of potential impairments of property, investments, identifiable intangible assets and goodwill, income tax reserves and the assessment of the realizability of deferred tax assets, the determination of the funded status and annual expense of defined benefit pension and other postretirement plans and the valuation of stock-based compensation awards granted to employees.

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2. Revenue Recognition

We track our revenue by product and by geography. See Note ~~14—~~16—Segment Disclosures for the revenue of each of our reportable segments, which are Ammonia, Granular Urea, UAN, AN and Other. The following table summarizes our revenue by product and by geography (based on destination of our shipment) for the three and nine months ended ~~March 31,~~September 30, 2023 and 2022:


		Ammonia		Granular Urea		UAN		AN		Other		Total			Ammonia		Granular Urea		UAN		AN		Other		Total
		(in millions)													(in millions)

Three months ended March 31, 2023
Three months ended September 30, 2023														Three months ended September 30, 2023
North America	North America	$	330	$	575	$	519	$	74	$	126	$	1,624	North America	$	165	$	340	$	330	$	50	$	111	$	996
Europe and other	Europe and other	94		36		148		85		25		388		Europe and other	70		20		105		64		18		277

Total revenue	Total revenue	$	424	$	611	$	667	$	159	$	151	$	2,012	Total revenue	$	235	$	360	$	435	$	114	$	129	$	1,273
Three months ended March 31, 2022
Three months ended September 30, 2022														Three months ended September 30, 2022
North America	North America	$	583	$	736	$	1,013	$	83	$	153	$	2,568	North America	$	367	$	571	$	531	$	70	$	132	$	1,671
Europe and other	Europe and other	57		29		2		140		72		300		Europe and other	164		118		205		110		53		650
Total revenue	Total revenue	$	640	$	765	$	1,015	$	223	$	225	$	2,868	Total revenue	$	531	$	689	$	736	$	180	$	185	$	2,321

Nine months ended September 30, 2023														Nine months ended September 30, 2023
North America														North America	$	955	$	1,375	$	1,312	$	189	$	357	$	4,188
Europe and other														Europe and other	229		56		338		188		61		872

Total revenue														Total revenue	$	1,184	$	1,431	$	1,650	$	377	$	418	$	5,060
Nine months ended September 30, 2022														Nine months ended September 30, 2022
North America														North America	$	1,937	$	2,123	$	2,421	$	229	$	465	$	7,175
Europe and other														Europe and other	349		164		306		427		157		1,403
Total revenue														Total revenue	$	2,286	$	2,287	$	2,727	$	656	$	622	$	8,578

As of ~~March 31,~~September 30, 2023 and December 31, 2022, we had ~~$284~~$282 million and $229 million, respectively, in customer advances on our consolidated balance sheets. ~~The revenue recognized during~~During the ~~three~~nine months ended ~~March 31,~~September 30, 2023 and 2022, ~~that was included in our~~substantially all of the customer advances at the beginning of each respective period ~~amounted to approximately $160 million and $560 million, respectively.~~were recognized as revenue.

We offer cash incentives to certain customers generally based on the volume of their purchases over the fertilizer year ending June 30. Our cash incentives do not provide an option to the customer for additional product. The balances of customer incentives accrued as of ~~March 31,~~September 30, 2023 and December 31, 2022 were not material.

We have certain customer contracts with performance obligations under which, if the customer does not take the required amount of product specified in the contract, then the customer is required to make a payment to us, the amount of which payment may vary based upon the terms and conditions of the applicable contract. As of ~~March 31,~~September 30, 2023, excluding contracts with original durations of less than one year, and based on the minimum product tonnage to be sold and current market price estimates, our remaining performance obligations under these contracts were approximately ~~$1.0 billion.~~$910 million. We expect to recognize approximately ~~34%~~14% of these performance obligations as revenue in the remainder of 2023, approximately ~~33%~~52% as revenue during 2024-2026, approximately 15% as revenue during 2027-2029, and the remainder thereafter. Subject to the terms and conditions of the applicable contracts, if the customers do not satisfy their purchase obligations under such contracts, the minimum amount that they would be required to pay to us under such contracts, in the aggregate, was approximately $280 million as of ~~March 31,~~September 30, 2023. Other than the performance obligations described above, we expect that any performance obligations ~~with~~under our ~~customers~~customer contracts that were unfulfilled or partially fulfilled at December 31, 2022 will be satisfied in 2023.

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3. Net Earnings Per Share

Net earnings per share were computed as follows:


		Three months ended March 31,			Three months ended September 30,						Nine months ended September 30,
			2023			2022			2023		2022		2023		2022
			(in millions, except per share amounts)						(in millions, except per share amounts)
Net earnings attributable to common stockholders	Net earnings attributable to common stockholders		$	560		$	883	Net earnings attributable to common stockholders	$	164	$	438	$	1,251	$	2,486
Basic earnings per common share:	Basic earnings per common share:							Basic earnings per common share:
Weighted-average common shares outstanding	Weighted-average common shares outstanding		196.2			208.6		Weighted-average common shares outstanding	192.4		200.2		194.4		205.6
Net earnings attributable to common stockholders	Net earnings attributable to common stockholders		$	2.86		$	4.23	Net earnings attributable to common stockholders	$	0.85	$	2.19	$	6.44	$	12.09
Diluted earnings per common share:	Diluted earnings per common share:							Diluted earnings per common share:
Weighted-average common shares outstanding	Weighted-average common shares outstanding		196.2			208.6		Weighted-average common shares outstanding	192.4		200.2		194.4		205.6
Dilutive common shares—stock-based awards	Dilutive common shares—stock-based awards		0.7			1.3		Dilutive common shares—stock-based awards	0.5		0.7		0.5		0.9
Diluted weighted-average common shares outstanding	Diluted weighted-average common shares outstanding		196.9			209.9		Diluted weighted-average common shares outstanding	192.9		200.9		194.9		206.5
Net earnings attributable to common stockholders	Net earnings attributable to common stockholders		$	2.85		$	4.21	Net earnings attributable to common stockholders	$	0.85	$	2.18	$	6.42	$	12.04

Diluted earnings per common share is calculated using weighted-average common shares outstanding, including the dilutive effect of stock-based awards as determined under the treasury stock method. In the computation of diluted earnings per common share, potentially dilutive stock-based awards are excluded if the effect of their inclusion is anti-dilutive. Shares for anti-dilutive stock-based awards not included in the computation of diluted earnings per common share were zero in both the three and nine months ended ~~March 31,~~September 30, 2023 and the three and nine months ended September 30, 2022.

4. Inventories

Inventories consist of the following:


		March 31, 2023		December 31, 2022			September 30, 2023		December 31, 2022
		(in millions)					(in millions)
Finished goods	Finished goods	$	393	$	437	Finished goods	$	279	$	437
Raw materials, spare parts and supplies	Raw materials, spare parts and supplies	37		37		Raw materials, spare parts and supplies	39		37
Total inventories	Total inventories	$	430	$	474	Total inventories	$	318	$	474

5. United Kingdom Operations Restructuring

In the second quarter of 2022, we approved and announced our proposed plan to restructure our U.K. operations, including the planned permanent closure of the Ince facility, which had been idled since September 2021, and optimization of the remaining manufacturing operations at our Billingham facility. Pursuant to our proposed plan to restructure our U.K. operations and dispose of the Ince facility assets before we originally intended, we concluded that an evaluation of our long-lived assets and an impairment test was required. Our assessment then identified the U.K. asset groups as U.K. Ammonia, U.K. AN and U.K. Other, comprising our ongoing U.K. operations, and Ince, U.K. In response to this impairment indicator, we compared the undiscounted cash flows expected to result from the use and eventual disposition of the Ince, U.K. asset group to its carrying amount and concluded the carrying amount was not recoverable and should be adjusted to its fair value. As a result, in the second quarter of 2022, we recorded total charges of $162 million related to the Ince facility as follows:

•asset impairment charges of $152 million consisting of the following:

◦an impairment charge of $135 million related to property, plant and equipment that is planned for abandonment at the Ince facility, including a liability of approximately $9 million for the costs of certain asset retirement activities related to the Ince site;

◦an intangible asset impairment charge of $8 million related to trade names; and

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◦an impairment charge of $9 million related to the write-down of spare parts and certain raw materials at the Ince facility;

and

•a charge for post-employment benefits totaling $10 million, which is included in the U.K. operations restructuring line item in our consolidated statements of operations, related to contractual and statutory obligations due to employees whose employment would be terminated in the proposed plan.

In August 2022, the final restructuring plan for our U.K. operations was approved, and decommissioning activities at our Ince facility were initiated. As a result, in the third quarter of 2022, we incurred additional charges related to our U.K. restructuring of $8 million, primarily related to one-time termination benefits, which are included in the U.K. operations restructuring line item in our consolidated statement of operations. As of June 30, 2023, the decommissioning of our Ince facility and other approved restructuring actions had been completed.

In the third quarter of 2022, the United Kingdom continued to experience extremely high and volatile natural gas prices. Russian natural gas pipeline flows to Europe via the Nord Stream 1 pipeline ceased, causing the United Kingdom to experience unprecedented natural gas prices. In addition, the European Union announced a desire to cap the price that Europe would pay Russia for natural gas deliveries, further contributing to the uncertainty in European energy markets. Given these factors and the lack of a corresponding increase in global nitrogen product market prices, in September 2022, we idled ammonia production at our Billingham complex. As a result, we concluded that an additional impairment test was triggered for the asset groups that comprise the continuing U.K. operations. The results of our impairment test indicated that the carrying values for our U.K. Ammonia and U.K. AN asset groups exceeded the undiscounted estimated future cash flows. As a result, we recognized asset impairment charges of $87 million, primarily related to property, plant and equipment and definite-lived intangible assets, which are included in the U.K. long-lived and intangible asset impairment line item in our consolidated statement of operations.

In July 2023, we approved and announced our proposed plan to permanently close the Billingham ammonia plant, and, in September 2023, the final plan was approved. As a result, in the third quarter of 2023, we recognized total charges of $5 million consisting primarily of the recognition of an asset retirement obligation and post-employment benefits related to contractual and statutory obligations due to employees whose employment would be terminated.

6. Property, Plant and Equipment—Net

Property, plant and equipment—net consists of the following:


		March 31, 2023		December 31, 2022			September 30, 2023		December 31, 2022
		(in millions)					(in millions)
Land	Land	$	113	$	113	Land	$	114	$	113
Machinery and equipment	Machinery and equipment	12,672		12,633		Machinery and equipment	12,716		12,633
Buildings and improvements	Buildings and improvements	920		914		Buildings and improvements	923		914
Construction in progress	Construction in progress	226		203		Construction in progress	339		203
Property, plant and equipment(1)	Property, plant and equipment(1)	13,931		13,863		Property, plant and equipment(1)	14,092		13,863
Less: Accumulated depreciation and amortization	Less: Accumulated depreciation and amortization	7,637		7,426		Less: Accumulated depreciation and amortization	7,936		7,426
Property, plant and equipment—net	Property, plant and equipment—net	$	6,294	$	6,437	Property, plant and equipment—net	$	6,156	$	6,437

(1)As of ~~March 31,~~September 30, 2023 and December 31, 2022, we had property, plant and equipment that was accrued but unpaid of approximately ~~$45~~$80 million and $53 million, respectively. As of ~~March 31,~~September 30, 2022 and December 31, 2021, we had property, plant and equipment that was accrued but unpaid of approximately ~~$22~~$60 million and $35 million, respectively.

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Depreciation and amortization related to property, plant and equipment was ~~$204~~$211 million and ~~$205~~$633 million for the three and nine months ended ~~March 31,~~September 30, 2023, respectively, and $219 million and $643 million for the three and nine months ended September 30, 2022, respectively.

Plant turnarounds—Scheduled inspections, replacements and overhauls of plant machinery and equipment at our continuous process manufacturing facilities during a full plant shutdown are referred to as plant turnarounds. The expenditures related to turnarounds are capitalized in property, plant and equipment when incurred.

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Scheduled replacements and overhauls of plant machinery and equipment during a plant turnaround include the dismantling, repair or replacement and installation of various components including piping, valves, motors, turbines, pumps, compressors and heat exchangers and the replacement of catalysts when a full plant shutdown occurs. Scheduled inspections, including required safety inspections which entail the disassembly of various components such as steam boilers, pressure vessels and other equipment requiring safety certifications, are also conducted during full plant shutdowns. Internal employee costs and overhead amounts are not considered turnaround costs and are not capitalized.

The following is a summary of capitalized plant turnaround costs:
Three months ended
March 31,
2023 2022
(in millions)
Net capitalized turnaround costs as of January 1 $ 312 $ 355
Additions 7 5
Depreciation (31) (36)
Effect of exchange rate changes — (1)
Net capitalized turnaround costs as of March 31 $ 288 $ 323


	Nine months ended September 30,
	2023		2022
	(in millions)
Net capitalized turnaround costs as of January 1	$	312	$	355
Additions	121		84

Depreciation	(95)		(101)
Impairment related to U.K. operations	—		(21)
Effect of exchange rate changes and other	(4)		(7)
Net capitalized turnaround costs as of September 30	$	334	$	310

6.7. Equity Method Investment

We have a 50% ownership interest in Point Lisas Nitrogen Limited (PLNL), which operates an ammonia production facility in the Republic of Trinidad and Tobago. We include our share of the net earnings from this equity method investment as an element of earnings from operations because PLNL provides additional production to our operations and is integrated with our other supply chain and sales activities in the Ammonia segment.

PLNL operates an ammonia plant that relies on natural gas supplied, under a gas sales contract (the NGC Contract), by The National Gas Company of Trinidad and Tobago Limited (NGC). The NGC Contract had an expiration date of September 2023. In the third quarter of 2023, PLNL entered into a new gas sales contract with NGC (the New NGC Contract), which is effective October 2023 through December 2025.

In the third quarter of 2023 and due to the terms of the New NGC Contract, we assessed our investment in PLNL for impairment and determined that the carrying value of our equity method investment in PLNL exceeded its fair value. As a result, we recorded an impairment of our equity method investment in PLNL of $43 million, which is reflected in equity in (losses) earnings of operating affiliate on our consolidated statements of operations for the three and nine months ended September 30, 2023. As of ~~March 31,~~September 30, 2023, the total carrying value of our equity method investment in PLNL was $81 million, $34 million more than our share of PLNL’s book value. The excess is attributable to the purchase accounting impact of our acquisition of the investment in PLNL and reflects the revaluation of property, plant and equipment. The increased basis for property, plant and equipment is being amortized over a remaining period of approximately 10 years. Our equity in earnings of PLNL is different from our ownership interest in income reported by PLNL due to amortization of this basis difference.$32 million.

We have transactions in the normal course of business with PLNL reflecting our obligation to purchase 50% of the ammonia produced by PLNL at current market prices. Our ammonia purchases from PLNL totaled ~~$59~~$20 million and ~~$74~~$115 million for the three and nine months ended ~~March 31,~~September 30, 2023, respectively, and $61 million and $212 million for the three and nine months ended September 30, 2022, respectively.

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7.8. Fair Value Measurements

Our cash and cash equivalents and other investments consist of the following:


		March 31, 2023									September 30, 2023
		Cost Basis		Unrealized Gains		Unrealized Losses		Fair Value			Cost Basis		Unrealized Gains		Unrealized Losses		Fair Value
		(in millions)									(in millions)
Cash	Cash	$	217	$	—	$	—	$	217	Cash	$	193	$	—	$	—	$	193
Cash equivalents:	Cash equivalents:									Cash equivalents:
U.S. and Canadian government obligations	U.S. and Canadian government obligations	2,314		—		—		2,314		U.S. and Canadian government obligations	2,687		—		—		2,687
Other debt securities	Other debt securities	294		—		—		294		Other debt securities	374		—		—		374
Total cash and cash equivalents	Total cash and cash equivalents	$	2,825	$	—	$	—	$	2,825	Total cash and cash equivalents	$	3,254	$	—	$	—	$	3,254

Nonqualified employee benefit trusts	Nonqualified employee benefit trusts	16		1		—		17		Nonqualified employee benefit trusts	16		—		—		16


	December 31, 2022
	Cost Basis		Unrealized Gains		Unrealized Losses		Fair Value
	(in millions)
Cash	$	153	$	—	$	—	$	153
Cash equivalents:
U.S. and Canadian government obligations	1,902		—		—		1,902
Other debt securities	268		—		—		268
Total cash and cash equivalents	$	2,323	$	—	$	—	$	2,323

Nonqualified employee benefit trusts	16		—		—		16

Under our short-term investment policy, we may invest our cash balances, either directly or through mutual funds, in several types of investment-grade securities, including notes and bonds issued by governmental entities or corporations. Securities issued by governmental entities include those issued directly by the U.S. and Canadian federal governments; those issued by state, local or other governmental entities; and those guaranteed by entities affiliated with governmental entities.

Assets and Liabilities Measured at Fair Value on a Recurring Basis

The following tables present assets and liabilities included in our consolidated balance sheets as of ~~March 31,~~September 30, 2023 and December 31, 2022 that are recognized at fair value on a recurring basis, and indicate the fair value hierarchy utilized to determine such fair value:


		March 31, 2023									September 30, 2023
		Total Fair Value		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)			Total Fair Value		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
		(in millions)									(in millions)
Cash equivalents	Cash equivalents	$	2,608	$	2,608	$	—	$	—	Cash equivalents	$	3,061	$	3,061	$	—	$	—

Nonqualified employee benefit trusts	Nonqualified employee benefit trusts	17		17		—		—		Nonqualified employee benefit trusts	16		16		—		—
Derivative assets	Derivative assets	4		—		4		—		Derivative assets	8		—		8		—
Derivative liabilities	Derivative liabilities	(5)		—		(5)		—		Derivative liabilities	(16)		—		(16)		—

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	December 31, 2022
	Total Fair Value		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
	(in millions)
Cash equivalents	$	2,170	$	2,170	$	—	$	—

Nonqualified employee benefit trusts	16		16		—		—
Derivative assets	12		—		12		—
Derivative liabilities	(85)		—		(85)		—

Cash Equivalents

Cash equivalents include highly liquid investments that are readily convertible to known amounts of cash with original maturities of three months or less. As of ~~March 31,~~September 30, 2023 and December 31, 2022, our cash equivalents consisted primarily of U.S. and Canadian government obligations and money market mutual funds that invest in U.S. government obligations and other investment-grade securities.

Nonqualified Employee Benefit Trusts

We maintain trusts associated with certain nonqualified supplemental pension plans. The fair values of the trust assets are based on daily quoted prices in an active market, which represent the net asset values of the shares held in the trusts, and are included on our consolidated balance sheets in other assets. Debt securities are accounted for as available-for-sale securities, and changes in fair value are reported in other comprehensive income. Changes in the fair value of available-for-sale equity securities in the trust assets are recognized through earnings.

Derivative Instruments

The derivative instruments that we use are primarily natural gas fixed price swaps, basis swaps and options traded in the over-the-counter markets with multi-national commercial banks, other major financial institutions or large energy companies. The natural gas derivative contracts represent anticipated natural gas needs for future periods, and settlements are scheduled to coincide with anticipated natural gas purchases during those future periods. The natural gas derivative contracts settle using primarily a NYMEX futures price index. To determine the fair value of these instruments, we use quoted market prices from NYMEX and standard pricing models with inputs derived from or corroborated by observable market data such as forward curves supplied by an industry-recognized independent third party. See Note ~~11—~~13—Derivative Financial Instruments for additional information.

Financial Instruments

The carrying amount and estimated fair value of our financial instruments are as follows:

March 31, 2023 December 31, 2022
Carrying
Amount Fair Value Carrying
Amount Fair Value
(in millions)
Long-term debt $ 2,966 $ 2,770 $ 2,965 $ 2,764


	September 30, 2023				December 31, 2022
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
	(in millions)
Long-term debt	$	2,967	$	2,656	$	2,965	$	2,764

The fair value of our long-term debt was based on quoted prices for identical or similar liabilities in markets that are not active or valuation models in which all significant inputs and value drivers are observable and, as a result, they are classified as Level 2 inputs.

The carrying amounts of cash and cash equivalents, as well as any instruments included in other current assets and other current liabilities that meet the definition of financial instruments, approximate fair values because of their short-term maturities.

Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis

We also have assets and liabilities that may be measured at fair value on a nonrecurring basis; that is, the assets and liabilities are not measured at fair value on an ongoing basis, but are subject to fair value adjustments in certain circumstances, such as when there is evidence of impairment, when there is allocation of purchase price in an acquisition or when a new liability is being established that requires fair value measurement. These include long-lived assets, goodwill and other

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intangible assets and investments in unconsolidated subsidiaries, such as equity method investments, which may be written down to fair value as a result of impairment. The fair value measurements related to each of these rely primarily on Company-specific inputs and the Company’s assumptions about the use of the assets. Since certain of the Company’s assumptions would involve inputs that are not observable, these fair values would reside within Level 3 of the fair value hierarchy.

In the third quarter of 2023, we determined the carrying value of our equity method investment in PLNL exceeded its fair value and recorded an impairment of our equity method investment in PLNL of $43 million. See Note 7—Equity Method Investment for additional information.

8.9. Income Taxes

For the three months ended ~~March 31,~~September 30, 2023, we recorded an income tax provision of ~~$169~~$23 million on pre-tax income of ~~$819~~$253 million, or an effective tax rate of ~~20.6%~~9.1%, compared to an income tax provision of ~~$401~~$155 million on pre-tax income of ~~$1.45~~$693 million, or an effective tax rate of 22.3%, for the three months ended September 30, 2022. For the three months ended September 30, 2023, our income tax provision includes a $9 million income tax benefit arising from the finalization of tax return filing positions and adjustments to accrued withholding taxes as a result of changes reflected on our filed U.S. federal return. This income tax benefit in relation to pre-tax income of $253 million contributed to a lower effective tax rate in the third quarter of 2023 compared to the U.S. statutory rate of 21%.

For the nine months ended September 30, 2023, we recorded an income tax provision of $326 million on pre-tax income of $1.81 billion, or an effective tax rate of ~~27.6%~~18.0%, compared to an income tax provision of $913 million on pre-tax income of $3.84 billion, or an effective tax rate of 23.8%, for the ~~three~~nine months ended ~~March 31,~~September 30, 2022.

For the three and nine months ended September 30, 2022, our income tax provision includes $18 million of income tax expense to record a valuation allowance in the United Kingdom due to the uncertainty surrounding the realization of the deferred tax assets as a result of the impairment described in Note 5—United Kingdom Operations Restructuring. In addition, for the nine months ended September 30, 2022, our income tax provision includes $22 million of income tax benefit due to share-based compensation activity and $78 million of income tax provision related to the Canada Revenue Agency Competent Authority Matter, as discussed below.

Our effective tax rate is impacted by earnings attributable to the noncontrolling interest in CF Industries Nitrogen, LLC (CFN), as our consolidated income tax provision does not include a tax provision on the earnings attributable to the noncontrolling interest. Our effective tax rate for the three months ended ~~March 31,~~September 30, 2023 of ~~20.6%~~9.1%, which is based on pre-tax income of ~~$819~~$253 million, including ~~$90~~$66 million of earnings attributable to the noncontrolling interest, would be ~~2.6~~3.2 percentage points higher if based on pre-tax income exclusive of the ~~$90~~$66 million of earnings attributable to the noncontrolling interest. Our effective tax rate for the three months ended ~~March 31,~~September 30, 2022 of ~~27.6%~~22.3%, which is based on pre-tax income of ~~$1.45 billion,~~$693 million, including ~~$168~~$100 million of earnings attributable to the noncontrolling interest, would be 3.7 percentage points higher if based on pre-tax income exclusive of the ~~$168~~$100 million of earnings attributable to the noncontrolling interest.

~~In addition,~~Our effective tax rate for the ~~three~~nine months ended ~~March 31, 2022, our~~September 30, 2023 of 18.0%, which is based on pre-tax income ~~tax provision includes $20~~of $1.81 billion, including $235 million of earnings attributable to the noncontrolling interest, would be 2.7 percentage points higher if based on pre-tax income ~~tax benefit due to share-based compensation activity and $78~~exclusive of the $235 million of ~~income tax provision related~~earnings attributable to the ~~Canada Revenue Agency Competent Authority Matter and certain transfer pricing reserves recorded in~~noncontrolling interest. Our effective tax rate for the ~~period, as discussed below.~~nine months ended September 30, 2022 of 23.8%, which is based on pre-tax income of $3.84 billion, including $442 million of earnings attributable to the noncontrolling interest, would be 3.1 percentage points higher if based on pre-tax income exclusive of the $442 million of earnings attributable to the noncontrolling interest.

Canada Revenue Agency Competent Authority Matter

In 2016, the Canada Revenue Agency (CRA) and Alberta Tax and Revenue Administration (Alberta TRA) issued Notices of Reassessment for tax years 2006 through 2009 to one of our Canadian affiliates asserting a disallowance of certain patronage deductions. We filed Notices of Objection with respect to the Notices of Reassessment with the CRA and Alberta TRA and posted letters of credit in lieu of paying the additional tax liability assessed. The letters of credit served as security until the matter was resolved, as discussed below. In 2018, the matter, including the related transfer pricing topic regarding the allocation of profits between Canada and the United States, was accepted for consideration under the bilateral settlement provisions of the U.S.-Canada tax treaty (the Treaty) by the United States and Canadian competent authorities, and included tax years 2006 through 2011. In the second quarter of 2021, the Company submitted the transfer pricing aspect of the matter into the arbitration process under the terms of the Treaty.

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the arbitration decision, additional income for tax years 2006 through 2011 was subject to tax in Canada, resulting in our having additional Canadian tax liability for those tax years.

In the ~~three~~nine months ended ~~March 31,~~September 30, 2022, as a result of the impact of these events on our Canadian and U.S. federal and state income taxes, we recognized an income tax provision of ~~$76~~$78 million, reflecting the net impact of ~~$127~~$129 million of accrued income taxes payable to Canada for tax years 2006 through 2011, partially offset by net income tax receivables of approximately $51 million in the United States, and we accrued net interest of ~~$99~~$103 million, primarily reflecting the impact of estimated interest payable to Canada.

Of the $78 million of income tax provision and $103 million of net interest expense recognized in the nine months ended September 30, 2022, a reduction of $1 million of net interest expense was recognized in the three months ended September 30, 2022.

In the second half of 2022, this tax liability and the related interest were assessed and paid, resulting in total payments of $224 million, which also reflect the impact of changes in foreign currency exchange rates. As a result, the letters of credit we had posted in lieu of paying the additional tax liability assessed by the Notices of Reassessment were cancelled. Due primarily to the availability of additional foreign tax credits to offset in part the increased Canadian tax referenced above, the Company has filed amended tax returns in the United States to request a refund of taxes paid.

Transfer pricing positions

~~In the first quarter of 2022, as~~As a result of the outcome of the arbitration decision discussed above, we also evaluated our transfer pricing positions between Canada and the United States for open years 2012 and after. Based on this evaluation, ~~for the three months ended March 31, 2022,~~ we recorded the ~~following:~~

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following in the nine months ended September 30, 2022:

•liabilities for unrecognized tax benefits of approximately ~~$319~~$314 million, with a corresponding income tax provision, and accrued interest of approximately ~~$91~~$123 million related to the liabilities for unrecognized tax benefits, and

•noncurrent income tax receivables of approximately ~~$329~~$359 million, with a corresponding income tax benefit, and accrued interest income of approximately ~~$28~~$33 million related to the noncurrent income tax receivables.

In the ~~three~~nine months ended ~~March 31,~~September 30, 2022, the impact on our consolidated statement of operations of the amounts recorded as a result of this evaluation of transfer pricing positions, including ~~a $12~~$29 million of net deferred income tax provision for other transfer pricing tax effects, was ~~a $2~~$16 million of income tax ~~provision~~benefit and ~~$63~~$90 million of net interest expense before tax ($6998 million after tax).

Of the $16 million of income tax benefit and $90 million of net interest expense recognized in the nine months ended September 30, 2022, $3 million of income tax provision and $4 million of net interest expense ($5 million after tax) was recognized in the three months ended September 30, 2022.

9.10. Pension Retiree Annuity Purchase

On July 15, 2022, we entered into an agreement with an insurance company to purchase a non-participating group annuity contract and transfer approximately $375 million of our primary U.S. defined benefit pension plan’s projected benefit obligation. The transaction closed on July 22, 2022 and was funded with plan assets. Under the transaction, the insurance company assumed responsibility for pension benefits and annuity administration for approximately 4,000 retirees or their beneficiaries. As a result of this transaction, in the third quarter of 2022, we remeasured the plan's projected benefit obligation and plan assets and recognized a non-cash pre-tax pension settlement loss of $24 million, reflecting the unamortized net unrecognized postretirement benefit costs related to the settled obligations, with a corresponding offset to accumulated other comprehensive loss. In the fourth quarter of 2022, the final settlement of the non-participating group annuity contract resulted in a refund of $4 million, which decreased the settlement loss by $3 million to $21 million.

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11. Financing Agreements

Revolving Credit Agreement

~~We have~~On October 26, 2023, we entered into a new senior unsecured revolving credit agreement (the New Revolving Credit Agreement), which ~~provides~~replaced our prior senior unsecured revolving credit agreement (the Prior Revolving Credit Agreement). See Note 18—Subsequent Event for additional information.

The Prior Revolving Credit Agreement provided for a revolving credit facility of up to $750 million with a maturity of December 5, ~~2024. The Revolving Credit Agreement includes~~2024 and included a letter of credit sub-limit of $125 million. Borrowings under the Prior Revolving Credit Agreement ~~may~~could be used for working capital, capital expenditures, acquisitions, share repurchases and other general corporate purposes.

Borrowings under the Prior Revolving Credit Agreement ~~may~~could be denominated in U.S. dollars, Canadian dollars, euros and British ~~pounds, and bear~~pounds. Borrowings in U.S. dollars bore interest at a per annum rate equal to, at our option, an applicable ~~eurocurrency rate~~adjusted term Secured Overnight Financing Rate or base rate plus, in either case, a specified margin. We ~~are~~were required to pay an undrawn commitment fee on the undrawn portion of the commitments under the Prior Revolving Credit Agreement and customary letter of credit fees. The specified margin and the amount of the commitment fee ~~depend~~depended on CF Holdings’ credit rating at the time.

~~As of March 31, 2023, we had unused borrowing capacity under the~~The Prior Revolving Credit Agreement of $750 million and no outstanding letters of credit. There were no borrowings outstanding under the Revolving Credit Agreement as of March 31, 2023 or December 31, 2022, or during the three months ended March 31, 2023.

~~The Revolving Credit Agreement contains~~contained representations and warranties and affirmative and negative covenants, including financial covenants. As of ~~March 31,~~September 30, 2023, we were in compliance with all covenants under the Prior Revolving Credit Agreement.

~~Letters~~As of September 30, 2023, we had unused borrowing capacity under the Prior Revolving Credit

~~In addition to the~~ Agreement of $750 million and no outstanding letters of credit ~~that may be issued~~ under the Prior Revolving Credit Agreement. There were no borrowings outstanding under the Prior Revolving Credit Agreement as ~~described above, we have also entered into~~of September 30, 2023 or December 31, 2022, or during the nine months ended September 30, 2023.

Letters of Credit Under Bilateral Agreement

We are party to a bilateral agreement ~~with capacity to issue~~providing for the issuance of up to $350 million of letters of credit. As of ~~March 31,~~September 30, 2023, approximately ~~$201~~$200 million of letters of credit were outstanding under this agreement.

Senior Notes

Long-term debt presented on our consolidated balance sheets as of ~~March 31,~~September 30, 2023 and December 31, 2022 consisted of the following debt securities issued by CF Industries:


		Effective Interest Rate	March 31, 2023				December 31, 2022					Effective Interest Rate	September 30, 2023				December 31, 2022
			Principal		Carrying Amount(1)		Principal		Carrying Amount(1)				Principal		Carrying Amount(1)		Principal		Carrying Amount(1)
			(in millions)										(in millions)
Public Senior Notes:	Public Senior Notes:										Public Senior Notes:

5.150% due March 2034	5.150% due March 2034	5.293%	750		741		750		741		5.150% due March 2034	5.293%	750		741		750		741
4.950% due June 2043	4.950% due June 2043	5.040%	750		742		750		742		4.950% due June 2043	5.040%	750		742		750		742
5.375% due March 2044	5.375% due March 2044	5.478%	750		740		750		740		5.375% due March 2044	5.478%	750		741		750		740
Senior Secured Notes:	Senior Secured Notes:										Senior Secured Notes:

4.500% due December 2026(2)	4.500% due December 2026(2)	4.783%	750		743		750		742		4.500% due December 2026(2)	4.783%	750		743		750		742
Total long-term debt	Total long-term debt		$	3,000	$	2,966	$	3,000	$	2,965	Total long-term debt		$	3,000	$	2,967	$	3,000	$	2,965

(1)Carrying amount is net of unamortized debt discount and deferred debt issuance costs. Total unamortized debt discount was $7 million as of both ~~March 31,~~September 30, 2023 and December 31, 2022, and total deferred debt issuance costs were ~~$27~~$26 million and $28 million as of ~~March 31,~~September 30, 2023 and December 31, 2022, respectively.

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(2)Effective August 23, 2021, these notes are no longer secured, in accordance with the terms of the applicable indenture.

Under the indentures (including the applicable supplemental indentures) governing the senior notes due 2034, 2043 and 2044 identified in the table above (the Public Senior Notes), each series of Public Senior Notes is guaranteed by CF Holdings. Under the terms of the indenture governing the 4.500% senior secured notes due December 2026 (the 2026 Notes) identified in the table above, the 2026 Notes are guaranteed by CF Holdings.

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Interest on the Public Senior Notes and the 2026 Notes is payable semiannually, and the Public Senior Notes and the 2026 Notes are redeemable at our option, in whole at any time or in part from time to time, at specified make-whole redemption prices.

~~10.~~12. Interest Expense

Details of interest expense are as follows:


		Three months ended March 31,			Three months ended September 30,						Nine months ended September 30,
			2023			2022			2023		2022		2023		2022
			(in millions)						(in millions)
Interest on borrowings(1)	Interest on borrowings(1)		$	37		$	42	Interest on borrowings(1)	$	38	$	38	$	112	$	118
Fees on financing agreements(1)	Fees on financing agreements(1)		2			2		Fees on financing agreements(1)	2		2		6		6
Interest on tax liabilities(2)	Interest on tax liabilities(2)		2			198		Interest on tax liabilities(2)	1		6		1		246
Interest capitalized	Interest capitalized		(1)			(1)		Interest capitalized	(2)		—		(4)		(1)
Total interest expense	Total interest expense		$	40		$	241	Total interest expense	$	39	$	46	$	115	$	369

(1)See Note 9—11—Financing Agreements for additional information.

(2)See Note 8—9—Income Taxes for additional information.

~~11.~~13. Derivative Financial Instruments

We use derivative financial instruments to reduce our exposure to changes in prices for natural gas that will be purchased in the future. Natural gas is the largest and most volatile component of our manufacturing cost for nitrogen-based products. From time to time, we may also use derivative financial instruments to reduce our exposure to changes in foreign currency exchange rates. The derivatives that we use to reduce our exposure to changes in prices for natural gas are primarily natural gas fixed price swaps, basis swaps and options traded in the over-the-counter markets. These natural gas derivatives settle using primarily a NYMEX futures price index, which represents the basis for fair value at any given time. We enter into natural gas derivative contracts with respect to natural gas to be consumed by us in the future, and settlements of those derivative contracts are scheduled to coincide with our anticipated purchases of natural gas used to manufacture nitrogen products during those future periods. We use natural gas derivatives as an economic hedge of natural gas price risk, but without the application of hedge accounting. As a result, changes in fair value of these contracts are recognized in earnings. As of ~~March 31,~~September 30, 2023, we had natural gas derivative contracts covering certain periods through March 2024.

As of ~~March 31,~~September 30, 2023, our open natural gas derivative contracts consisted of natural gas fixed price swaps, basis swaps and options for ~~18.9~~65.3 million MMBtus of natural gas. As of December 31, 2022, we had open natural gas derivative contracts consisting of natural gas fixed price swaps, basis swaps and options for 66.3 million MMBtus of natural gas. For the ~~three~~nine months ended ~~March 31,~~September 30, 2023, we used derivatives to cover approximately ~~69%~~27% of our natural gas consumption.

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The effect of derivatives in our consolidated statements of operations is shown in the table below.


		Gain (loss) recognized in income		Gain (loss) recognized in income
			Three months ended March 31,						Three months ended September 30,			Nine months ended September 30,
		Location			2023		2022				Location	2023		2022		2023		2022
					(in millions)						(in millions)

Unrealized net gains on natural gas derivatives		Cost of sales			$	72	$	33
Unrealized net (losses) gains on natural gas derivatives										Unrealized net (losses) gains on natural gas derivatives	Cost of sales	$	(7)	$	(11)	$	65	$	39
Realized net (losses) gains on natural gas derivatives	Realized net (losses) gains on natural gas derivatives	Cost of sales			(118)		17			Realized net (losses) gains on natural gas derivatives	Cost of sales	(1)		12		(119)		20

Net derivative (losses) gains	Net derivative (losses) gains				$	(46)	$	50		Net derivative (losses) gains		$	(8)	$	1	$	(54)	$	59

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The fair values of derivatives on our consolidated balance sheets are shown below. As of ~~March 31,~~September 30, 2023 and December 31, 2022, none of our derivative instruments were designated as hedging instruments. See Note 7—8—Fair Value Measurements for additional information on derivative fair values.

Asset Derivatives Liability Derivatives
Balance Sheet Location March 31,
2023 December 31, 2022 Balance Sheet
Location March 31,
2023 December 31, 2022
(in millions) (in millions)
Natural gas derivatives Other current assets $ 4 $ 12 Other current liabilities $ (5) $ (85)

Asset Derivatives

Liability Derivatives

Balance Sheet Location

September 30,
2023

December 31, 2022

Balance Sheet
Location

September 30,
2023

December 31, 2022

(in millions)

Natural gas derivatives

Other current assets

Other current liabilities

(16)

(85)

Most of our International Swaps and Derivatives Association (ISDA) agreements contain credit-risk-related contingent features such as cross default provisions. In the event of certain defaults or termination events, our counterparties may request early termination and net settlement of certain derivative trades or, under certain ISDA agreements, may require us to collateralize derivatives in a net liability position. As of ~~March 31,~~September 30, 2023 and December 31, 2022, the aggregate fair value of the derivative instruments with credit-risk-related contingent features in net liability positions was $1$8 million and $73 million, respectively, which also approximates the fair value of the assets that may be needed to settle the obligations if the credit-risk-related contingent features were triggered at the reporting dates. The credit support documents executed in connection with certain of our ISDA agreements generally provide us and our counterparties the right to set off collateral against amounts owing under the ISDA agreements upon the occurrence of a default or a specified termination event. As of ~~March 31,~~September 30, 2023 and December 31, 2022, we had no cash collateral on deposit with counterparties for derivative contracts.

The following table presents amounts relevant to offsetting of our derivative assets and liabilities as of ~~March 31,~~September 30, 2023 and December 31, 2022:


		Amounts presented in consolidated balance sheets(1)		Gross amounts not offset in consolidated balance sheets							Amounts presented in consolidated balance sheets(1)		Gross amounts not offset in consolidated balance sheets
				Financial instruments		Cash collateral received (pledged)		Net amount					Financial instruments		Cash collateral received (pledged)		Net amount
		(in millions)									(in millions)
March 31, 2023
September 30, 2023										September 30, 2023
Total derivative assets	Total derivative assets	$	4	$	—	$	—	$	4	Total derivative assets	$	8	$	—	$	—	$	8
Total derivative liabilities	Total derivative liabilities	(5)		—		—		(5)		Total derivative liabilities	(16)		—		—		(16)
Net derivative liabilities	Net derivative liabilities	$	(1)	$	—	$	—	$	(1)	Net derivative liabilities	$	(8)	$	—	$	—	$	(8)
December 31, 2022	December 31, 2022									December 31, 2022
Total derivative assets	Total derivative assets	$	12	$	—	$	—	$	12	Total derivative assets	$	12	$	—	$	—	$	12
Total derivative liabilities	Total derivative liabilities	(85)		—		—		(85)		Total derivative liabilities	(85)		—		—		(85)
Net derivative liabilities	Net derivative liabilities	$	(73)	$	—	$	—	$	(73)	Net derivative liabilities	$	(73)	$	—	$	—	$	(73)

(1)We report the fair values of our derivative assets and liabilities on a gross basis on our consolidated balance sheets. As a result, the gross amounts recognized and net amounts presented are the same.

We do not believe the contractually allowed netting, close-out netting or setoff of amounts owed to, or due from, the counterparties to our ISDA agreements would have a material effect on our financial position.

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~~12.~~14. Noncontrolling Interest

We have a strategic venture with CHS Inc. (CHS) under which CHS owns an equity interest in CFN, a subsidiary of CF Holdings, which represents approximately 11% of the membership interests of CFN. We own the remaining membership interests. Under the terms of CFN’s limited liability company agreement, each member’s interest will reflect, over time, the impact of the profitability of CFN, any member contributions made to CFN and withdrawals and distributions received from CFN. For financial reporting purposes, the assets, liabilities and earnings of the strategic venture are consolidated into our financial statements. CHS’ interest in the strategic venture is recorded in noncontrolling interest in our consolidated financial statements.

A reconciliation of the beginning and ending balances of noncontrolling interest and distributions payable to noncontrolling interest in our consolidated balance sheets is provided below.


		2023		2022			2023		2022

		(in millions)					(in millions)
Noncontrolling interest:	Noncontrolling interest:					Noncontrolling interest:
Balance as of January 1	Balance as of January 1	$	2,802	$	2,830	Balance as of January 1	$	2,802	$	2,830

Earnings attributable to noncontrolling interest	Earnings attributable to noncontrolling interest	90		168		Earnings attributable to noncontrolling interest	235		442
Declaration of distributions payable	Declaration of distributions payable	(255)		(247)		Declaration of distributions payable	(459)		(619)

Balance as of March 31		$	2,637	$	2,751
Balance as of September 30						Balance as of September 30	$	2,578	$	2,653
Distributions payable to noncontrolling interest:	Distributions payable to noncontrolling interest:					Distributions payable to noncontrolling interest:
Balance as of January 1	Balance as of January 1	$	—	$	—	Balance as of January 1	$	—	$	—
Declaration of distributions payable	Declaration of distributions payable	255		247		Declaration of distributions payable	459		619
Distributions to noncontrolling interest	Distributions to noncontrolling interest	(255)		(247)		Distributions to noncontrolling interest	(459)		(619)

Balance as of March 31		$	—	$	—
Balance as of September 30						Balance as of September 30	$	—	$	—

CHS also receives deliveries pursuant to a supply agreement under which CHS has the right to purchase annually from CFN up to approximately 1.1 million tons of granular urea and 580,000 tons of UAN at market prices. As a result of its equity interest in CFN, CHS is entitled to semi-annual cash distributions from CFN. We are also entitled to semi-annual cash distributions from CFN. The amounts of distributions from CFN to us and CHS are based generally on the profitability of CFN and determined based on the volume of granular urea and UAN sold by CFN to us and CHS pursuant to supply agreements, less a formula driven amount based primarily on the cost of natural gas used to produce the granular urea and UAN, and adjusted for the allocation of items such as operational efficiencies and overhead amounts.

~~13.~~15. Stockholders’ Equity

Common Stock

InThe following table summarizes the ~~three months ended March 31, 2023, we repurchased approximately 1.1 million shares~~share repurchases under the ~~2021~~2022 Share Repurchase Program ~~for $75 million, of which $21 million was accrued~~ and ~~unpaid as of March 31, 2023. As of March 31, 2023, there was approximately $80 million of authorization remaining under~~ the 2021 Share Repurchase Program.

In the three months ended March 31, 2022, we repurchased approximately 1.3 million shares under the 2021 Share Repurchase Program for $100 million and we retired 27,962 shares of repurchased stock, including shares repurchased under the share repurchase program that expired on December 31, 2021.

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	2022 Share Repurchase Program			2021 Share Repurchase Program
	Shares	Amounts(1)		Shares	Amounts(1)
	(in millions)

Shares repurchased in 2022:
First quarter	—	$	—	1.3	$	100
Second quarter	—	—		5.3	490
Third quarter	—	—		6.1	532
Fourth quarter	—	—		2.2	223
Total shares repurchased in 2022	—	—		14.9	1,345
Shares repurchased as of December 31, 2022	—	$	—	14.9	$	1,345
Shares repurchased in 2023:
First quarter	—	$	—	1.1	$	75
Second quarter	0.8	50		1.2	80
Third quarter	1.9	150		—	—

Total shares repurchased in 2023	2.7	200		2.3	155
Shares repurchased as of September 30, 2023	2.7	$	200	17.2	$	1,500

______________________________________________________________________________

(1)As defined in the share repurchase programs, amounts reflect the price paid for the shares of common stock repurchased, excluding commissions paid to brokers and excise taxes.

In the first half of 2023, we completed the 2021 Share Repurchase Program with the repurchase of approximately 2.3 million shares for $155 million. In the nine months ended September 30, 2023, we repurchased approximately 2.7 million shares under the 2022 Share Repurchase Program for $200 million and retired approximately 3.3 million shares of repurchased stock. We held approximately 1.9 million shares of treasury stock as of September 30, 2023.

In the nine months ended September 30, 2022, we repurchased approximately 12.7 million shares under the 2021 Share Repurchase Program for $1.12 billion, of which $27 million was accrued and unpaid as of September 30, 2022. In the nine months ended September 30, 2022, we retired approximately 3.2 million shares of repurchased stock.

Accumulated Other Comprehensive Loss

Changes to accumulated other comprehensive loss and the impact on other comprehensive income (loss) are as follows:


		Foreign Currency Translation Adjustment		Unrealized Gain on Derivatives		Defined Benefit Plans		Accumulated Other Comprehensive Income (Loss)
		(in millions)
Balance as of December 31, 2021		$	(141)	$	4	$	(120)	$	(257)

Reclassification to earnings		—		—		1		1

Effect of exchange rate changes and deferred taxes		(13)		—		3		(10)
Balance as of March 31, 2022		$	(154)	$	4	$	(116)	$	(266)

Balance as of December 31, 2022		$	(179)	$	3	$	(54)	$	(230)

											Foreign Currency Translation Adjustment		Unrealized Gain on Derivatives		Defined Benefit Plans		Accumulated Other Comprehensive Income (Loss)
											(in millions)

Balance as of December 31, 2022										Balance as of December 31, 2022	$	(179)	$	3	$	(54)	$	(230)

Gain arising during the period										Gain arising during the period	—		—		5		5

Reclassification to earnings										Reclassification to earnings	—		—		(1)		(1)

Effect of exchange rate changes and deferred taxes	Effect of exchange rate changes and deferred taxes	7		—		(1)		6		Effect of exchange rate changes and deferred taxes	3		—		(2)		1
Balance as of March 31, 2023		$	(172)	$	3	$	(55)	$	(224)
Balance as of September 30, 2023										Balance as of September 30, 2023	$	(176)	$	3	$	(52)	$	(225)

Balance as of December 31, 2021										Balance as of December 31, 2021	$	(141)	$	4	$	(120)	$	(257)
Gain arising during the period										Gain arising during the period	—		—		3		3
Reclassification to earnings(1)										Reclassification to earnings(1)	—		—		26		26
Effect of exchange rate changes and deferred taxes										Effect of exchange rate changes and deferred taxes	(49)		—		7		(42)
Balance as of September 30, 2022										Balance as of September 30, 2022	$	(190)	$	4	$	(84)	$	(270)

(1)Reclassifications out of accumulated other comprehensive loss to the consolidated statements of operations during the three and nine months ended September 30, 2022 include anon-cash pre-tax pension settlement loss of $24 million. See Note 10—Pension Retiree Annuity Purchase for additional information.

~~14.~~

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16. Segment Disclosures

Our reportable segments consist of Ammonia, Granular Urea, UAN, AN and Other. These segments are differentiated by products. Our management uses gross margin to evaluate segment performance and allocate resources. Total other operating costs and expenses (consisting primarily of selling, general and administrative expenses and other operating—net) and non-operating expenses (consisting primarily of interest and income taxes) are centrally managed and are not included in the measurement of segment profitability reviewed by management. Segment data for sales, cost of sales and gross margin for the three and nine months ended ~~March 31,~~September 30, 2023 and 2022 are presented in the table below.


		Ammonia		Granular Urea(1)		UAN(1)		AN(1)		Other(1)		Consolidated			Ammonia		Granular Urea(1)		UAN(1)		AN(1)		Other(1)		Consolidated
		(in millions)													(in millions)

Three months ended March 31, 2023
Three months ended September 30, 2023														Three months ended September 30, 2023
Net sales	Net sales	$	424	$	611	$	667	$	159	$	151	$	2,012	Net sales	$	235	$	360	$	435	$	114	$	129	$	1,273
Cost of sales	Cost of sales	280		327		346		104		92		1,149		Cost of sales	214		226		302		79		75		896
Gross margin	Gross margin	$	144	$	284	$	321	$	55	$	59	863		Gross margin	$	21	$	134	$	133	$	35	$	54	377
Total other operating costs and expenses	Total other operating costs and expenses											54		Total other operating costs and expenses											97
Equity in earnings of operating affiliate												17
Equity in losses of operating affiliate(2)														Equity in losses of operating affiliate(2)											(36)
Operating earnings	Operating earnings											$	826	Operating earnings											$	244
Three months ended March 31, 2022
Three months ended September 30, 2022														Three months ended September 30, 2022
Net sales	Net sales	$	640	$	765	$	1,015	$	223	$	225	$	2,868	Net sales	$	531	$	689	$	736	$	180	$	185	$	2,321
Cost of sales	Cost of sales	280		270		345		171		104		1,170		Cost of sales	353		394		414		136		108		1,405
Gross margin	Gross margin	$	360	$	495	$	670	$	52	$	121	1,698		Gross margin	$	178	$	295	$	322	$	44	$	77	916
Total other operating costs and expense												66
Total other operating costs and expenses(3)														Total other operating costs and expenses(3)											186
Equity in earnings of operating affiliate														Equity in earnings of operating affiliate											20
Operating earnings														Operating earnings											$	750

Nine months ended September 30, 2023														Nine months ended September 30, 2023
Net sales														Net sales	$	1,184	$	1,431	$	1,650	$	377	$	418	$	5,060
Cost of sales														Cost of sales	797		775		937		264		243		3,016
Gross margin														Gross margin	$	387	$	656	$	713	$	113	$	175	2,044
Total other operating costs and expenses														Total other operating costs and expenses											228
Equity in losses of operating affiliate(2)														Equity in losses of operating affiliate(2)											(12)
Operating earnings														Operating earnings											$	1,804
Nine months ended September 30, 2022														Nine months ended September 30, 2022
Net sales														Net sales	$	2,286	$	2,287	$	2,727	$	656	$	622	$	8,578
Cost of sales														Cost of sales	1,075		1,024		1,102		458		314		3,973
Gross margin														Gross margin	$	1,211	$	1,263	$	1,625	$	198	$	308	4,605
Total other operating costs and expenses(3)														Total other operating costs and expenses(3)											493

Equity in earnings of operating affiliate	Equity in earnings of operating affiliate											26		Equity in earnings of operating affiliate											74
Operating earnings	Operating earnings											$	1,658	Operating earnings											$	4,186

_______________________________________________________________________________

(1)The cost of the products that are upgraded into other products is transferred at cost into the upgraded product results.

(2)Equity in losses of operating affiliate for the three and nine months ended September 30, 2023 include an impairment of our equity method investment in PLNL of $43 million. See Note 7—Equity Method Investment for additional information.

(3)Total other operating costs and expenses for the three and nine months ended September 30, 2022 include $95 million and $257 million, respectively, of asset impairment and restructuring charges related to our U.K. operations. See Note 5—United Kingdom Operations Restructuring for additional information.

1721

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~~15.~~17. Agreement To Purchase Ammonia Production Facility

On March 20, 2023, we entered into an asset purchase agreement with Dyno Nobel Louisiana Ammonia, LLC (DNLA), a U.S. subsidiary of Australian-based Incitec Pivot Limited (IPL), and IPL. Under the terms of the agreement, we will purchase DNLA’s ammonia production complex located in Waggaman, Louisiana for a purchase price of $1.675 billion, subject to adjustment. The facility has a nameplate capacity of 880,000 tons of ammonia annually. The parties will allocate $425 million of the purchase price to a long-term ammonia offtake agreement providing for us to supply up to 200,000 tons of ammonia per year to IPL’s Dyno Nobel, Inc. subsidiary. We expect to fund the balance of the purchase price, representing the $1.675 billion purchase price, as adjusted, less $425 million, with cash on hand.

The consummation of the transaction is subject to the satisfaction or waiver of customary conditions, including, among others, the expiration or early termination of the waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended. The agreement includes certain customary termination rights, including the right of either party to terminate the agreement if the closing has not occurred by March 20, 2025. We have agreed to pay a termination fee of $75 million if the agreement is terminated in certain circumstances and certain regulatory approvals are not obtained.

18. Subsequent Event

On October 26, 2023, we entered into the New Revolving Credit Agreement, which replaced the Prior Revolving Credit Agreement that was scheduled to mature on December 5, 2024. The New Revolving Credit Agreement provides for a revolving credit facility of up to $750 million with a maturity of October 26, 2028 and includes a letter of credit sub-limit of $125 million. See Note 11—Financing Agreements for additional information on the Prior Revolving Credit Agreement.

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS.

You should read the following discussion and analysis in conjunction with our annual consolidated financial statements and related notes and our discussion and analysis of financial condition and results of operations that were included in our Annual Report on Form 10-K for the fiscal year ended December 31, 2022, filed with the Securities and Exchange Commission (SEC) on February 23, 2023, as well as Item 1. Financial Statements in Part I of this Quarterly Report on Form 10-Q. All references to “CF Holdings,” “we,” “us,” “our” and “the Company” refer to CF Industries Holdings, Inc. and its subsidiaries, except where the context makes clear that the reference is to CF Industries Holdings, Inc. only and not its subsidiaries. All references to “CF Industries” refer to CF Industries, Inc., a 100% owned subsidiary of CF Industries Holdings, Inc. References to tons refer to short tons, and references to tonnes refer to metric tons. Notes referenced in this discussion and analysis refer to the notes to our unaudited interim consolidated financial statements in Item 1. Financial Statements in Part I of this Quarterly Report on Form 10-Q. The following is an outline of the discussion and analysis included herein:

•Overview of CF Holdings

•Agreement to Purchase Ammonia Production Facility

•Market Conditions

•Financial Executive Summary

•Items Affecting Comparability of Results

•Consolidated Results of Operations

•Operating Results by Business Segment

•Liquidity and Capital Resources

•Critical Accounting Estimates

•Forward-Looking Statements

Overview of CF Holdings

Our Company

Our principal assets as of ~~March 31,~~September 30, 2023 include:

•five U.S. nitrogen manufacturing facilities located in Donaldsonville, Louisiana (the largest nitrogen complex in the world); Sergeant Bluff, Iowa (our Port Neal complex); Yazoo City, Mississippi; Claremore, Oklahoma (our Verdigris complex); and Woodward, Oklahoma. These facilities are wholly owned directly or indirectly by CF Industries Nitrogen, LLC (CFN), of which we own approximately 89% and CHS Inc. (CHS) owns the remainder (see Note ~~12—~~14—Noncontrolling Interest for additional information on our strategic venture with CHS);

•two Canadian nitrogen manufacturing facilities located in Medicine Hat, Alberta (the largest nitrogen complex in Canada) and Courtright, Ontario;

•a United Kingdom nitrogen manufacturing facility located in Billingham;

•an extensive system of terminals and associated transportation equipment located primarily in the Midwestern United States; and

1923

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•a 50% interest in Point Lisas Nitrogen Limited (PLNL), an ammonia production joint venture located in the Republic of Trinidad and Tobago (Trinidad) that we account for under the equity method.

We previously operated a United Kingdom nitrogen manufacturing facility located in Ince. In June 2022, we approved and announced our proposed plan to restructure our U.K. operations, including the permanent closure of our Ince facility. In August 2022, the final restructuring plan was approved, and decommissioning activities were initiated.

Our Commitment to a Clean Energy Economy

We are taking significant steps to support a global hydrogen and clean fuel economy, through the production of green and blue ammonia. Since ammonia is one of the most efficient ways to transport and store hydrogen and is also a fuel in its own right, we believe that the Company, as the world’s largest producer of ammonia with an unparalleled manufacturing and distribution network and deep technical expertise, is uniquely positioned to fulfill anticipated demand for hydrogen and ammonia from green and blue sources. Our approach includes green ammonia production, which refers to ammonia produced through a carbon-free process, and blue ammonia production, which relates to ammonia produced by conventional processes but with the ammonia process CO2 byproduct removed through carbon capture and sequestration (CCS).

In April 2021, we signed an engineering and procurement contract with thyssenkrupp to supply a 20 MW alkaline water electrolysis plant to produce green hydrogen at our Donaldsonville complex. ~~Construction and installation, which is being managed by us, is expected to finish in late 2023, with an estimated total cost of approximately $100 million.~~ We will integrate the green hydrogen generated by the electrolysis plant into existing ammonia synthesis loops to enable the production of approximately 20,000 tons per year of green ammonia. Fabrication and delivery of most major equipment is complete, and installation of the new electrolyzer unit is in progress. We believe that the Donaldsonville green ammonia project will be the largest of its kind in North America at the time of its startup.

In July 2022, we and Mitsui & Co., Ltd. (Mitsui) signed a joint development agreement for the companies’ proposed plans to construct an export-oriented blue ammonia facility. We and Mitsui ~~continue~~are expecting to ~~progress a~~complete the front-end engineering and design (FEED) study for the project ~~and expect to make~~in the fourth quarter of 2023, with a final investment decision on the proposed facility ~~in the second half of 2023.~~to follow. Should the companies agree to move forward, the ammonia facility would be constructed at our new Blue Point complex. We own the land for the complex, which is located on the west bank of the Mississippi river in Ascension Parish, Louisiana. Construction and commissioning of a new world-scale ammonia plant typically takes approximately four years from the time construction begins.

In the first quarter of 2023, we signed a memorandum of understanding (MOU) with JERA Co., Inc. (JERA), Japan’s largest energy generator, regarding the long-term supply of up to 500,000 tonnes per year of clean ammonia beginning in 2027. The execution of the MOU was the result of a supplier comparison and evaluation process for the procurement of clean ammonia that JERA initiated in February 2022 for the world’s first commercial scale ammonia co-firing operations that JERA is developing. The MOU establishes a framework for JERA and us to assess how we would best supply JERA with clean ammonia, which will be required to be produced with at least 60% lower carbon emissions than conventionally produced ammonia, under a long-term offtake agreement. We and JERA expect to evaluate a range of potential supply options, including JERA making an equity investment with us to develop a clean ammonia facility in Louisiana and a supplementary long-term offtake agreement.

In the first quarter of 2023, we signed an MOU with LOTTE CHEMICAL Corporation (LOTTE), a global chemicals company in South Korea. The MOU will guide LOTTE and us in a joint exploration of the development of clean ammonia production in the United States, in addition to the quantification of expected clean ammonia demand in South Korea and long-term clean ammonia offtake volumes into South Korea.

In September 2023, we and POSCO Holdings Inc. (POSCO) signed a joint development agreement term sheet to evaluate an export-oriented blue ammonia facility to be located at our new Blue Point complex. Should the project move forward, POSCO expects to import low-carbon clean ammonia from the facility into South Korea to support decarbonization of POSCO’s own and third-party coal-based power generation facilities. We and POSCO are initiating a joint FEED study in the fourth quarter of 2023 for the blue ammonia plant utilizing an autothermal reforming (ATR) ammonia production technology and are expecting to complete the FEED study in the second half of 2024.

We are also pursuing opportunities to produce blue ammonia from our existing ammonia production network. We are currently executing a project with an estimated cost of $200 million to construct a CO2 dehydration and compression facility at our Donaldsonville complex to enable the transport and permanent sequestration of the ammonia process CO2 byproduct. Engineering activities for the construction of the dehydration and ~~procurement of~~compression unit continue to advance, all major equipment for the facility ~~are in progress,~~has been procured, and ~~modification~~fabrication of the ~~site’s existing equipment~~CO2 compressors is proceeding. In October 2022, we announced that we had entered into a definitive CO2 offtake agreement with ExxonMobil to ~~allow integration with existing operations has begun.~~transport and permanently sequester CO2 from Donaldsonville. Once the dehydration and compression unit is in service and sequestration is initiated, we expect that the Donaldsonville complex will have the capacity to dehydrate and compress up to 2 million tons per year of process CO2, enabling the production of blue ammonia. ~~In October 2022, we announced that we had entered into a definitive CO~~2 ~~offtake agreement with ExxonMobil to transport and permanently sequester CO~~2 ~~from Donaldsonville.~~ Start-up for the project is planned for 2025. Under current regulations, the project

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would be expected to qualify for tax credits under Section 45Q of the Internal Revenue Code, which provides a credit per tonne of CO2 sequestered.

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Agreement to Purchase Ammonia Production Facility

The agreement includes certain customary termination rights, including the right of either party to terminate the agreement if the closing has not occurred by March 20, 2025. We have agreed to pay a termination fee of $75 million if the agreement is terminated in certain circumstances and certain regulatory approvals are not obtained.

Market Conditions

Geopolitical Environment

Changes in the geopolitical environment can have significant effects on our financial results. Russia’s invasion of Ukraine in February 2022, and the resulting war between Russia and Ukraine, disrupted global markets for certain commodities, including natural gas, nitrogen fertilizers and certain commodity grains and oilseeds, leading to production curtailments, export reductions and logistical complications involving these commodities. Additionally, energy, financial and transportation sanctions were announced by U.S., Canadian, European and other governments against Russia in response to the war. During 2022 and ~~continuing into~~ 2023, market participants ~~adjusted~~have continued to adjust trade flows and manufacturers ~~adjusted~~have continued to adjust production levels in response to changing conditions resulting from these factors. As of the date of filing of this report, nitrogen fertilizers have largely been explicitly exempted from ~~Russian~~ sanctions against Russia by the United States and certain other ~~governments.~~governments, and as a result, there has been an increase in Russian fertilizer exports into the United States and other parts of the world.

As further described below, natural gas is the principal raw material used to produce our nitrogen products. Natural gas is a globally traded commodity that experiences price fluctuations based on supply and demand balances and has been impacted by geopolitical events relating to the war between Russia and Ukraine. European energy markets, which have historically sourced a substantial portion of their natural gas from Russia, were disrupted by Russia’s invasion of Ukraine and the subsequent reduction of Russian natural gas supply to Europe during 2022. This led to further increases in natural gas prices and natural gas price volatility, which in turn led to disruptions in manufacturing and distribution activities at other nitrogen manufacturers and suppliers in our industry, resulting in changes in nitrogen product trade flows and reductions in global fertilizer supply. In September 2022, in response to the high prices for natural gas in the United Kingdom, we ~~temporarily~~ idled ammonia production at our Billingham complex and since that time have been importing ammonia from one of our North American manufacturing facilities or from purchases in the open market for upgrade into AN and other nitrogen products at that location. In the third quarter of 2023, we approved our plan to permanently close the Billingham ammonia plant.

The geopolitical developments that began in 2022 relating to the war in Ukraine also led to some supply chain disruptions for Russian and other producers of fertilizer, contributing to reduced global nitrogen fertilizer supply. ~~Prior to its February 2022 invasion of Ukraine,~~In particular, disruptions in nitrogen exports from Russia, ~~in recent years had been a significant supplier of nitrogen fertilizer products to North America and Europe and~~ a leading exporter of nitrogen fertilizer products ~~globally. Since that invasion, the closure~~globally, and nitrogen production in Europe, as a result of ~~a pipeline historically transporting ammonia from Russia through Ukraine for export has been a large contributor~~higher and more volatile natural gas prices as Russian-sourced natural gas supply declined, contributed to reduced ~~global exportable ammonia supply.~~nitrogen supply globally. In addition, Russia and Ukraine have been large exporters of commodity grains such as wheat, corn and soybeans. The direct and indirect impacts of the war in Ukraine, and the related uncertainty, resulted in reduced commodity grain supply from Russia and Ukraine, causing increased prices for grains globally. The increase in commodity grain prices in turn supported strong demand for nitrogen fertilizer in 2022. All of these geopolitical developments further contributed to an already tight global supply and demand balance for nitrogen ~~fertilizers. These factors caused~~fertilizers, causing changes in global trade flows as both manufacturers and customers reacted to the changing market dynamics. As a result, global nitrogen fertilizer prices remained high and also experienced significant volatility in 2022.

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As Russian-sourced natural gas supply declined due to geopolitical factors, European purchasers of natural gas increased imports from the liquified natural gas (LNG) market to build storage levels leading up to the winter 2022/2023 peak demand season. As storage levels of natural gas increased due to the increased LNG imports, in conjunction with a warmer than expected winter in Europe, prices for natural gas fell during the first ~~stabilized~~half of 2023 and then ~~fell as~~stabilized during the ~~first~~third quarter of ~~2023 progressed.~~2023. As natural gas prices decreased, certain nitrogen producers restarted previously idled production, leading to an increase in global nitrogen production operating rates. The increased global nitrogen product supply availability resulting from the increase in operating rates, in

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addition to new global production coming on line and an increase in Russian imports of UAN into ~~North America,~~the United States, resulted in an increase in supply and lower average selling prices in the first ~~quarter~~nine months of 2023 compared to average selling prices realized in 2022.

Nitrogen Selling Prices

Our nitrogen products are globally traded commodities with selling prices that fluctuate in response to global market conditions, changes in supply and demand, and other cost factors including domestic and local conditions. Intense global competition—reflected in import volumes and prices—strongly influences delivered prices for nitrogen fertilizers. In general, the prevailing global prices for nitrogen products must be at a level to incent the high cost marginal producer to produce product at a breakeven or above price, or else they would cease production and leave a portion of global demand unsatisfied.

In the ~~first~~third quarter of 2023, the average selling price for our products was ~~$444~~$268 per ton, a decrease of ~~28%~~49% compared to ~~$620~~$527 per ton in the ~~first~~third quarter of 2022, reflecting lower average selling prices across all our segments, which drove a decrease in net sales of approximately ~~$804 million~~$1.22 billion for the ~~first~~third quarter of 2023 compared to the ~~first~~third quarter of 2022. In the nine months ended September 30, 2023, the average selling price for our products was $356 per ton, or 42% lower compared to $619 per ton in the nine months ended September 30, 2022. This resulted in a decrease in net sales of approximately $3.68 billion for the nine months ended September 30, 2023 compared to the nine months ended September 30, 2022. The decrease in average selling prices reflects the impact of an increase in global supply availability asdue to higher global inventories entering 2023 and lower global energy costs, which drove higher global operating rates. In addition, higher average selling prices in 2022 were driven in part by the geopolitical environment, ~~experienced in 2022,~~ as described above.

Natural Gas

Natural gas is the principal raw material used to produce our nitrogen products. Natural gas is both a chemical feedstock and a fuel used to produce nitrogen products. Natural gas is a significant cost component of our manufactured nitrogen products, representing approximately 40% and 50%, respectively, of our production costs in ~~both~~ the first ~~three~~nine months of 2023 and in the year ended December 31, 2022.

The following table presents the average daily market price of natural gas at the Henry Hub, the most heavily-traded natural gas pricing point in North ~~America, and the National Balancing Point (NBP), the major trading point for natural gas in the United Kingdom:~~America:

Three Months Ended March 31,
2023 2022 2023 v. 2022
Natural gas supplemental data (per MMBtu)
Average daily market price of natural gas Henry Hub (Louisiana) $ 2.68 $ 4.60 $ (1.92) (42) %
Average daily market price of natural gas National Balancing Point (United Kingdom) $ 16.20 $ 30.20 $ (14.00) (46) %


	Three Months Ended September 30,								Nine Months Ended September 30,
	2023		2022		2023 v. 2022				2023		2022		2023 v. 2022








Average daily market price of natural gas Henry Hub (Louisiana) (per MMBtu)	$	2.58	$	7.96	$	(5.38)	(68)	%	$	2.46	$	6.66	$	(4.20)	(63)	%

Most of our nitrogen manufacturing facilities are located in the United States and Canada. As a result, the price of natural gas in North America directly impacts a substantial portion of our operating expenses. Average North American natural gas prices were lower ~~on average~~ during the first ~~three~~nine months of 2023 than during the first ~~three~~nine months of 2022. Warmer-than-normal temperatures in the first quarter of 2023 drove lower heating demand for natural gas, while North American supply remained strong, as there were few weather-related production disruptions. In addition, although the higher cost for natural gas outside of North America incentivized liquefaction facilities in the United States to export domestic natural gas during the first ~~quarter~~nine months of 2023, the ~~ongoing~~ outage at the Freeport LNG facility ~~limited total gas exports, supporting domestic supply. As a result, North American gas withdrawals from storage during~~in the first quarter of 2023 as well as planned maintenance in 2023 at several other LNG facilities limited total gas exports, resulting in greater domestic supply availability. As North America entered the 2023 summer season, natural gas demand for power generation increased due in part to coal-fired power plant retirements and lower natural gas costs. As a result, despite entering the third quarter of 2023 with well above-average volumes of gas in storage, which were ~~lower~~25% higher than ~~normal,~~one year ago and 15% higher than the five-year average, injection rates in the United States during the third quarter lagged historical averages, leading to end-of-quarter storage levels that were ~~32%~~12% higher than one year ago and ~~20%~~5% higher than the five-year average. ~~For the first three weeks of April 2023, the average daily market price of natural gas at the Henry Hub was $2.11 per MMBtu.~~

Our Billingham U.K. nitrogen manufacturing facility ishas been subject to fluctuations associated with the price of natural gas in Europe. Russia’s invasion of Ukraine in February 2022 disrupted European energy markets and threatened security of supply, driving natural gas prices in Europe upward to unprecedented levels. During the first quarter of 2023, Europe benefited from warmer-than-normal temperatures along with increased LNG imports, which were used to fill local storage capacity, decreasing the risk of natural gas shortage. This resulted in lower natural gas prices in the United Kingdom during the first quarter of 2023, despite lower European natural gas imports from Russia. Throughout the first quarter of 2023, storage levels remained well above historical averages, putting the market in a strong position to refill stocks in preparation for the next winter season and contributing to lower prices. ForIn the three and nine months ended March 31, 2023, the daily closing price at the NBP reached a low of $11.00 per MMBtu on March 21, 2023 and a high of $21.51 per MMBtu on two consecutive days in January 2023. For the first three weeks of April 2023,September 30, 2022, the average daily market price of natural gas at the ~~NBP~~National Balancing Point (NBP), the major trading point for natural

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gas in the United Kingdom, was ~~$12.84~~$32.54 per ~~MMBtu.~~MMBtu and $26.26 per MMBtu, respectively. In September 2022, as a result of extremely high and volatile natural gas prices and the lack of a corresponding increase in global nitrogen product market prices, we idled ammonia production at our Billingham complex. Since that time, we have imported ammonia for upgrade into AN and other nitrogen products at that location. In the third quarter of 2023, we approved our plan to permanently close the Billingham ammonia plant. As a result, we will continue to import ammonia for upgrade.

In the ~~first~~third quarter of 2023, our cost of natural gas used for production, which includes the impact of realized natural gas derivatives, ~~increased 2%~~decreased 70% to ~~$6.62~~$2.54 per MMBtu from ~~$6.48~~$8.35 per MMBtu in the ~~first~~third quarter of 2022. This ~~increase~~decrease in natural gas costs resulted in ~~a decrease~~an increase in gross margin of ~~approximately $28~~$496 million compared to the third quarter of 2022. In the first nine months of 2023, our cost of natural gas used for production, which includes the impact of realized natural gas derivatives, decreased 46% to $3.90 per MMBtu from $7.28 per MMBtu in the first nine months of 2022. This decrease in natural gas costs resulted in an increase in gross margin of $828 million compared to the first ~~quarter~~nine months of 2022. ~~The higher cost of~~

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~~natural gas reflects the impact of losses realized on natural gas derivatives that settled during the first quarter of 2023.~~In 2022, in response to high North American natural gas prices and continued price volatility, we entered into certain natural gas derivatives in order to reduce our exposure to further natural gas price volatility in the winter of 2022/2023.

Financial Executive Summary

We reported net earnings attributable to common stockholders of ~~$560~~$164 million for the three months ended ~~March 31,~~September 30, 2023 compared to ~~$883~~$438 million for the three months ended ~~March 31,~~September 30, 2022, a decrease in net earnings of ~~$323~~$274 million. The decrease in net earnings for the three months ended ~~March 31,~~September 30, 2023 compared to the three months ended ~~March 31,~~September 30, 2022 reflects a decrease ~~of $835 million~~ in gross margin, partially offset by a lower income tax provision in the third quarter of 2023 as compared to ~~$863~~the third quarter of 2022 and impairment charges related to our U.K. operations in the third quarter of 2022 that did not recur in the third quarter of 2023.

Gross margin decreased by $539 million to $377 million for the three months ended ~~March 31, 2023.~~September 30, 2023 compared to the three months ended September 30, 2022. The decrease in gross margin was due primarily to a 49% decrease ~~of 28%~~ in average selling prices to ~~$444~~$268 per ton in the ~~first~~third quarter of 2023 from ~~$620~~$527 per ton in the ~~first~~third quarter of 2022, which decreased gross margin by ~~$804 million. Lower gross margin~~$1.22 billion. The impact of lower selling prices was partially offset by ~~a decrease in interest expense of $201~~lower natural gas costs, which increased gross margin by $496 million, ~~due primarily to interest expense on tax liabilities related to Canadian-U.S. transfer pricing matters in the first quarter of 2022 that did not recur in 2023~~ and a decrease in the income tax provision of ~~$232~~$132 million due primarily to lower pre-tax earnings in the ~~first~~third quarter of 2023. In addition, pre-tax impairment and restructuring charges related to our U.K. operations of $95 million were recognized in the third quarter of 2022 compared to $5 million in the third quarter of 2023.

Diluted net earnings per share attributable to common stockholders decreased ~~$1.36~~$1.33 per share, to ~~$2.85~~$0.85 per share, in the ~~first~~third quarter of 2023 compared to ~~$4.21~~$2.18 per share in the ~~first~~third quarter of 2022 due primarily to lower net earnings, partially offset by lower weighted-average common shares outstanding as a result of shares repurchased under our share repurchase ~~program.~~programs.

Items Affecting Comparability of Results

For the three months ended ~~March 31,~~September 30, 2023 and 2022, we reported net earnings attributable to common stockholders of ~~$560~~$164 million and ~~$883~~$438 million, respectively. For the nine months ended September 30, 2023 and 2022, we reported net earnings attributable to common stockholders of $1.25 billion and $2.49 billion, respectively. In addition to the impact of market conditions discussed above, certain items affected the comparability of our financial results for the three and nine months ended ~~March 31,~~September 30, 2023 and 2022. The following table and related discussion outline these items and their impact on the comparability of our financial results for these periods. The descriptions of items below that refer to amounts in the table refer to the pre-tax amounts unless otherwise noted.

Three Months Ended March 31,
2023 2022
Pre-Tax After-Tax Pre-Tax After-Tax
(in millions)
Unrealized net mark-to-market gain on natural gas derivatives(1)
$ (72) $ (55) $ (33) $ (25)
(Gain) loss on foreign currency transactions, including intercompany loans(2)
(1) (1) 6 5
U.K. operations restructuring 2 2 — —
Transaction costs related to acquisition agreement 13 10 — —
Canada Revenue Agency Competent Authority Matter and transfer pricing positions:
Interest expense — — 198 196
Interest income — — (36) (28)
Income tax provision(3)
— — — 72

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	Three Months Ended September 30,								Nine Months Ended September 30,
	2023				2022				2023				2022
	Pre-Tax		After-Tax		Pre-Tax		After-Tax		Pre-Tax		After-Tax		Pre-Tax		After-Tax
	(in millions)

Unrealized net mark-to-market loss (gain) on natural gas derivatives(1)	$	7	$	5	$	11	$	7	$	(65)	$	(50)	$	(39)	$	(31)










Loss on foreign currency transactions, including intercompany loans(2)	7		5		27		21		5		4		38		29


U.K. operations:

U.K. long-lived and intangible asset impairment	—		—		87		66		—		—		239		181
U.K. operations restructuring	5		4		8		6		7		5		18		13


Transaction costs related to acquisition agreement	11		9		—		—		27		21		—		—
Impairment of equity method investment in PLNL(3)	43		33		—		—		43		33		—		—
Pension settlement loss(4)	—		—		24		18		—		—		24		18

Canada Revenue Agency Competent Authority Matter and transfer pricing positions:
Interest expense	—		—		6		6		—		—		234		232
Interest income	—		—		(3)		(2)		—		—		(41)		(31)
Income tax provision(5)	—		—		—		2		—		—		—		54

Loss on debt extinguishment	—		—		—		—		—		—		8		6

(1)Included in cost of sales in our consolidated statements of operations.

(2)Included in other operating—net in our consolidated statements of operations.

(3)Included in equity in (losses) earnings of operating affiliate in our consolidated statements of operations.

(4)Included in other non-operating—net in our consolidated statements of operations.

(5)For the three months ended ~~March 31,~~September 30, 2022, the after-tax income tax provision amount of ~~$72~~$2 million reflects the $3 million of income tax provision referenced below under “Transfer pricing positions,” net of $1 million of income tax provision that is reflected in the after-tax interest income amount shown in this table. For the nine months ended September 30, 2022, the after-tax income tax provision amount of $54 million reflects an income tax provision of ~~$78~~$62 million, consisting of the ~~$76~~$78 million income tax provision referenced below under “Canada Revenue Agency Competent Authority Matter” and the $2$16 million of income tax ~~provision~~benefit referenced below under “Transfer pricing positions,” net of $6$8 million of income tax provision that is reflected in the after-tax interest expense and interest income amounts shown in this table.

Unrealized net mark-to-market ~~gain~~loss (gain) on natural gas derivatives

Natural gas is the largest and most volatile single component of the manufacturing cost for our nitrogen-based products. At certain times, we have managed the risk of changes in natural gas prices through the use of derivative financial instruments. The derivatives that we use for this purpose are primarily natural gas fixed price swaps, basis swaps and options. We use natural gas derivatives as an economic hedge of natural gas price risk, but without the application of hedge accounting. This can result in volatility in reported earnings due to the unrealized mark-to-market adjustments that occur from changes in the value of the derivatives, which are reflected in cost of sales in our consolidated statements of operations. In the three months ended ~~March 31,~~September 30, 2023 and 2022, we recognized unrealized net mark-to-market losses of $7 million and $11 million, respectively. In the nine months ended September 30, 2023 and 2022, we recognized unrealized net mark-to-market gains of ~~$72~~$65 million and ~~$33~~$39 million, respectively.

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~~(Gain) loss~~Loss on foreign currency transactions, including intercompany loans

In the three months ended ~~March 31,~~September 30, 2023 and 2022, we recognized ~~a (gain) loss~~losses on foreign currency transactions of ~~$(1)~~$7 million and $6$27 million, respectively. ~~Gains~~In the nine months ended September 30, 2023 and 2022, we recognized losses on foreign currency transactions ~~consist~~of $5 million and $38 million, respectively. Loss on foreign currency transactions consists of foreign currency exchange rate impacts on foreign currency denominated transactions, including the impact of changes in foreign currency exchange rates on intercompany loans that ~~were~~are not permanently invested.

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U.K. operations ~~restructuring~~

In the three and nine months ended ~~March 31,~~September 30, 2023, we ~~incurred restructuring costs~~recognized total charges of $2$5 million and $7 million, respectively, consisting primarily of the recognition of an asset retirement obligation and post-employment benefits related to ~~the permanent closure~~contractual and statutory obligations due to employees as a result of our approved plan to permanently close the Billingham ammonia plant.

In the three and nine months ended September 30, 2022, we recognized total charges of $95 million and $257 million, respectively, consisting primarily of asset impairment charges related to property, plant and equipment at our Billingham and Ince ~~facility.~~facilities and definite-lived intangible assets. See Note 5—United Kingdom Operations Restructuring for additional information.

Transaction costs related to acquisition agreement

On March 20, 2023, we entered into an asset purchase agreement with DNLA and IPL to acquire DNLA’s ammonia production complex located in Waggaman, Louisiana, as described above under “Agreement to Purchase Ammonia Production Facility.” In the three and nine months ended ~~March 31,~~September 30, 2023, we incurred ~~$13~~$11 million and $27 million, respectively, of transaction costs related to the acquisition agreement.

Impairment of equity method investment in PLNL

PLNL, our joint venture in Trinidad, operates an ammonia plant that relies on natural gas supplied, under a gas sales contract (the NGC Contract), by The National Gas Company of Trinidad and Tobago Limited (NGC). The NGC Contract had an expiration date of September 2023. In the third quarter of 2023, PLNL entered into a new gas sales contract with NGC (the New NGC Contract), which is effective October 2023 through December 2025.

Pension settlement loss

Canada Revenue Agency Competent Authority Matter

In 2016, the Canada Revenue Agency (CRA) and Alberta Tax and Revenue Administration (Alberta TRA) issued Notices of Reassessment for tax years 2006 through 2009 to one of our Canadian affiliates asserting a disallowance of certain patronage deductions. We filed Notices of Objection with respect to the Notices of Reassessment with the CRA and Alberta TRA and posted letters of credit in lieu of paying the additional tax liability assessed. The letters of credit served as security until the matter was resolved. In 2018, the matter, including the related transfer pricing topic regarding the allocation of profits between Canada and the United States, was accepted for consideration under the bilateral settlement provisions of the U.S.-Canada tax treaty (the Treaty) by the United States and Canadian competent authorities, and included tax years 2006 through 2011. In the second quarter of 2021, the Company submitted the transfer pricing aspect of the matter into the arbitration process under the terms of the Treaty.

In February 2022, we were informed that a decision was reached by the arbitration panel for tax years 2006 through 2011. In March 2022, we received further details of the results of the arbitration proceedings and the settlement provisions between the United States and Canadian competent authorities, and we accepted the decision of the arbitration panel. Under the terms of the arbitration decision, additional income for tax years 2006 through 2011 was subject to tax in Canada, resulting in our having additional Canadian tax liability for those tax years. See Note 8—9—Income Taxes for additional information.

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CF INDUSTRIES HOLDINGS, INC.

Transfer pricing positions

~~In the first quarter of 2022, as~~As a result of the outcome of the arbitration decision discussed above, we also evaluated our transfer pricing positions between Canada and the United States for open years 2012 and after. Based on this evaluation, for the nine months ended September 30, 2022, we recorded the following:

•liabilities for unrecognized tax benefits of ~~$319~~approximately $314 million, with a corresponding income tax provision, and accrued interest of ~~$91~~approximately $123 million related to the liabilities for unrecognized tax benefits, and

•noncurrent income tax receivables of ~~$329~~approximately $359 million, with a corresponding income tax benefit, and accrued interest income of ~~$28~~approximately $33 million related to the noncurrent income tax receivables.

In the ~~three~~nine months ended ~~March 31,~~September 30, 2022, the impact on our consolidated statement of operations of the amounts recorded as a result of this evaluation of transfer pricing positions, ~~on our consolidated statement~~including $29 million of ~~operations, including a $12 million~~net deferred income tax provision for other transfer pricing tax effects, was ~~a $2~~$16 million of income tax ~~provision~~benefit and ~~$63~~$90 million of net interest expense before tax ($6998 million after tax).

Loss on debt extinguishment

On April 21, 2022, we redeemed in full all of the $500 million outstanding principal amount of the 3.450% senior notes due June 2023 (the 2023 Notes) in accordance with the optional redemption provisions in the indenture governing the 2023 Notes. The total aggregate redemption price paid in connection with the April 2022 redemption of the 2023 Notes was $513 million, including accrued interest. As a result, we recognized a loss on debt extinguishment of $8 million, consisting primarily of the premium paid on the redemption of the $500 million principal amount of the 2023 Notes prior to their scheduled maturity.

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CF INDUSTRIES HOLDINGS, INC.

Consolidated Results of Operations

The following table presents our consolidated results of operations for the three and nine months ended September 30, 2023 and 2022:


	Three Months Ended September 30,											Nine Months Ended September 30,
	2023			2022			2023 v. 2022					2023			2022			2023 v. 2022
	(dollars in millions, except per share and per MMBtu amounts)
Net sales	$	1,273		$	2,321		$	(1,048)		(45)	%	$	5,060		$	8,578		$	(3,518)		(41)	%
Cost of sales	896			1,405			(509)			(36)	%	3,016			3,973			(957)			(24)	%
Gross margin	377			916			(539)			(59)	%	2,044			4,605			(2,561)			(56)	%
Gross margin percentage	29.6		%	39.5		%	(9.9)		%			40.4		%	53.7		%	(13.3)		%
Selling, general and administrative expenses	68			66			2			3	%	213			203			10			5	%
U.K. long-lived and intangible asset impairment	—			87			(87)			(100)	%	—			239			(239)			(100)	%

U.K. operations restructuring	5			8			(3)			(38)	%	7			18			(11)			(61)	%
Transaction costs	11			—			11			N/M		27			—			27			N/M

Other operating—net	13			25			(12)			(48)	%	(19)			33			(52)			N/M
Total other operating costs and expenses	97			186			(89)			(48)	%	228			493			(265)			(54)	%

Equity in (losses) earnings of operating affiliate	(36)			20			(56)			N/M		(12)			74			(86)			N/M
Operating earnings	244			750			(506)			(67)	%	1,804			4,186			(2,382)			(57)	%
Interest expense	39			46			(7)			(15)	%	115			369			(254)			(69)	%
Interest income	(45)			(12)			(33)			(275)	%	(115)			(56)			(59)			(105)	%
Loss on debt extinguishment	—			—			—			—	%	—			8			(8)			(100)	%
Other non-operating—net	(3)			23			(26)			N/M		(8)			24			(32)			N/M
Earnings before income taxes	253			693			(440)			(63)	%	1,812			3,841			(2,029)			(53)	%
Income tax provision	23			155			(132)			(85)	%	326			913			(587)			(64)	%

Net earnings	230			538			(308)			(57)	%	1,486			2,928			(1,442)			(49)	%
Less: Net earnings attributable to noncontrolling interest	66			100			(34)			(34)	%	235			442			(207)			(47)	%
Net earnings attributable to common stockholders	$	164		$	438		$	(274)		(63)	%	$	1,251		$	2,486		$	(1,235)		(50)	%
Diluted net earnings per share attributable to common stockholders	$	0.85		$	2.18		$	(1.33)		(61)	%	$	6.42		$	12.04		$	(5.62)		(47)	%
Diluted weighted-average common shares outstanding	192.9			200.9			(8.0)			(4)	%	194.9			206.5			(11.6)			(6)	%
Dividends declared per common share	$	0.40		$	0.40		$	—		—	%	$	1.20		$	1.10		$	0.10		9	%

___________________________________________________________________________

N/M—Not Meaningful

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The following table presents certain supplemental ~~data:~~data for the three and nine months ended September 30, 2023 and 2022:

Three Months Ended March 31,
2023 2022 2023 v. 2022
(in millions, except per share and per MMBtu)
Net sales $ 2,012 $ 2,868 $ (856) (30) %
Cost of sales 1,149 1,170 (21) (2) %
Gross margin 863 1,698 (835) (49) %
Gross margin percentage 42.9 % 59.2 % (16.3) %
Selling, general and administrative expenses 74 64 10 16 %
U.K. operations restructuring 2 — 2 N/M
Transaction costs 13 — 13 N/M
Other operating—net (35) 2 (37) N/M
Total other operating costs and expenses 54 66 (12) (18) %
Equity in earnings of operating affiliate 17 26 (9) (35) %
Operating earnings 826 1,658 (832) (50) %
Interest expense—net 10 205 (195) (95) %
Other non-operating—net (3) 1 (4) N/M
Earnings before income taxes 819 1,452 (633) (44) %
Income tax provision 169 401 (232) (58) %
Net earnings 650 1,051 (401) (38) %
Less: Net earnings attributable to noncontrolling interest 90 168 (78) (46) %
Net earnings attributable to common stockholders $ 560 $ 883 $ (323) (37) %
Diluted net earnings per share attributable to common stockholders $ 2.85 $ 4.21 $ (1.36) (32) %
Diluted weighted-average common shares outstanding 196.9 209.9 (13.0) (6) %
Dividends declared per common share $ 0.40 $ 0.30 $ 0.10 33 %
Natural gas supplemental data (per MMBtu)
Natural gas costs in cost of sales(1)
$ 5.14 $ 6.70 $ (1.56) (23) %
Realized derivatives loss (gain) in cost of sales(2)
1.48 (0.22) 1.70 N/M
Cost of natural gas used for production in cost of sales $ 6.62 $ 6.48 $ 0.14 2 %
Average daily market price of natural gas Henry Hub (Louisiana) $ 2.68 $ 4.60 $ (1.92) (42) %
Average daily market price of natural gas National Balancing Point (United Kingdom) $ 16.20 $ 30.20 $ (14.00) (46) %
Unrealized net mark-to-market gain on natural gas derivatives $ (72) $ (33) $ (39) (118) %
Depreciation and amortization $ 206 $ 208 $ (2) (1) %
Capital expenditures $ 69 $ 63 $ 6 10 %
Sales volume by product tons (000s) 4,535 4,624 (89) (2) %
Production volume by product tons (000s):
Ammonia(3)
2,359 2,613 (254) (10) %
Granular urea 1,211 1,074 137 13 %
UAN (32%) 1,598 1,865 (267) (14) %
AN 388 405 (17) (4) %


	Three Months Ended September 30,								Nine Months Ended September 30,
	2023		2022		2023 v. 2022				2023		2022		2023 v. 2022
	(dollars in millions, except per MMBtu amounts)




























Natural gas supplemental data (per MMBtu)
Natural gas costs in cost of sales(1)	$	2.53	$	8.50	$	(5.97)	(70)	%	$	3.43	$	7.36	$	(3.93)	(53)	%
Realized derivatives loss (gain) in cost of sales(2)	0.01		(0.15)		0.16		N/M		0.47		(0.08)		0.55		N/M
Cost of natural gas used for production in cost of sales	$	2.54	$	8.35	$	(5.81)	(70)	%	$	3.90	$	7.28	$	(3.38)	(46)	%



Average daily market price of natural gas Henry Hub (Louisiana)	$	2.58	$	7.96	$	(5.38)	(68)	%	$	2.46	$	6.66	$	(4.20)	(63)	%

Unrealized net mark-to-market loss (gain) on natural gas derivatives	$	7	$	11	$	(4)	(36)	%	$	(65)	$	(39)	$	(26)	(67)	%
Depreciation and amortization	$	213	$	221	$	(8)	(4)	%	$	640	$	652	$	(12)	(2)	%
Capital expenditures	$	147	$	190	$	(43)	(23)	%	$	311	$	319	$	(8)	(3)	%
Sales volume by product tons (000s)	4,745		4,408		337		8	%	14,218		13,867		351		3	%
Production volume by product tons (000s):
Ammonia(3)	2,238		2,283		(45)		(2)	%	6,971		7,366		(395)		(5)	%
Granular urea	1,081		1,187		(106)		(9)	%	3,414		3,418		(4)		—	%
UAN (32%)	1,749		1,381		368		27	%	5,012		4,879		133		3	%
AN	416		358		58		16	%	1,104		1,162		(58)		(5)	%

N/M—Not Meaningful

(1)Includes the cost of natural gas used for production and related transportation that is included in cost of sales during the period under the first-in, first-out inventory cost method.

(2)Includes realized gains and losses on natural gas derivatives settled during the period. Excludes unrealized mark-to-market gains and losses on natural gas derivatives.

(3)Gross ammonia production, including amounts subsequently upgraded on-site into granular urea, UAN, or AN.

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~~First~~Third Quarter of 2023 Compared to ~~First~~Third Quarter of 2022

Net Sales

Our total net sales decreased ~~$856 million,~~$1.05 billion, or ~~30%~~45%, to ~~$2.01~~$1.27 billion in the ~~first~~third quarter of 2023 compared to ~~$2.87~~$2.32 billion in the ~~first~~third quarter of 2022 due primarily to ~~decreases~~a decrease in average selling prices, ~~and~~partially offset by an increase in sales volume.

Our average selling price was ~~$444~~$268 per ton in the ~~first~~third quarter of 2023, or ~~28%~~49% lower compared to ~~$620~~$527 per ton in the ~~first~~third quarter of 2022, due to lower average selling prices across all of our ~~segments, primarily driven by~~segments. The impact of lower average selling prices was a decrease in net sales of approximately $1.22 billion for the third quarter of 2023 compared to the third quarter of 2022. The decrease in average selling prices reflects the impact of an increase in global supply availability as lower global energy costs drove higher global operating rates.

Our total sales volume of ~~4.5~~4.7 million product tons in the ~~first~~third quarter of 2023 was ~~2% lower~~8% higher compared to ~~4.6~~4.4 million product tons in the ~~first~~third quarter of 2022 ~~as lower~~due primarily to higher sales volume in our UAN, Ammonia, AN and Other segments, ~~was~~ partially offset by ~~higher~~lower sales volume in our Granular Urea segment.

Gross ammonia production for the three and nine months ended September 30, 2023 was 2.2 million tons and 7.0 million tons, respectively. We expect gross ammonia production for 2023 will be in a range of 9.0 million to 9.5 million tons as we have an approved plan to permanently close the ammonia plant at our Billingham, U.K. complex.

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CF INDUSTRIES HOLDINGS, INC.

Cost of Sales

Our total cost of sales decreased ~~$21~~$509 million, or 2%36%, to ~~$1.15 billion~~$896 million in the ~~first~~third quarter of 2023 from ~~$1.17~~$1.41 billion in the ~~first~~third quarter of 2022. The decrease in our cost of sales was due primarily to ~~a decrease in sales volume~~lower costs for natural gas, including the impact of ~~2%,~~realized derivatives, which decreased cost of sales by ~~$30~~$496 million, and lower costs for ammonia purchased from PLNL, our joint venture in Trinidad. ~~The factors that decreased cost of sales were partially offset by higher costs for~~Lower natural gas ~~including~~costs include the ~~impact~~benefit of realized derivatives, which increased cost of sales by $28 million, and higher costs for imported ammonia for our operations in the United Kingdom. Higher costs for natural gas were due primarily to losses on natural gas derivatives settled in the first quarter of 2023, partially offset by lower costs forno longer purchasing natural gas in the United Kingdom ~~as we imported~~for ammonia production. The decrease in our cost of sales from lower natural gas costs was partially offset by the cost to import ammonia in the third quarter of 2023 for ~~upgrading to AN.~~our U.K. operations.

Cost of sales ~~also includes the impact of a $72 million unrealized net mark-to-market gain on natural gas derivatives~~averaged $189 per ton in the ~~first~~third quarter of 2023 compared to ~~a $33 million gain in the first quarter of 2022.~~

~~Cost of sales averaged $254~~$319 per ton in the ~~first quarter of 2023 compared to $253 per ton in the first~~third quarter of 2022. ~~The~~Our cost of natural gas ~~used for production includes the impact of natural gas derivatives used~~decreased 70% to ~~reduce the volatility of natural gas prices. The cost of natural gas increased 2% to $6.62~~$2.54 per MMBtu in the ~~first~~third quarter of 2023 from ~~$6.48~~$8.35 per MMBtu in the ~~first~~third quarter of 2022. ~~The higher cost of natural gas reflects the impact of losses realized on natural gas derivatives that settled during the first quarter of 2023.~~In 2022, in response to high North American natural gas prices and continued price volatility, we entered into certain natural gas derivatives in order to reduce our exposure to further natural gas price volatility in the winter of 2022/2023.

Selling, General and Administrative Expenses

Selling, general and administrative expenses ~~increased $10 million to $74~~were $68 million in the ~~first~~third quarter of 2023, ~~as compared to $64~~a 3% increase from $66 million in the ~~first~~third quarter of 2022. ~~The increase was due~~

U.K. Operations

In the three months ended September 30, 2023, we recognized total charges of $5 million, consisting primarily ~~to higher costs~~of the recognition of an asset retirement obligation and post-employment benefits related to ~~certain corporate initiatives, including amortization~~contractual and statutory obligations due to employees as a result of our ~~recently implemented enterprise resource planning (ERP) system,~~approved plan to permanently close the Billingham ammonia plant.

In the three months ended September 30, 2022, we recognized total charges of $95 million consisting of $87 million of asset impairment charges primarily related to property, plant and ~~higher salaries~~equipment at our Billingham, U.K. facility and ~~incentive compensation.~~definite-lived intangible assets and $8 million of restructuring charges primarily related to one-time termination benefits. See Note 5—United Kingdom Operations Restructuring for additional information.

Transaction Costs

On March 20, 2023, we entered into an asset purchase agreement with DNLA and IPL to acquire DNLA’s ammonia production complex located in Waggaman, Louisiana, as described above under “Agreement to Purchase Ammonia Production Facility.” In the three months ended ~~March 31,~~September 30, 2023, we incurred ~~$13~~$11 million of transaction costs related to the acquisition agreement.

Other Operating—Net

Other operating—net was ~~$35~~$13 million of ~~income~~expense in the ~~first~~third quarter of 2023 compared to $2$25 million of expense in the ~~first~~third quarter of 2022. The ~~$35~~decrease of $12 million in other operating—net was due primarily to a loss on foreign currency transactions of ~~income~~$7 million in the ~~first~~third quarter of 2023 compared to $27 million in the third quarter of 2022. Loss on foreign currency transactions consists ~~primarily~~ of ~~a gain~~foreign currency exchange rate impacts on ~~sales~~foreign currency denominated transactions, including the impact of ~~emission credits.~~changes in foreign currency exchange rates on intercompany loans that are not permanently invested.

Equity in (Losses) Earnings of Operating Affiliate

Equity in (losses) earnings of operating affiliate was ~~$17~~$36 million of losses in the ~~first~~third quarter of 2023 compared to ~~$26~~$20 million of earnings in the ~~first~~third quarter of 2022. The ~~decrease was due primarily to~~$36 million of losses in the third quarter of 2023 includes an impairment of our equity method investment in PLNL of $43 million. See “Items Affecting Comparability of Results—Impairment of equity method investment in PLNL,” above, for further discussion. Lower equity in earnings of operating affiliate also reflects a decrease in the operating results of PLNL as a result of lower ammonia selling prices, partially offset by lower natural gas costs.

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Interest Expense

Interest ~~Expense—Net~~

~~Net interest~~ expense was ~~$10~~$39 million in the ~~first~~third quarter of 2023 compared to ~~$205~~$46 million in the ~~first~~third quarter of 2022. The decrease of ~~$195~~$7 million was due primarily to ~~$162~~$6 million of ~~net~~tax-related interest expense recorded in the ~~first~~third quarter of 2022 that did not recur in the third quarter of 2023 and was related to income tax matters ~~which are~~ described under “Items Affecting Comparability of Results—Canada Revenue Agency Competent Authority Matter” and “Items Affecting Comparability of Results—Transfer pricing positions,” above. ~~In addition,~~

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CF INDUSTRIES HOLDINGS, INC.

Interest Income

Interest income was $45 million in the ~~decrease~~third quarter of 2023 compared to $12 million in ~~net interest expense was due to~~the third quarter of 2022. The increase of $33 million reflects higher interest income on short-term investments due primarily to higher interest rates. Short-term investments are included in cash and ~~lower interest~~cash equivalents in our consolidated balance sheet.

Other Non-Operating—Net

Other non-operating—net was $3 million of income in the third quarter of 2023 compared to $23 million of expense ~~on borrowings~~in the third quarter of 2022. The $23 million of expense in the third quarter of 2022 was due primarily to a pension settlement loss of $24 million related to the ~~redemption~~purchase of ~~$500 million principal amount~~a non-participating group annuity contract to settle retiree obligations under our primary U.S. defined benefit pension plan, which is more fully described under “Items Affecting Comparability of ~~3.450% senior notes due June 2023 in April 2022 prior to their scheduled maturity.~~Results—Pension settlement loss,” above.

Income Taxes

For the three months ended ~~March 31,~~September 30, 2023, we recorded an income tax provision of ~~$169~~$23 million on pre-tax income of ~~$819~~$253 million, or an effective tax rate of ~~20.6%~~9.1%, compared to an income tax provision of ~~$401~~$155 million on a pre-tax income of ~~$1.45 billion,~~$693 million, or an effective tax rate of ~~27.6%~~22.3%, for the three months ended ~~March 31,~~September 30, 2022. For the three months ended September 30, 2023, our income tax provision includes a $9 million income tax benefit arising from the finalization of tax return filing positions and adjustments to accrued withholding taxes as a result of changes reflected on our filed U.S. federal return. This income tax benefit in relation to pre-tax income of $253 million contributed to a lower effective tax rate in the third quarter of 2023 compared to the U.S. statutory rate of 21%.

For the three months ended September 30, 2022, our income tax provision includes $18 million of income tax expense to record a valuation allowance in the United Kingdom due to the uncertainty surrounding the realization of the deferred tax assets as a result of the impairment described in Note 5—United Kingdom Operations Restructuring.

Our effective tax rate is impacted by earnings attributable to the noncontrolling interest in CFN, as our consolidated income tax provision does not include a tax provision on the earnings attributable to the noncontrolling interest. Our effective tax rate for the three months ended ~~March 31,~~September 30, 2023 of ~~20.6%~~9.1%, which is based on pre-tax income of ~~$819~~$253 million, including ~~$90~~$66 million of earnings attributable to the noncontrolling interest, would be ~~2.6~~3.2 percentage points higher, or ~~23.2%~~12.3%, if based on pre-tax income exclusive of the ~~$90 million of~~ earnings attributable to the noncontrolling ~~interest.~~interest of $66 million. Our effective tax rate for the three months ended ~~March 31,~~September 30, 2022 of ~~27.6%~~22.3%, which is based on pre-tax income of ~~$1.45 billion,~~$693 million, including ~~$168~~$100 million of earnings attributable to the noncontrolling interest, would be 3.7 percentage points higher, or ~~31.3%~~26.0%, if based on pre-tax income exclusive of the ~~$168~~$100 million of earnings attributable to the noncontrolling interest. See Note ~~12—~~14—Noncontrolling Interest for additional information.

In addition, for the three months ended March 31, 2022, our income tax provision includes $20 million of income tax benefit due to share-based compensation activity and $78 million of income tax provision related to the Canada Revenue Agency Competent Authority Matter and certain transfer pricing reserves recorded in the period, which are described above under “Items Affecting Comparability of Results.”

Net Earnings Attributable to Noncontrolling Interest

Net earnings attributable to noncontrolling interest decreased ~~$78~~$34 million to ~~$90~~$66 million in the ~~first~~third quarter of 2023 compared to ~~$168~~$100 million in the ~~first~~third quarter of 2022 due to lower earnings of CFN driven by lower average selling prices as described above under “Net Sales.”

Diluted Net Earnings Per Share Attributable to Common Stockholders

~~Net~~Diluted net earnings per share attributable to common stockholders decreased ~~$1.36~~$1.33 to ~~$2.85~~$0.85 per ~~diluted~~ share in the ~~first~~third quarter of 2023 from ~~$4.21~~$2.18 per ~~diluted~~ share in the ~~first~~third quarter of 2022. This decrease was due primarily to a decrease in gross margin, driven by lower average selling ~~prices.~~prices, partially offset by lower natural gas costs. Lower gross margin was partially offset by a decrease in the income tax provision resulting from lower profitability and pre-tax impairment and restructuring charges related to our U.K. operations of $95 million in the third quarter of 2022 compared to $5 million in the third quarter of 2023. Additionally, diluted weighted-average common shares outstanding declined 4% from 200.9 million shares for the three months ended September 30, 2022 to 192.9 million shares for the three months ended September 30, 2023, due primarily to repurchases of common shares under our share repurchase programs.

Nine Months Ended September 30, 2023 Compared to Nine Months Ended September 30, 2022

Net Sales

Our total net sales decreased $3.52 billion, or 41%, to $5.06 billion in the first nine months of 2023 compared to $8.58 billion in the first nine months of 2022 due primarily to a 42% decrease in average selling prices.

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Our average selling price was $356 per ton in the first nine months of 2023 compared to $619 per ton in the first nine months of 2022, due to lower average selling prices across all of our segments, primarily driven by an increase in global supply availability due to higher global inventories entering 2023 and lower global energy costs, which drove higher global operating rates. The impact of lower average selling prices was a decrease in net sales of approximately $3.68 billion for the nine months ended September 30, 2023 compared to the nine months ended September 30, 2022.

Cost of Sales

Our total cost of sales decreased $957 million, or 24%, to $3.02 billion in the first nine months of 2023 from $3.97 billion in the first nine months of 2022. The decrease in our cost of sales was due primarily to lower costs for natural gas, including the impact of realized derivatives, which decreased cost of sales by $828 million, and lower costs for ammonia purchased from PLNL, our joint venture in Trinidad. Lower natural gas costs include the benefit of no longer purchasing natural gas in the United Kingdom for ammonia production. The decrease in our cost of sales from lower natural gas costs was partially offset by the cost to import ammonia in the first nine months of 2023 for our U.K. operations.

Cost of sales also includes the impact of a $65 million unrealized net mark-to-market gain on natural gas derivatives in the first nine months of 2023 compared to a $39 million gain in the first nine months of 2022.

Cost of sales averaged $212 per ton in the first nine months of 2023 compared to $287 per ton in the first nine months of 2022. Our cost of natural gas decreased 46% to $3.90 per MMBtu in the first nine months of 2023 from $7.28 per MMBtu in the first nine months of 2022.

Selling, General and Administrative Expenses

Selling, general and administrative expenses increased $10 million to $213 million in the first nine months of 2023 compared to $203 million in the first nine months of 2022. The increase was due primarily to higher costs related to certain corporate initiatives, including higher amortization due to our recently implemented enterprise resource planning (ERP) system.

U.K. Operations

In the first nine months of 2023, we recognized total charges of $7 million, consisting primarily of the recognition of an asset retirement obligation and post-employment benefits related to contractual and statutory obligations due to employees as a result of our approved plan to permanently close the Billingham ammonia plant in the third quarter of 2023.

In the first nine months of 2022, we recognized total charges of $257 million, consisting of $239 million of asset impairment charges primarily related to property, plant and equipment at our Billingham and Ince facilities and $18 million of restructuring charges primarily related to post-employment benefits related to contractual and statutory obligations and one-time termination benefits. See Note 5—United Kingdom Operations Restructuring for additional information.

Transaction Costs

On March 20, 2023, we entered into an asset purchase agreement with DNLA and IPL to acquire DNLA’s ammonia production complex located in Waggaman, Louisiana, as described above under “Agreement to Purchase Ammonia Production Facility.” In the nine months ended September 30, 2023, we incurred $27 million of transaction costs related to the acquisition agreement.

Other Operating—Net

Other operating—net was $19 million of income in the first nine months of 2023 compared to $33 million of expense in the first nine months of 2022. The $19 million of income in the first nine months of 2023 consists primarily of gains on the sales of emission credits, partially offset by FEED study costs for our proposed plans to construct an export-oriented blue ammonia facility with Mitsui, and a loss on foreign currency transactions of $5 million. See “Our Commitment to a Clean Energy Economy,” above, for additional information related to our proposed joint venture with Mitsui.

The $33 million of expense in the first nine months of 2022 consists primarily of a loss on foreign currency transactions of $38 million. Loss on foreign currency transactions consists of foreign currency exchange rate impacts on foreign currency denominated transactions, including the impact of changes in foreign currency exchange rates on intercompany loans that are not permanently invested.

Equity in (Losses) Earnings of Operating Affiliate

Equity in (losses) earnings of operating affiliate was $12 million of losses in the first nine months of 2023 compared to $74 million of earnings in the first nine months of 2022. The $12 million of losses in the first nine months of 2023 includes an

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impairment of our equity method investment in PLNL of $43 million recognized in the third quarter of 2023. See “Items Affecting Comparability of Results—Impairment of equity method investment in PLNL,” above, for further discussion. Lower equity in earnings of operating affiliate also reflects a decrease in the operating results of PLNL as a result of lower ammonia selling prices, partially offset by lower natural gas costs.

Interest Expense

Interest expense was $115 million in the first nine months of 2023 compared to $369 million in the first nine months of 2022. The decrease of $254 million was due primarily to $246 million of tax-related interest expense recorded in the first nine months of 2022, including $234 million of interest expense related to income tax matters described under “Items Affecting Comparability of Results—Canada Revenue Agency Competent Authority Matter” and “Items Affecting Comparability of Results—Transfer pricing positions,” above. In addition, the decrease in interest expense was due to lower interest expense on borrowings due to the redemption of $500 million principal amount of the 2023 Notes in April 2022 prior to their scheduled maturity.

Interest Income

Interest income was $115 million in the first nine months of 2023 compared to $56 million in the first nine months of 2022. The increase of $59 million reflects an $84 million increase in interest income on short-term investments in the first nine months of 2023 due primarily to higher interest rates. Partially offsetting this was interest income recorded in the first nine months of 2022 that did not recur in the first nine months of 2023, which was related to income tax matters described under “Items Affecting Comparability of Results—Canada Revenue Agency Competent Authority Matter” and “Items Affecting Comparability of Results—Transfer pricing positions,” above.

Loss on Debt Extinguishment

Loss on debt extinguishment of $8 million in the first nine months of 2022 is described under “Items Affecting Comparability of Results—Loss on debt extinguishment,” above.

Income Taxes

For the nine months ended September 30, 2023, we recorded an income tax provision of $326 million on pre-tax income of $1.81 billion, or an effective tax rate of 18.0%, compared to an income tax provision of $913 million on pre-tax income of $3.84 billion, or an effective tax rate of 23.8%, for the nine months ended September 30, 2022.

Our effective tax rate is impacted by earnings attributable to the noncontrolling interest in CFN, as our consolidated income tax provision does not include a tax provision on the earnings attributable to the noncontrolling interest. Our effective tax rate for the nine months ended September 30, 2023 of 18.0%, which is based on pre-tax income of $1.81 billion, including $235 million of earnings attributable to the noncontrolling interest, would be 2.7 percentage points higher, or 20.7%, if based on pre-tax income exclusive of the earnings attributable to the noncontrolling interest of $235 million. Our effective tax rate for the nine months ended September 30, 2022 of 23.8%, which is based on pre-tax income of $3.84 billion, including $442 million of earnings attributable to the noncontrolling interest, would be 3.1 percentage points higher, or 26.9%, if based on pre-tax income exclusive of the earnings attributable to the noncontrolling interest of $442 million.

In addition, for the nine months ended September 30, 2022, our income tax provision includes $18 million of income tax expense to record a valuation allowance in the United Kingdom, $22 million of income tax benefit due to share-based compensation activity and $78 million of income tax provision related to the Canada Revenue Agency Competent Authority Matter, which is described above under “Items Affecting Comparability of Results.”

Net Earnings Attributable to Noncontrolling Interest

Net earnings attributable to noncontrolling interest decreased $207 million to $235 million in the first nine months of 2023 compared to $442 million in the first nine months of 2022 due to lower earnings of CFN driven by lower average selling prices as described above under “Net Sales.”

Diluted Net Earnings Per Share Attributable to Common Stockholders

Diluted net earnings per share attributable to common stockholders decreased $5.62 to $6.42 per share in the first nine months of 2023 from $12.04 per share in the first nine months of 2022. This decrease was due primarily to a decrease in gross margin, driven by lower average selling prices, partially offset by lower costs for natural gas. Lower gross margin was partially offset by a decrease in the income tax provision resulting from lower profitability, a decrease in interest expense due primarily to interest expense on tax liabilities in the first ~~quarter~~nine months of 2022 related to Canadian-U.S. transfer pricing matters and a decrease in the income tax provision resulting from lower profitability. Additionally, diluted weighted-average common shares outstanding declined 6% from 209.9 million shares for the three months ended March 31, 2022 to 196.9 million shares for the three months ended March 31, 2023, due primarily to repurchases of common shares under our share repurchase program.

that did

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not recur in the first nine months of 2023, and pre-tax impairment and restructuring charges related to our U.K. operations of $257 million in the first nine months of 2022 compared to $7 million in the first nine months of 2023. Additionally, diluted weighted-average common shares outstanding declined 6% from 206.5 million shares for the nine months ended September 30, 2022 to 194.9 million shares for the nine months ended September 30, 2023, due primarily to repurchases of common shares under our share repurchase programs.

Operating Results by Business Segment

Our reportable segments consist of Ammonia, Granular Urea, UAN, AN and Other. These segments are differentiated by products. Our management uses gross margin to evaluate segment performance and allocate resources. Total other operating costs and expenses (consisting primarily of selling, general and administrative expenses and other operating—net) and non-operating expenses (consisting primarily of interest and income taxes), are centrally managed and are not included in the measurement of segment profitability reviewed by management. The following table presents summary operating results by business segment:


		Ammonia			Granular Urea(1)			UAN(1)			AN(1)			Other(1)			Consolidated				Ammonia			Granular Urea(1)			UAN(1)			AN(1)			Other(1)			Consolidated
		(in millions)																			(dollars in millions)

Three months ended March 31, 2023
Three months ended September 30, 2023																				Three months ended September 30, 2023
Net sales	Net sales	$	424		$	611		$	667		$	159		$	151		$	2,012		Net sales	$	235		$	360		$	435		$	114		$	129		$	1,273
Cost of sales	Cost of sales	280			327			346			104			92			1,149			Cost of sales	214			226			302			79			75			896
Gross margin	Gross margin	$	144		$	284		$	321		$	55		$	59		$	863		Gross margin	$	21		$	134		$	133		$	35		$	54		$	377
Gross margin percentage	Gross margin percentage	34.0		%	46.5		%	48.1		%	34.6		%	39.1		%	42.9		%	Gross margin percentage	8.9		%	37.2		%	30.6		%	30.7		%	41.9		%	29.6		%
Three months ended March 31, 2022
Three months ended September 30, 2022																				Three months ended September 30, 2022
Net sales	Net sales	$	640		$	765		$	1,015		$	223		$	225		$	2,868		Net sales	$	531		$	689		$	736		$	180		$	185		$	2,321
Cost of sales	Cost of sales	280			270			345			171			104			1,170			Cost of sales	353			394			414			136			108			1,405
Gross margin	Gross margin	$	360		$	495		$	670		$	52		$	121		$	1,698		Gross margin	$	178		$	295		$	322		$	44		$	77		$	916
Gross margin percentage	Gross margin percentage	56.3		%	64.7		%	66.0		%	23.3		%	53.8		%	59.2		%	Gross margin percentage	33.5		%	42.8		%	43.8		%	24.4		%	41.6		%	39.5		%
Nine months ended September 30, 2023																				Nine months ended September 30, 2023
Net sales																				Net sales	$	1,184		$	1,431		$	1,650		$	377		$	418		$	5,060
Cost of sales																				Cost of sales	797			775			937			264			243			3,016
Gross margin																				Gross margin	$	387		$	656		$	713		$	113		$	175		$	2,044
Gross margin percentage																				Gross margin percentage	32.7		%	45.8		%	43.2		%	30.0		%	41.9		%	40.4		%
Nine months ended September 30, 2022																				Nine months ended September 30, 2022
Net sales																				Net sales	$	2,286		$	2,287		$	2,727		$	656		$	622		$	8,578
Cost of sales																				Cost of sales	1,075			1,024			1,102			458			314			3,973
Gross margin																				Gross margin	$	1,211		$	1,263		$	1,625		$	198		$	308		$	4,605
Gross margin percentage																				Gross margin percentage	53.0		%	55.2		%	59.6		%	30.2		%	49.5		%	53.7		%

_______________________________________________________________________________

(1)The cost of the products that are upgraded into other products is transferred at cost into the upgraded product results.

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Ammonia Segment

Our Ammonia segment produces anhydrous ammonia (ammonia), which is the base product that we manufacture, containing 82% nitrogen and 18% hydrogen. The results of our Ammonia segment consist of sales of ammonia to external customers for its nitrogen content as a fertilizer, in emissions control and in other industrial applications. In addition, we upgrade ammonia into other nitrogen products such as granular urea, UAN and AN.

The following table presents summary operating data for our Ammonia segment:


		Three Months Ended March 31,					Three Months Ended September 30,														Nine Months Ended September 30,
			2023	2022				2023 v. 2022						2023				2022			2023 v. 2022						2023		2022			2023 v. 2022
				(dollars in millions, except per ton amounts)														(dollars in millions, except per ton amounts)
Net sales	Net sales			$	424			$	640		$	(216)			(34)	%	Net sales	$	235		$	531		$	(296)		(56)	%	$	1,184		$	2,286		$	(1,102)		(48)	%
Cost of sales	Cost of sales			280				280			—				—	%	Cost of sales	214			353			(139)			(39)	%	797			1,075			(278)			(26)	%
Gross margin	Gross margin			$	144			$	360		$	(216)			(60)	%	Gross margin	$	21		$	178		$	(157)		(88)	%	$	387		$	1,211		$	(824)		(68)	%
Gross margin percentage	Gross margin percentage			34.0		%		56.3		%	(22.3)		%				Gross margin percentage	8.9		%	33.5		%	(24.6)		%			32.7		%	53.0		%	(20.3)		%
Sales volume by product tons (000s)	Sales volume by product tons (000s)			652				727			(75)				(10)	%	Sales volume by product tons (000s)	764			643			121			19	%	2,469			2,405			64			3	%
Sales volume by nutrient tons (000s)(1)	Sales volume by nutrient tons (000s)(1)			535				596			(61)				(10)	%	Sales volume by nutrient tons (000s)(1)	627			528			99			19	%	2,025			1,973			52			3	%
Average selling price per product ton	Average selling price per product ton			$	650			$	880		$	(230)			(26)	%	Average selling price per product ton	$	308		$	826		$	(518)		(63)	%	$	480		$	951		$	(471)		(50)	%
Average selling price per nutrient ton(1)	Average selling price per nutrient ton(1)			$	793			$	1,074		$	(281)			(26)	%	Average selling price per nutrient ton(1)	$	375		$	1,006		$	(631)		(63)	%	$	585		$	1,159		$	(574)		(50)	%
Gross margin per product ton	Gross margin per product ton			$	221			$	495		$	(274)			(55)	%	Gross margin per product ton	$	27		$	277		$	(250)		(90)	%	$	157		$	504		$	(347)		(69)	%
Gross margin per nutrient ton(1)	Gross margin per nutrient ton(1)			$	269			$	604		$	(335)			(55)	%	Gross margin per nutrient ton(1)	$	33		$	337		$	(304)		(90)	%	$	191		$	614		$	(423)		(69)	%
Depreciation and amortization	Depreciation and amortization			$	31			$	34		$	(3)			(9)	%	Depreciation and amortization	$	39		$	35		$	4		11	%	$	117		$	119		$	(2)		(2)	%
Unrealized net mark-to-market gain on natural gas derivatives				$	(21)			$	(8)		$	(13)			(163)	%
Unrealized net mark-to-market loss (gain) on natural gas derivatives																	Unrealized net mark-to-market loss (gain) on natural gas derivatives	$	2		$	4		$	(2)		50	%	$	(19)		$	(6)		$	(13)		(217)	%

(1)Ammonia represents 82% nitrogen content. Nutrient tons represent the tons of nitrogen within the product tons.

~~First~~Third Quarter of 2023 Compared to ~~First~~Third Quarter of 2022

Net Sales. Net sales in our Ammonia segment decreased by ~~$216~~$296 million, or ~~34%~~56%, to ~~$424~~$235 million in the ~~first~~third quarter of 2023 from ~~$640~~$531 million in the ~~first~~third quarter of 2022 due to a ~~26%~~63% decrease in average selling prices, ~~and~~partially offset by a ~~10% decrease~~19% increase in sales volume. Average selling prices decreased to ~~$650~~$308 per ton in the ~~first~~third quarter of 2023 compared to ~~$880~~$826 per ton in the ~~first~~third quarter of 2022 due primarily to an increase in global supply availability as lower global energy costs drove higher global operating rates. ~~Sales~~The increase in sales volume was ~~lower~~ due primarily to ~~lower demand compared to a robust ammonia sales environment in the first quarter of 2022.~~higher supply availability resulting from higher beginning inventory.

Cost of Sales. Cost of sales in our Ammonia segment averaged ~~$429~~$281 per ton in the ~~first~~third quarter of 2023, ~~an 11% increase~~a 49% decrease from ~~$385~~$549 per ton in the ~~first~~third quarter of 2022. The ~~increase~~decrease was due primarily to ~~higher~~lower realized natural gas costs, including the impact of realized derivatives, ~~partially offset by~~ a lower cost per ton for ammonia purchased from PLNL, our joint venture in Trinidad, and lower manufacturing and maintenance costs.

Gross Margin. Gross margin in our Ammonia segment decreased by $157 million to $21 million in the third quarter of 2023 from $178 million in the third quarter of 2022, and our gross margin percentage was 8.9% in the third quarter of 2023 compared to 33.5% in the third quarter of 2022. The decrease in gross margin was due primarily to a 63% decrease in average selling prices, which decreased gross margin by $391 million. This decrease in gross margin was partially offset by a decrease in realized natural gas costs, including the impact of realized derivatives, which increased gross margin by $121 million, a net decrease in manufacturing, maintenance and other costs, which increased gross margin by $57 million, and an increase in sales volume, which increased gross margin by $54 million. Gross margin in the third quarter of 2023 also includes the impact of a $2 million unrealized net mark-to-market loss on natural gas derivatives compared to a $4 million loss in the third quarter of 2022.

Nine Months Ended September 30, 2023 Compared to Nine Months Ended September 30, 2022

Net Sales. Net sales in our Ammonia segment decreased by $1.10 billion, or 48%, to $1.18 billion in the nine months ended September 30, 2023 from $2.29 billion in the nine months ended September 30, 2022 due to a 50% decrease in average selling prices, partially offset by a 3% increase in sales volume. Average selling prices decreased to $480 per ton in the nine

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months ended September 30, 2023 compared to $951 per ton in the nine months ended September 30, 2022 due primarily to an increase in global supply availability as lower global energy costs drove higher global operating rates.

Cost of Sales. Cost of sales in our Ammonia segment averaged $323 per ton in the nine months ended September 30, 2023, a 28% decrease from $447 per ton in the nine months ended September 30, 2022. The decrease was due primarily to lower realized natural gas costs, including the impact of realized derivatives, and a lower cost per ton for ammonia purchased from PLNL, our joint venture in Trinidad.

Gross Margin. Gross margin in our Ammonia segment decreased by ~~$216~~$824 million to ~~$144~~$387 million in the ~~first quarter of~~nine months ended September 30, 2023 from ~~$360 million~~$1.21 billion in the ~~first quarter of~~nine months ended September 30, 2022, and our gross margin percentage was ~~34.0%~~32.7% in the ~~first quarter of~~nine months ended September 30, 2023 compared to ~~56.3%~~53.0% in the ~~first quarter of~~nine months ended September 30, 2022. The decrease in gross margin was due primarily to a ~~26%~~ 50% decrease in average selling prices, which decreased gross margin by ~~$144 million, a 10% decrease~~$1.14 billion, and the impact of changes in sales volume and mix, which decreased gross margin by $37 million. These factors that decreased gross margin were partially offset by ~~$63~~a net decrease in manufacturing, maintenance and other costs, which increased gross margin by $183 million, and ~~an increase~~a decrease in realized natural gas costs, including the impact of realized derivatives, which ~~reduced~~increased gross margin by ~~$47~~$157 million. ~~The factors that decreased gross margin were partially offset by a $25 million net decrease in manufacturing, maintenance and other costs, driven by lower purchased product costs.~~ Gross margin also includes the impact of a $2119 million unrealized net mark-to-market gain on natural gas derivatives in the ~~first quarter of~~nine months ended September 30, 2023 compared to ana $86 million gain in the ~~first quarter of~~nine months ended September 30, 2022.

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Granular Urea Segment

Our Granular Urea segment produces granular urea, which contains 46% nitrogen. Produced from ammonia and carbon dioxide, it has the highest nitrogen content of any of our solid nitrogen fertilizers. Granular urea is produced at our Donaldsonville, Port Neal and Medicine Hat ~~nitrogen~~ complexes.

The following table presents summary operating data for our Granular Urea segment:


		Three Months Ended March 31,					Three Months Ended September 30,														Nine Months Ended September 30,
			2023	2022				2023 v. 2022						2023				2022			2023 v. 2022						2023		2022			2023 v. 2022
				(dollars in millions, except per ton amounts)														(dollars in millions, except per ton amounts)
Net sales	Net sales			$	611			$	765		$	(154)			(20)	%	Net sales	$	360		$	689		$	(329)		(48)	%	$	1,431		$	2,287		$	(856)		(37)	%
Cost of sales	Cost of sales			327				270			57				21	%	Cost of sales	226			394			(168)			(43)	%	775			1,024			(249)			(24)	%
Gross margin	Gross margin			$	284			$	495		$	(211)			(43)	%	Gross margin	$	134		$	295		$	(161)		(55)	%	$	656		$	1,263		$	(607)		(48)	%
Gross margin percentage	Gross margin percentage			46.5		%		64.7		%	(18.2)		%				Gross margin percentage	37.2		%	42.8		%	(5.6)		%			45.8		%	55.2		%	(9.4)		%
Sales volume by product tons (000s)	Sales volume by product tons (000s)			1,323				1,096			227				21	%	Sales volume by product tons (000s)	1,062			1,262			(200)			(16)	%	3,532			3,539			(7)			—	%
Sales volume by nutrient tons (000s)(1)	Sales volume by nutrient tons (000s)(1)			608				504			104				21	%	Sales volume by nutrient tons (000s)(1)	488			580			(92)			(16)	%	1,625			1,628			(3)			—	%
Average selling price per product ton	Average selling price per product ton			$	462			$	698		$	(236)			(34)	%	Average selling price per product ton	$	339		$	546		$	(207)		(38)	%	$	405		$	646		$	(241)		(37)	%
Average selling price per nutrient ton(1)	Average selling price per nutrient ton(1)			$	1,005			$	1,518		$	(513)			(34)	%	Average selling price per nutrient ton(1)	$	738		$	1,188		$	(450)		(38)	%	$	881		$	1,405		$	(524)		(37)	%
Gross margin per product ton	Gross margin per product ton			$	215			$	452		$	(237)			(52)	%	Gross margin per product ton	$	126		$	234		$	(108)		(46)	%	$	186		$	357		$	(171)		(48)	%
Gross margin per nutrient ton(1)	Gross margin per nutrient ton(1)			$	467			$	982		$	(515)			(52)	%	Gross margin per nutrient ton(1)	$	275		$	509		$	(234)		(46)	%	$	404		$	776		$	(372)		(48)	%
Depreciation and amortization	Depreciation and amortization			$	79			$	64		$	15			23	%	Depreciation and amortization	$	66		$	79		$	(13)		(16)	%	$	216		$	213		$	3		1	%
Unrealized net mark-to-market gain on natural gas derivatives				$	(20)			$	(7)		$	(13)			(186)	%
Unrealized net mark-to-market loss (gain) on natural gas derivatives																	Unrealized net mark-to-market loss (gain) on natural gas derivatives	$	2		$	4		$	(2)		(50)	%	$	(18)		$	(4)		$	(14)		(350)	%

(1)Granular urea represents 46% nitrogen content. Nutrient tons represent the tons of nitrogen within the product tons.

~~First~~Third Quarter of 2023 Compared to ~~First~~Third Quarter of 2022

Net Sales. Net sales in our Granular Urea segment decreased ~~$154~~$329 million, or ~~20%~~48%, to ~~$611~~$360 million in the ~~first~~third quarter of 2023 from ~~$765~~$689 million in the ~~first~~third quarter of 2022 due primarily to a ~~34%~~38% decrease in average selling prices ~~partially offset by~~and a ~~21% increase~~16% decrease in sales volume. Average selling prices decreased to ~~$462~~$339 per ton in the ~~first~~third quarter of 2023 compared to ~~$698~~$546 per ton in the ~~first~~third quarter of 2022, due primarily to an increase in global supply availability as lower global energy costs drove higher global operating rates and new global production came on line. Sales volume was lower due primarily to lower supply availability resulting from lower production and lower beginning inventory.

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Cost of Sales. Cost of sales in our Granular Urea segment averaged $213 per ton in the third quarter of 2023 compared to $312 per ton in the third quarter of 2022. The decrease was due primarily to lower realized natural gas costs, including the impact of realized derivatives.

Gross Margin. Gross margin in our Granular Urea segment decreased by $161 million to $134 million in the third quarter of 2023 from $295 million in the third quarter of 2022, and our gross margin percentage was 37.2% in the third quarter of 2023 compared to 42.8% in the third quarter of 2022. The decrease in gross margin was due primarily to a 38% decrease in average selling prices, which decreased gross margin by $217 million, a 16% decrease in sales volume, which decreased gross margin by $54 million, and a net increase in manufacturing, maintenance and other costs, which decreased gross margin by $4 million. These factors that decreased gross margin were partially offset by a decrease in realized natural gas costs, including the impact of realized derivatives, which increased gross margin by $112 million. Gross margin in the third quarter of 2023 also includes the impact of a $2 million unrealized net mark-to-market loss on natural gas derivatives compared to a $4 million loss in the third quarter of 2022.

Nine Months Ended September 30, 2023 Compared to Nine Months Ended September 30, 2022

Net Sales. Net sales in our Granular Urea segment decreased $856 million, or 37%, to $1.43 billion in the nine months ended September 30, 2023 from $2.29 billion in the nine months ended September 30, 2022 due primarily to a 37% decrease in average selling prices. Average selling prices decreased to $405 per ton in the nine months ended September 30, 2023 compared to $646 per ton in the nine months ended September 30, 2022, due primarily to an increase in global supply availability ~~resulting from~~as lower global energy costs drove higher global operating rates and new global production ~~coming online. Sales volume was higher due primarily to greater supply availability resulting from higher production.~~came on line.

Cost of Sales. Cost of sales in our Granular Urea segment averaged ~~$247~~$219 per ton in the ~~first quarter of~~nine months ended September 30, 2023 compared to ~~$246~~$289 per ton in the ~~first quarter of 2022, as higher~~nine months ended September 30, 2022. The decrease was due primarily to lower realized natural gas costs, including the impact of realized ~~derivatives, were partially offset by the impact of lower production costs.~~derivatives.

Gross Margin. Gross margin in our Granular Urea segment decreased by ~~$211~~$607 million to ~~$284~~$656 million in the ~~first quarter of~~nine months ended September 30, 2023 from ~~$495 million~~$1.26 billion in the ~~first quarter of~~nine months ended September 30, 2022, and our gross margin percentage was ~~46.5%~~45.8% in the ~~first quarter of~~nine months ended September 30, 2023 compared to ~~64.7%~~55.2% in the ~~first quarter of~~nine months ended September 30, 2022. The decrease in gross margin was due primarily to a ~~34%~~37% decrease in average selling prices, which decreased gross margin by ~~$313 million, and an increase~~$890 million. The decrease in average selling prices was partially offset by a decrease in realized natural gas costs, including the impact of realized derivatives, which ~~reduced~~increased gross margin by ~~$19 million. The factors that reduced gross margin were partially offset by a 21% increase~~$199 million, the impact of changes in sales volume and mix, which increased gross margin by ~~$104~~$65 million,, and a ~~$4 million~~ net decrease in manufacturing, maintenance and other ~~costs.~~costs, which increased gross margin by $5 million. Gross margin also includes the impact of ~~a $20~~an $18 million unrealized net mark-to-market gain on natural gas derivatives in the ~~first quarter of~~nine months ended September 30, 2023 compared to a $7$4 million gain in the ~~first quarter of~~nine months ended September 30, 2022.

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UAN Segment

Our UAN segment produces urea ammonium nitrate solution (UAN). UAN, a liquid fertilizer product with a nitrogen content that typically ranges from 28% to 32%, is produced by combining urea and ammonium nitrate. UAN is produced at our Courtright, Donaldsonville, Port Neal, Verdigris, Woodward and Yazoo City ~~nitrogen~~ complexes.

The following table presents summary operating data for our UAN segment:


		Three Months Ended March 31,					Three Months Ended September 30,														Nine Months Ended September 30,
			2023	2022				2023 v. 2022						2023				2022			2023 v. 2022						2023		2022			2023 v. 2022
				(dollars in millions, except per ton amounts)														(dollars in millions, except per ton amounts)
Net sales	Net sales			$	667			$	1,015		$	(348)			(34)	%	Net sales	$	435		$	736		$	(301)		(41)	%	$	1,650		$	2,727		$	(1,077)		(39)	%
Cost of sales	Cost of sales			346				345			1				—	%	Cost of sales	302			414			(112)			(27)	%	937			1,102			(165)			(15)	%
Gross margin	Gross margin			$	321			$	670		$	(349)			(52)	%	Gross margin	$	133		$	322		$	(189)		(59)	%	$	713		$	1,625		$	(912)		(56)	%
Gross margin percentage	Gross margin percentage			48.1		%		66.0		%	(17.9)		%				Gross margin percentage	30.6		%	43.8		%	(13.2)		%			43.2		%	59.6		%	(16.4)		%
Sales volume by product tons (000s)	Sales volume by product tons (000s)			1,662				1,828			(166)				(9)	%	Sales volume by product tons (000s)	1,954			1,644			310			19	%	5,425			5,098			327			6	%
Sales volume by nutrient tons (000s)(1)	Sales volume by nutrient tons (000s)(1)			524				576			(52)				(9)	%	Sales volume by nutrient tons (000s)(1)	616			519			97			19	%	1,710			1,610			100			6	%
Average selling price per product ton	Average selling price per product ton			$	401			$	555		$	(154)			(28)	%	Average selling price per product ton	$	223		$	448		$	(225)		(50)	%	$	304		$	535		$	(231)		(43)	%
Average selling price per nutrient ton(1)	Average selling price per nutrient ton(1)			$	1,273			$	1,762		$	(489)			(28)	%	Average selling price per nutrient ton(1)	$	706		$	1,418		$	(712)		(50)	%	$	965		$	1,694		$	(729)		(43)	%
Gross margin per product ton	Gross margin per product ton			$	193			$	367		$	(174)			(47)	%	Gross margin per product ton	$	68		$	196		$	(128)		(65)	%	$	131		$	319		$	(188)		(59)	%
Gross margin per nutrient ton(1)	Gross margin per nutrient ton(1)			$	613			$	1,163		$	(550)			(47)	%	Gross margin per nutrient ton(1)	$	216		$	620		$	(404)		(65)	%	$	417		$	1,009		$	(592)		(59)	%
Depreciation and amortization	Depreciation and amortization			$	66			$	70		$	(4)			(6)	%	Depreciation and amortization	$	78		$	73		$	5		7	%	$	214		$	208		$	6		3	%
Unrealized net mark-to-market gain on natural gas derivatives				$	(21)			$	(8)		$	(13)			(163)	%
Unrealized net mark-to-market loss (gain) on natural gas derivatives																	Unrealized net mark-to-market loss (gain) on natural gas derivatives	$	3		$	4		$	(1)		(25)	%	$	(18)		$	(4)		$	(14)		(350)	%

(1)UAN represents between 28% and 32% of nitrogen content. Nutrient tons represent the tons of nitrogen within the product tons.

~~First~~Third Quarter of 2023 Compared to ~~First~~Third Quarter of 2022

Net Sales. Net sales in our UAN segment decreased ~~$348~~$301 million, or ~~34%~~41%, to ~~$667~~$435 million in the ~~first~~third quarter of 2023 from ~~$1.02 billion~~$736 million in the ~~first~~third quarter of 2022 due to a ~~28%~~50% decrease in average selling prices, ~~and~~partially offset by a ~~9% decrease~~19% increase in sales volume. Average selling prices decreased to ~~$401~~$223 per ton in the ~~first~~third quarter of 2023 compared to ~~$555~~$448 per ton in the ~~first~~third quarter of 2022 due primarily to an increase in global supply availability as lower global energy costs drove higher global operating rates. ~~Sales~~The increase in sales volume was ~~lower~~ due primarily to ~~lower~~higher supply availability resulting from ~~a decrease in~~higher production.

Cost of Sales. Cost of sales in our UAN segment averaged ~~$208~~$155 per ton in the ~~first~~third quarter of 2023, ~~an 11% increase~~a 38% decrease from ~~$188~~$252 per ton in the ~~first~~third quarter of 2022, due primarily to the impact of ~~higher~~lower realized natural gas costs, including the impact of realized derivatives, and ~~higher production~~lower manufacturing and maintenance costs.

Gross Margin. Gross margin in our UAN segment decreased by ~~$349~~$189 million to ~~$321~~$133 million in the ~~first~~third quarter of 2023 from ~~$670~~$322 million in the ~~first~~third quarter of 2022, and our gross margin percentage was ~~48.1%~~30.6% in the ~~first~~third quarter of 2023 compared to ~~66.0%~~43.8% in the ~~first~~third quarter of 2022. The decrease in gross margin was due primarily to a ~~28%~~50% decrease in average selling prices, which decreased gross margin by ~~$259 million, a 9%~~$446 million. This decrease in ~~sales volume, which decreased~~ gross margin was partially offset by ~~$63 million, an increase~~a decrease in realized natural gas costs, including the impact of realized derivatives, which ~~reduced~~increased gross margin by ~~$29~~$142 million, a 19% increase in sales volume, which increased gross margin by $84 million, and a net ~~increase~~decrease in manufacturing, maintenance and other costs, which ~~reduced~~increased gross margin by ~~$11 million~~.$30 million. Gross margin in the third quarter of 2023 also includes the impact of a ~~$21~~$3 million unrealized net mark-to-market ~~gain~~loss on natural gas derivatives compared to a $4 million loss in the ~~first quarter of 2023 compared to an $8 million gain in the first~~third quarter of 2022.

Nine Months Ended September 30, 2023 Compared to Nine Months Ended September 30, 2022

Net Sales. Net sales in our UAN segment decreased $1.08 billion, or 39%, to $1.65 billion in the nine months ended September 30, 2023 from $2.73 billion in the nine months ended September 30, 2022 due primarily to a 43% decrease in average selling prices, partially offset by a 6% increase in sales volume. Average selling prices decreased to $304 per ton in the nine months ended September 30, 2023 compared to $535 per ton in the nine months ended September 30, 2022 due primarily to an increase in global supply availability as lower global energy costs drove higher global operating rates and an increase in

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Russian imports into the United States. The increase in sales volume was due primarily to higher supply availability resulting from higher production.

Cost of Sales. Cost of sales in our UAN segment averaged $173 per ton in the nine months ended September 30, 2023, a 20% decrease from $216 per ton in the nine months ended September 30, 2022, due primarily to the impact of lower realized natural gas costs, including the impact of realized derivatives.

Gross Margin. Gross margin in our UAN segment decreased by $912 million to $713 million in the nine months ended September 30, 2023 from $1.63 billion in the nine months ended September 30, 2022, and our gross margin percentage was 43.2% in the nine months ended September 30, 2023 compared to 59.6% in the nine months ended September 30, 2022. The decrease in gross margin was due primarily to a 43% decrease in average selling prices, which decreased gross margin by $1.24 billion. This decrease in gross margin was partially offset by a decrease in realized natural gas costs, including the impact of realized derivatives, which increased gross margin by $200 million, a 6% increase in sales volume, which increased gross margin by $101 million, and a net decrease in manufacturing, maintenance and other costs, which increased gross margin by $17 million. Gross margin also includes the impact of an $18 million unrealized net mark-to-market gain on natural gas derivatives in the nine months ended September 30, 2023 compared to a $4 million gain in the nine months ended September 30, 2022.

AN Segment

Our AN segment produces ammonium nitrate (AN). AN, which has a nitrogen content between 29% and 35%, is produced by combining anhydrous ammonia and nitric acid. AN is used as nitrogen fertilizer and is also used by industrial customers for commercial explosives and blasting systems. AN is produced at our Yazoo City and Billingham ~~nitrogen~~ complexes.

The following table presents summary operating data for our AN segment:


		Three Months Ended March 31,					Three Months Ended September 30,														Nine Months Ended September 30,
			2023	2022				2023 v. 2022						2023				2022			2023 v. 2022						2023		2022			2023 v. 2022
				(dollars in millions, except per ton amounts)														(dollars in millions, except per ton amounts)
Net sales	Net sales			$	159			$	223		$	(64)			(29)	%	Net sales	$	114		$	180		$	(66)		(37)	%	$	377		$	656		$	(279)		(43)	%
Cost of sales	Cost of sales			104				171			(67)				(39)	%	Cost of sales	79			136			(57)			(42)	%	264			458			(194)			(42)	%
Gross margin	Gross margin			$	55			$	52		$	3			6	%	Gross margin	$	35		$	44		$	(9)		(20)	%	$	113		$	198		$	(85)		(43)	%
Gross margin percentage	Gross margin percentage			34.6		%		23.3		%	11.3		%				Gross margin percentage	30.7		%	24.4		%	6.3		%			30.0		%	30.2		%	(0.2)		%
Sales volume by product tons (000s)	Sales volume by product tons (000s)			374				428			(54)				(13)	%	Sales volume by product tons (000s)	414			363			51			14	%	1,157			1,227			(70)			(6)	%
Sales volume by nutrient tons (000s)(1)	Sales volume by nutrient tons (000s)(1)			128				146			(18)				(12)	%	Sales volume by nutrient tons (000s)(1)	141			124			17			14	%	396			419			(23)			(5)	%
Average selling price per product ton	Average selling price per product ton			$	425			$	521		$	(96)			(18)	%	Average selling price per product ton	$	275		$	496		$	(221)		(45)	%	$	326		$	535		$	(209)		(39)	%
Average selling price per nutrient ton(1)	Average selling price per nutrient ton(1)			$	1,242			$	1,527		$	(285)			(19)	%	Average selling price per nutrient ton(1)	$	809		$	1,452		$	(643)		(44)	%	$	952		$	1,566		$	(614)		(39)	%
Gross margin per product ton	Gross margin per product ton			$	147			$	121		$	26			21	%	Gross margin per product ton	$	85		$	121		$	(36)		(30)	%	$	98		$	161		$	(63)		(39)	%
Gross margin per nutrient ton(1)	Gross margin per nutrient ton(1)			$	430			$	356		$	74			21	%	Gross margin per nutrient ton(1)	$	248		$	355		$	(107)		(30)	%	$	285		$	473		$	(188)		(40)	%
Depreciation and amortization	Depreciation and amortization			$	11			$	17		$	(6)			(35)	%	Depreciation and amortization	$	13		$	14		$	(1)		(7)	%	$	36		$	48		$	(12)		(25)	%
Unrealized net mark-to-market gain on natural gas derivatives	Unrealized net mark-to-market gain on natural gas derivatives			$	(3)			$	(6)		$	3			50	%	Unrealized net mark-to-market gain on natural gas derivatives	$	—		$	(1)		$	1		100	%	$	(3)		$	(18)		$	15		83	%

(1)AN represents between 29% and 35% of nitrogen content. Nutrient tons represent the tons of nitrogen within the product tons.

~~First~~Third Quarter of 2023 Compared to ~~First~~Third Quarter of 2022

In September 2022, as a result of extremely high and volatile natural gas prices and the lack of a corresponding increase in global nitrogen product market prices, we ~~temporarily~~ idled ammonia production at our Billingham complex. Since that time, we have imported ammonia for upgrade into AN and other nitrogen products at that ~~location.~~location, including nitric acid and aqua ammonia, which are included in our Other segment. In the third quarter of 2023, we approved our plan to permanently close the ammonia plant at our Billingham complex.

Net Sales. Net sales in our AN segment decreased ~~$64~~$66 million, or ~~29%~~37%, to ~~$159~~$114 million in the ~~first~~third quarter of 2023 from ~~$223~~$180 million in the ~~first~~third quarter of 2022 due to ~~an 18%~~a 45% decrease in average selling prices, ~~and~~partially offset by a ~~13% decrease~~14% increase in sales volume. Average selling prices decreased to ~~$425~~$275 per ton in the ~~first~~third quarter of 2023 compared to ~~$521~~$496 per ton in the ~~first~~third quarter of 2022 due primarily to an increase in global supply availability as lower global energy costs drove higher global operating rates. Sales volume ~~declined~~increased due primarily to ~~weak domestic demand in the United Kingdom.~~higher supply availability resulting from higher production.

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Cost of Sales. Cost of sales in our AN segment averaged ~~$278~~$190 per ton in the ~~first~~third quarter of 2023, a ~~31%~~49% decrease from ~~$400~~$375 per ton in the ~~first~~third quarter of 2022. The decrease was due primarily to lower production costs for our Billingham complex in the ~~first~~third quarter of 2023, as purchased ammonia was used for upgrading into AN as compared to the higher-cost natural gas used to produce ammonia to upgrade into AN in the ~~first~~third quarter of 2022. In addition, the decrease in cost of sales per ton reflects lower realized natural gas costs in North America in the third quarter of 2023 compared to the third quarter of 2022.

Gross Margin. Gross margin in our AN segment ~~increased $3~~decreased $9 million to ~~$55~~$35 million in the ~~first~~third quarter of 2023 from ~~$52~~$44 million in the ~~first quarter of 2022, and our gross margin percentage was 34.6% in the first quarter of 2023 compared to 23.3% in the first~~third quarter of 2022. The ~~increase~~decrease in gross margin reflects the following:

•a decrease in ~~realized natural gas costs, due primarily to the idling~~average selling prices of ~~the Billingham ammonia plant,~~45%, which decreased gross margin by $88 million, partially offset by an increase in sales volume of 14%, which increased gross margin by ~~$55~~$5 million;

•a decrease in realized natural gas costs, which increased gross margin by $77 million, due primarily to the closure of our Billingham ammonia plant, partially offset by a net increase in manufacturing, maintenance and other costs of $2 million, driven by the cost for purchased ammonia for upgrade at our Billingham complex, partially offset by lower production costs; and

•the impact of a $1 million unrealized net mark-to-market gain on natural gas derivatives in the third quarter of 2022.

Our gross margin percentage was 30.7% in the third quarter of 2023 compared to 24.4% in the third quarter of 2022. The increase was due primarily to lower production costs for our Billingham complex in the third quarter of 2023 as purchased ammonia was used for upgrading into AN as compared to the higher-cost natural gas used to produce ammonia to upgrade into AN in the third quarter of 2022.

Nine Months Ended September 30, 2023 Compared to Nine Months Ended September 30, 2022

Net Sales. Net sales in our AN segment decreased $279 million, or 43%, to $377 million in the nine months ended September 30, 2023 from $656 million in the nine months ended September 30, 2022 due to a 39% decrease in average selling prices and a 6% decrease in sales volume. Average selling prices decreased to $326 per ton in the nine months ended September 30, 2023 compared to $535 per ton in the nine months ended September 30, 2022 due primarily to an increase in global supply availability as lower global energy costs drove higher global operating rates. Sales volume decreased due primarily to lower supply availability resulting from lower production.

Cost of Sales. Cost of sales in our AN segment averaged $228 per ton in the nine months ended September 30, 2023, a 39% decrease from $374 per ton in the nine months ended September 30, 2022. The decrease was due primarily to lower production costs for our Billingham complex in the first nine months of 2023, as purchased ammonia was used for upgrading into AN as compared to the higher-cost natural gas used to produce ammonia to upgrade into AN in the first nine months of 2022. In addition, the decrease in cost of sales per ton reflects lower realized natural gas costs in North America in the first nine months of 2023 compared to the first nine months of 2022.

Gross Margin. Gross margin in our AN segment decreased $85 million to $113 million in the nine months ended September 30, 2023 from $198 million in the nine months ended September 30, 2022, and our gross margin percentage was 30.0% in the nine months ended September 30, 2023 compared to 30.2% in the nine months ended September 30, 2022. The decrease in gross margin reflects the following:

•a decrease in average selling prices of 39%, which decreased gross margin by $198 million, and a decrease in sales volume of 6%, which decreased gross margin by $20 million;

•a decrease in realized natural gas costs, which increased gross margin by $183 million, due primarily to the closure of our Billingham ammonia plant, partially offset by a net increase of ~~$25~~$35 million in manufacturing, maintenance and other costs, driven by the cost for purchased ammonia for upgrade at our Billingham complex, partially offset by lower production costs;

•~~favorable location product mix, which increased gross margin by $2 million;~~

•~~a decrease in average selling prices of 18%, which decreased gross margin by $26 million;~~ and

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•the impact of a $3 million unrealized net mark-to-market gain on natural gas derivatives in the ~~first quarter of~~nine months ended September 30, 2023 compared to ~~a $6~~an $18 million gain in the ~~first quarter~~nine months ended September 30, 2022.

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Other Segment

Our Other segment primarily includes the following products:

•diesel exhaust fluid (DEF), an aqueous urea solution typically made with 32.5% or 50% high-purity urea and the remainder deionized water;

•urea liquor, a liquid product that we sell in concentrations of 40%, 50% and 70% urea as a chemical ~~intermediate~~intermediate; and

•nitric acid, a nitrogen-based mineral acid that is used in the production of nitrate-based fertilizers, nylon precursors and other specialty chemicals.

The following table presents summary operating data for our Other segment:


		Three Months Ended March 31,					Three Months Ended September 30,														Nine Months Ended September 30,
			2023	2022				2023 v. 2022						2023				2022			2023 v. 2022						2023		2022			2023 v. 2022
				(dollars in millions, except per ton amounts)														(dollars in millions, except per ton amounts)
Net sales	Net sales			$	151			$	225		$	(74)			(33)	%	Net sales	$	129		$	185		$	(56)		(30)	%	$	418		$	622		$	(204)		(33)	%
Cost of sales	Cost of sales			92				104			(12)				(12)	%	Cost of sales	75			108			(33)			(31)	%	243			314			(71)			(23)	%
Gross margin	Gross margin			$	59			$	121		$	(62)			(51)	%	Gross margin	$	54		$	77		$	(23)		(30)	%	$	175		$	308		$	(133)		(43)	%
Gross margin percentage	Gross margin percentage			39.1		%		53.8		%	(14.7)		%				Gross margin percentage	41.9		%	41.6		%	0.3		%			41.9		%	49.5		%	(7.6)		%
Sales volume by product tons (000s)	Sales volume by product tons (000s)			524				545			(21)				(4)	%	Sales volume by product tons (000s)	551			496			55			11	%	1,635			1,598			37			2	%
Sales volume by nutrient tons (000s)(1)	Sales volume by nutrient tons (000s)(1)			103				104			(1)				(1)	%	Sales volume by nutrient tons (000s)(1)	108			99			9			9	%	321			313			8			3	%
Average selling price per product ton	Average selling price per product ton			$	288			$	413		$	(125)			(30)	%	Average selling price per product ton	$	234		$	373		$	(139)		(37)	%	$	256		$	389		$	(133)		(34)	%
Average selling price per nutrient ton(1)	Average selling price per nutrient ton(1)			$	1,466			$	2,163		$	(697)			(32)	%	Average selling price per nutrient ton(1)	$	1,194		$	1,869		$	(675)		(36)	%	$	1,302		$	1,987		$	(685)		(34)	%
Gross margin per product ton	Gross margin per product ton			$	113			$	222		$	(109)			(49)	%	Gross margin per product ton	$	98		$	155		$	(57)		(37)	%	$	107		$	193		$	(86)		(45)	%
Gross margin per nutrient ton(1)	Gross margin per nutrient ton(1)			$	573			$	1,163		$	(590)			(51)	%	Gross margin per nutrient ton(1)	$	500		$	778		$	(278)		(36)	%	$	545		$	984		$	(439)		(45)	%
Depreciation and amortization	Depreciation and amortization			$	16			$	19		$	(3)			(16)	%	Depreciation and amortization	$	15		$	17		$	(2)		(12)	%	$	48		$	53		$	(5)		(9)	%
Unrealized net mark-to-market gain on natural gas derivatives	Unrealized net mark-to-market gain on natural gas derivatives			$	(7)			$	(4)		$	(3)			(75)	%	Unrealized net mark-to-market gain on natural gas derivatives	$	—		$	—		$	—		—	%	$	(7)		$	(7)		$	—		—	%

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(1)Nutrient tons represent the tons of nitrogen within the product tons.

~~First~~Third Quarter of 2023 Compared to ~~First~~Third Quarter of 2022

In June 2022, we approved and announced our proposed plan to restructure our U.K. operations, including the planned permanent closure of our Ince facility. In August 2022, the final restructuring plan was approved, and decommissioning activities were initiated. We produced compound fertilizer products (NPKs), which are solid granular fertilizer products for which the nutrient content is a combination of nitrogen, phosphorus and potassium, only at our Ince facility, and closure of this facility resulted in our discontinuation of the NPK product line.

Net Sales. Net sales in our Other segment decreased by ~~$74~~$56 million, or ~~33%~~30%, to ~~$151~~$129 million in the ~~first~~third quarter of 2023 from ~~$225~~$185 million in the ~~first~~third quarter of 2022 due to a ~~30%~~37% decrease in average selling prices, ~~and a 4% decrease~~partially offset by an 11% increase in sales volume. The decrease in average selling prices was due primarily to an increase in global supply availability as lower global energy costs drove higher global operating rates. The ~~decrease~~increase in sales volume was due ~~primarily~~ to ~~lower~~higher DEF and nitric acid ~~and NPK~~ sales volumes, ~~in the first quarter of 2023,~~ partially offset by ~~higher DEF~~lower urea liquor sales ~~volumes.~~volume.

Cost of Sales. Cost of sales in our Other segment averaged ~~$175~~$136 per ton in the ~~first~~third quarter of 2023, ~~an 8%~~a 38% decrease from ~~$191~~$218 per ton in the ~~first~~third quarter of 2022, due primarily to lower production costs for our Billingham complex in the ~~idling~~third quarter of ~~the Billingham ammonia plant and its usage of~~2023, as purchased ammonia was used for upgrading ~~and~~into other nitrogen products as compared to the higher-cost natural gas used to produce ammonia to upgrade into other nitrogen products in the third quarter of 2022.In addition, the decrease in cost of sales per ton reflects lower ~~other manufacturing costs.~~realized natural gas costs in North America in the third quarter of 2023 compared to the third quarter of 2022.

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Gross Margin. Gross margin in our Other segment decreased by ~~$62~~$23 million to ~~$59~~$54 million in the ~~first~~third quarter of 2023 from ~~$121~~$77 million in the ~~first~~third quarter of 2022, and our gross margin percentage was ~~39.1%~~41.9% in the ~~first~~third quarter of 2023 compared to ~~53.8%~~41.6% in the ~~first~~third quarter of 2022. The decrease in gross margin reflects the following:

•a decrease in average selling prices of ~~30%~~37%, which decreased gross margin by ~~$62~~$74 million, partially offset by an increase in sales volume of 11%, which increased gross margin by $8 million; and

•a decrease in realized natural gas costs, which increased gross margin by $44 million, due primarily to the closure of our Billingham ammonia plant, partially offset by a net increase of ~~$13~~$1 million in manufacturing, maintenance and other costs, driven by the cost for purchased ammonia for upgrade at our Billingham complex, partially offset by lower production ~~costs, which net increase was~~costs.

Nine Months Ended September 30, 2023 Compared to Nine Months Ended September 30, 2022

Net Sales. Net sales in our Other segment decreased by $204 million, or 33%, to $418 million in the nine months ended September 30, 2023 from $622 million in the nine months ended September 30, 2022 due to a 34% decrease in average selling prices partially offset by a 2% increase in sales volume. The decrease in average selling prices was due primarily to an increase in global supply availability as lower global energy costs drove higher global operating rates.

Cost of Sales. Cost of sales in our Other segment averaged $149 per ton in the nine months ended September 30, 2023, a 24% decrease from $196 per ton in the nine months ended September 30, 2022, due primarily to lower production costs for our Billingham complex in the first nine months of 2023, as purchased ammonia was used for upgrading into other nitrogen products as compared to the higher-cost natural gas used to produce ammonia to upgrade into other nitrogen products in the first nine months of 2022.

Gross Margin. Gross margin in our Other segment decreased by $133 million to $175 million in the nine months ended September 30, 2023 from $308 million in the nine months ended September 30, 2022, and our gross margin percentage was 41.9% in the nine months ended September 30, 2023 compared to 49.5% in the nine months ended September 30, 2022. The decrease in gross margin reflects the following:

•a decrease in average selling prices of 34%, which decreased gross margin by $212 million, partially offset by an increase in sales volume of 2%, which increased gross margin by $10 million; and

•a decrease in realized natural gas costs, ~~due primarily to the idling of the Billingham ammonia plant,~~ which increased gross margin by ~~$12 million;~~

•$89 million, due primarily to the closure of our Billingham ammonia plant, partially offset by a ~~decrease~~net increase of $20 million in ~~sales volume of 4%, which decreased gross margin~~manufacturing, maintenance and other costs, driven by ~~$2 million; and~~

•the ~~impact of a $7 million unrealized net mark-to-market gain on natural gas derivatives in the first quarter of 2023 compared to a $4 million gain in the first quarter of 2022.~~cost for purchased ammonia for upgrade at our Billingham complex, partially offset by lower production costs.

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Liquidity and Capital Resources

Our primary uses of cash are generally for operating costs, working capital, capital expenditures, debt service, investments, taxes, share repurchases, and dividends. Our working capital requirements are affected by several factors, including demand for our products, selling prices, raw material costs, freight costs and seasonal factors inherent in the business. We may also utilize our cash to fund acquisitions. In addition, we may from time to time seek to retire or purchase our outstanding debt through cash purchases, in open market or privately negotiated transactions or otherwise. Such repurchases, if any, will depend on prevailing market conditions, our liquidity requirements, contractual restrictions and other factors. The amounts involved may be material.

Generally, our primary source of cash is cash from operations, which includes cash generated by customer advances. We may also from time to time access the capital markets or engage in borrowings under our revolving credit agreement.

As of ~~March 31,~~September 30, 2023, our cash and cash equivalents balance was ~~$2.83~~$3.25 billion, an increase of ~~$502~~$931 million from $2.32 billion at December 31, 2022. At ~~March 31,~~September 30, 2023, we were in compliance with all applicable covenant requirements under our revolving credit agreement and senior notes, and unused borrowing capacity under our revolving credit agreement was $750 million.

Cash Equivalents

Cash equivalents include highly liquid investments that are readily convertible to known amounts of cash with original maturities of three months or less. Under our short-term investment policy, we may invest our cash balances, either directly or through mutual funds, in several types of investment-grade securities, including notes and bonds issued by governmental entities or corporations. Securities issued by governmental entities include those issued directly by the U.S. and Canadian federal governments; those issued by state, local or other governmental entities; and those guaranteed by entities affiliated with governmental entities.

Share Repurchase Programs

On November 3, 2021, our Board of Directors (the Board) authorized the repurchase of up to $1.5 billion of CF Holdings common stock through December 31, 2024 (the 2021 Share Repurchase Program). On November 2, 2022, the Board authorized the repurchase of up to $3 billion of CF Holdings common stock commencing upon completion of the 2021 Share Repurchase Program and effective through December 31, 2025 (the 2022 Share Repurchase Program). Repurchases under our share repurchase programs may be made from time to time in the open market, through privately negotiated transactions, through block transactions or otherwise. The manner, timing and amount of repurchases will be determined by our management based on the evaluation of market conditions, stock price, and other factors. Shares repurchased, including those repurchased under share repurchase programs, are retired as approved by the Board. The 2021 Share Repurchase Program was completed in the second quarter of 2023. The following table summarizes the share repurchases under the 2022 Share Repurchase Program and 2021 Share Repurchase Program.


	2022 Share Repurchase Program			2021 Share Repurchase Program
	Shares	Amounts(1)		Shares	Amounts(1)
	(in millions)

Shares repurchased in 2022:
First quarter	—	$	—	1.3	$	100
Second quarter	—	—		5.3	490
Third quarter	—	—		6.1	532
Fourth quarter	—	—		2.2	223
Total shares repurchased in 2022	—	—		14.9	1,345
Shares repurchased as of December 31, 2022	—	$	—	14.9	$	1,345
Shares repurchased in 2023:
First quarter	—	$	—	1.1	$	75
Second quarter	0.8	50		1.2	80
Third quarter	1.9	150		—	—

Total shares repurchased in 2023	2.7	200		2.3	155
Shares repurchased as of September 30, 2023	2.7	$	200	17.2	$	1,500

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(1)As defined in the share repurchase programs, amounts reflect the price paid for the shares of common stock repurchased, excluding commissions paid to brokers and excise taxes.

In the ~~three months ended March 31,~~first half of 2023, we ~~repurchased approximately 1.1 million shares under~~completed the 2021 Share Repurchase Program with the repurchase of approximately 2.3 million shares for ~~$75~~$155 million. In the nine months ended September 30, 2023, we repurchased approximately 2.7 million ~~of which $21 million was accrued and unpaid as of March 31, 2023. As of March 31, 2023, there was approximately $80 million of authorization remaining~~shares under the ~~2021~~2022 Share Repurchase ~~Program.~~Program for $200 million.

Capital Spending

We make capital expenditures to sustain our asset base, increase our capacity or capabilities, improve plant efficiency, comply with various environmental, health and safety requirements, and invest in our clean energy strategy. Capital expenditures totaled ~~$69~~$311 million in the first ~~three~~nine months of 2023 compared to ~~$63~~$319 million in the first ~~three~~nine months of 2022.

We currently anticipate that capital expenditures for the full year 2023 will be in the range of ~~$500~~$450 to ~~$550~~$500 million, which includes capital expenditures related to green and blue ammonia projects. Planned capital expenditures are generally subject to change due to delays in regulatory approvals or permitting, unanticipated increases in cost, changes in scope and completion time, performance of third parties, delays in the receipt of equipment, adverse weather, defects in materials and workmanship, labor or material shortages, transportation constraints, acceleration or delays in the timing of the work and other unforeseen difficulties.

Agreement to Purchase Ammonia Production Facility

On March 20, 2023, we entered into an asset purchase agreement with DNLA and IPL. Under the terms of the agreement, we will purchase DNLA’s ammonia production complex located in Waggaman, Louisiana for a purchase price of $1.675 billion, subject to adjustment. The facility has a nameplate capacity of 880,000 tons of ammonia annually. The parties will allocate $425 million of the purchase price to a long-term ammonia offtake agreement providing for us to supply up to

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200,000 tons of ammonia per year to IPL’s Dyno Nobel, Inc. subsidiary. We expect to fund the balance of the purchase price, representing the $1.675 billion purchase price, as adjusted, less $425 million, with cash on hand.

United Kingdom Operations

During the third quarter of 2021, the United Kingdom began experiencing an energy crisis that included a substantial increase in the price of natural gas, which impacted our U.K. ~~operations. On September 15, 2021, we announced~~operations and resulted in the halt of operations at both our Ince and Billingham manufacturing ~~facilities in the United Kingdom due to negative profitability driven by the high cost of natural gas.~~facilities. Shortly thereafter, our Billingham facility resumed operations.

In ~~June~~the third quarter of 2022, we approved ~~and announced~~ our ~~proposed~~ plan to restructure our U.K. operations, including the permanent closure of our Ince facility and optimization of the remaining manufacturing operations at the Billingham facility. ~~In August 2022,~~As of June 30, 2023, the ~~final~~decommissioning of our Ince facility and other approved restructuring ~~plan was approved, and decommissioning activities were initiated.~~actions had been completed.

~~Production~~ With the ammonia plant idled since September 2022, production of AN and other nitrogen products ~~continues~~has continued at our Billingham facility using imported ammonia, a portion of which is imported from our other ammonia production sites. In the third quarter of 2023, we approved our plan to permanently close the ammonia plant at our Billingham complex. There remains uncertainty regarding the future cost of ammonia used for upgrading, natural gas and electricity, and selling prices for the products we produce in the United ~~Kingdom and U.K. government policy, which~~Kingdom. These factors, in addition to any remaining disposition activities at our Ince facility, could necessitate, among other things, additional funding to support the cash needs of our U.K. operations and recognition of further losses and could have ~~a material~~an adverse impact on our results of operations and cash flows.

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Debt

Revolving Credit Agreement

~~We have~~On October 26, 2023, we entered into a new senior unsecured revolving credit agreement (the New Revolving Credit Agreement), which replaced our prior senior unsecured revolving credit agreement (the Prior Revolving Credit Agreement) that was scheduled to mature on December 5, 2024. The Prior Revolving Credit Agreement provided for a revolving credit facility of up to $750 million and included a letter of credit sub-limit of $125 million.

The New Revolving Credit Agreement provides for a revolving credit facility of up to $750 million with a maturity of ~~December 5, 2024. The Revolving Credit Agreement~~October 26, 2028 and includes a letter of credit sub-limit of $125 million. Borrowings under the New Revolving Credit Agreement may be used for working capital, capital expenditures, acquisitions, share repurchases and other general corporate purposes. CF Industries is the lead borrower, and CF Holdings is the sole guarantor, under the New Revolving Credit Agreement.

Borrowings under the New Revolving Credit Agreement may be denominated in U.S. dollars, Canadian dollars, euros and British ~~pounds, and~~pounds. Borrowings in U.S. dollars bear interest at a per annum rate equal to, at our option, an applicable ~~eurocurrency rate~~adjusted term Secured Overnight Financing Rate or base rate plus, in either case, a specified margin. We are required to pay an undrawn commitment fee on the undrawn portion of the commitments under the New Revolving Credit Agreement and customary letter of credit fees. The specified margin and the amount of the commitment fee depend on CF Holdings’ credit rating at the time.

As of March 31, 2023, we had unused borrowing capacity under the Revolving Credit Agreement of $750 million and no outstanding letters of credit. There were no borrowings outstanding under the Revolving Credit Agreement as of March 31, 2023 or December 31, 2022, or during the three months ended March 31, 2023.

The New Revolving Credit Agreement contains representations and warranties and affirmative and negative covenants, including a financial ~~covenants.~~ covenant.

As of ~~March 31,~~September 30, 2023, we ~~were in compliance with all covenants~~had unused borrowing capacity under the Prior Revolving Credit Agreement of $750 million and no outstanding letters of credit under the Prior Revolving Credit Agreement. There were no borrowings outstanding under the Prior Revolving Credit Agreement as of September 30, 2023 or December 31, 2022, or during the nine months ended September 30, 2023. See Note 11—Financing Agreements for additional information on the Prior Revolving Credit Agreement.

Letters of Credit Under Bilateral Agreement

~~In addition~~We are party to ~~the letters of credit that may be issued under the Revolving Credit Agreement, as described above, we have also entered into~~ a bilateral agreement ~~with capacity to issue~~providing for the issuance of up to $350 million of letters of credit. As of ~~March 31,~~September 30, 2023, approximately ~~$201~~$200 million of letters of credit were outstanding under this agreement.

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Senior Notes

Long-term debt presented on our consolidated balance sheets as of ~~March 31,~~September 30, 2023 and December 31, 2022 consisted of the following debt securities issued by CF Industries:


		Effective Interest Rate	March 31, 2023				December 31, 2022					Effective Interest Rate	September 30, 2023				December 31, 2022
			Principal		Carrying Amount(1)		Principal		Carrying Amount(1)				Principal		Carrying Amount(1)		Principal		Carrying Amount(1)
			(in millions)										(in millions)
Public Senior Notes:	Public Senior Notes:										Public Senior Notes:

5.150% due March 2034	5.150% due March 2034	5.293%	$	750	$	741	$	750	$	741	5.150% due March 2034	5.293%	$	750	$	741	$	750	$	741
4.950% due June 2043	4.950% due June 2043	5.040%	750		742		750		742		4.950% due June 2043	5.040%	750		742		750		742
5.375% due March 2044	5.375% due March 2044	5.478%	750		740		750		740		5.375% due March 2044	5.478%	750		741		750		740
Senior Secured Notes:	Senior Secured Notes:										Senior Secured Notes:

4.500% due December 2026(2)	4.500% due December 2026(2)	4.783%	750		743		750		742		4.500% due December 2026(2)	4.783%	750		743		750		742
Total long-term debt	Total long-term debt		$	3,000	$	2,966	$	3,000	$	2,965	Total long-term debt		$	3,000	$	2,967	$	3,000	$	2,965

(2)Effective August 23, 2021, these notes are no longer secured, in accordance with the terms of the applicable indenture.

Under the terms of the indentures (including the applicable supplemental indentures) governing our senior notes due 2034, 2043 and 2044 identified in the table above (the Public Senior Notes), each series of Public Senior Notes is guaranteed by CF Holdings.

Under the terms of the indenture governing the 4.500% senior secured notes due 2026 (the 2026 Notes), the 2026 Notes are guaranteed by CF Holdings. ~~Until August 23, 2021, the 2026 Notes were guaranteed by~~

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CF Holdings and certain subsidiaries of CF Industries. The requirement for subsidiary guarantees of the 2026 Notes was eliminated, and all subsidiary guarantees were automatically released, as a result of an investment grade rating event under the terms of the indenture governing the 2026 Notes on August 23, 2021. Prior to the investment grade rating event, subject to certain exceptions, the obligations under the 2026 Notes and related guarantees were secured by a first priority security interest in collateral consisting of substantially all of the assets of CF Industries, CF Holdings and the subsidiary guarantors. As a result of the investment grade rating event, the liens on the collateral securing the obligations under the 2026 Notes and related guarantees were automatically released on August 23, 2021, and the indenture covenant that had limited dispositions of assets constituting collateral no longer applies.INDUSTRIES HOLDINGS, INC.

Forward Sales and Customer Advances

We offer our customers the opportunity to purchase products from us on a forward basis at prices and on delivery dates we propose. Therefore, our reported fertilizer selling prices and margins may differ from market spot prices and margins available at the time of shipment.

Customer advances, which typically represent a portion of the contract’s value, are received shortly after the contract is executed, with any remaining unpaid amount generally being collected by the time control transfers to the customer, thereby reducing or eliminating the accounts receivable related to such sales. Any cash payments received in advance from customers in connection with forward sales contracts are reflected on our consolidated balance sheets as a current liability until control transfers and revenue is recognized. As of ~~March 31,~~September 30, 2023 and December 31, 2022, we had ~~$284~~$282 million and $229 million, respectively, in customer advances on our consolidated balance sheets.

While customer advances are generally a significant source of liquidity, the level of forward sales contracts is affected by many factors, including current market conditions, our customers’ outlook of future market fundamentals and seasonality. During periods of declining prices, customers tend to delay purchasing fertilizer in anticipation that prices in the future will be lower than the current prices. If the level of sales under our forward sales programs were to decrease in the future, our cash received from customer advances would likely decrease and our accounts receivable balances would likely increase.

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Additionally, borrowing under the New Revolving Credit Agreement could become necessary. Due to the volatility inherent in our business and changing customer expectations, we cannot estimate the amount of future forward sales activity.

Under our forward sales programs, a customer may delay delivery of an order due to weather conditions or other factors. These delays generally subject the customer to potential charges for storage or may be grounds for termination of the contract by us. Such a delay in scheduled shipment or termination of a forward sales contract due to a customer’s inability or unwillingness to perform may negatively impact our reported sales.

Derivative Financial Instruments

Defined Benefit Pension Plans

We contributed $7$38 million to our pension plans in the ~~three~~nine months ended ~~March 31,~~September 30, 2023. Over the remainder of 2023, we expect to contribute approximately ~~$36~~$6 million to our pension plans, which would result in our making total contributions of approximately ~~$43~~$44 million to our pension plans for the full year 2023. In addition, in the two-year period from 2024 to 2025, we expect to contribute a total of approximately £30 million (or ~~$37~~$36 million) to our U.K. plans, as agreed with the plans’ trustees.

Distribution to Noncontrolling Interest in CFN

On January 31, 2023, CFN distributed $255 million to CHS for the distribution period ended December 31, 2022. On July 31, 2023, the CFN Board of Managers approved semi-annual distribution payments for the distribution period ended ~~December 31, 2022~~June 30, 2023 in accordance with CFN’s limited liability company ~~agreement. On January~~agreement, and on July 31, 2023, CFN distributed ~~$255~~$204 million to CHS for ~~the~~this distribution ~~period ended December 31, 2022.~~period. The estimate of the partnership distribution earned by CHS, but not yet declared, for the ~~first~~third quarter of 2023 is approximately ~~$110~~$66 million.

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Cash Flows

Net cash provided by operating activities during the first ~~three~~nine months of 2023 was ~~$947 million,~~$2.28 billion, a decrease of ~~$444~~$993 million compared to ~~$1.39~~$3.27 billion in the first ~~three~~nine months of 2022. The decrease in cash flow from operations was due primarily to lower net earnings, partially offset by changes in net working capital. Net earnings for the first ~~three~~nine months of 2023 was ~~$650 million as~~$1.49 billion compared to ~~$1.05~~$2.93 billion for the first ~~three~~nine months of 2022, a decrease of ~~$401 million.~~$1.44 billion. The decrease in net earnings was due primarily to a decrease in gross margin, driven by lower average selling prices, ~~and sales volume.~~partially offset by lower natural gas costs. During the first ~~three~~nine months of 2023, net changes in working capital increased cash flow from operations by ~~$213~~$289 million, while in the first ~~three~~nine months of 2022, net changes in working capital ~~increased~~reduced cash flow from operations by ~~$110~~$621 million. The increase in cash flow from working capital changes was attributable primarily to ~~higher cash collections from~~favorable movements in accounts receivable, inventory and customer advances ~~and lower levels of accounts receivable~~ in the first ~~three~~nine months of 2023 as compared to the first ~~three~~nine months of 2022.

Net cash used in investing activities was ~~$34~~$271 million in the first ~~three~~nine months of 2023 as compared to ~~$62~~$308 million in the first ~~three~~nine months of 2022. ~~The decrease was due primarily~~Capital expenditures totaled $311 million during the first nine months of 2023 compared to ~~an increase~~$319 million in ~~proceeds from~~ the ~~sale~~first nine months of ~~emission credits, as proceeds~~2022. Proceeds from the sale of emission credits was ~~$35~~$39 million in the first ~~three~~nine months of 2023 compared to $9$15 million in the first ~~three months of 2022. Capital expenditures totaled $69 million during the first three months of 2023 compared to $63 million in the first three~~nine months of 2022.

Net cash used in financing activities was ~~$410 million~~$1.07 billion in the first ~~three~~nine months of 2023 compared to ~~$339 million~~$2.37 billion in the first ~~three~~nine months of 2022. The ~~increase~~decrease was due primarily to proceeds from issuances of common stock under employee stock plans of $97 million in the first three months of 2022 that did not recur in the first three months of 2023. In addition, the increase reflects an increase in dividends, as the dividend declared and paid in the first quarter of 2023 was $0.40 per common share compared to $0.30 per common share in the first quarter of 2022. Dividends paid on common stock was $79 million in the first three months of 2023 compared to $64 million in the first three months of 2022. These factors were partially offset by a decrease in share repurchases. In the first ~~three~~nine months of 2023, we paid ~~$54~~$355 million for share repurchases compared to ~~$98 million~~$1.10 billion paid for share repurchases in the first ~~three~~nine months of 2022. In addition, we paid $507 million in connection with the redemption of the 2023 Notes in the first ~~three~~nine months of ~~2023, share repurchases totaled $75 million, of which $21 million was accrued and unpaid as of March 31, 2023.~~2022.

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Critical Accounting Estimates

During the first ~~three~~nine months of 2023, there were no material changes to our critical accounting estimates as described in Item 7 of our Annual Report on Form 10-K for the fiscal year ended December 31, 2022.

Forward-Looking Statements

From time to time, in this Quarterly Report on Form 10-Q as well as in other written reports and oral statements, we make forward-looking statements that are not statements of historical fact and may involve a number of risks and uncertainties. These statements relate to analyses and other information that are based on forecasts of future results and estimates of amounts not yet determinable. These statements may also relate to our prospects, future developments and business strategies. We have used the words “anticipate,” “believe,” “could,” “estimate,” “expect,” “intend,” “may,” “plan,” “predict,” “project,” “will,” or “would” and similar terms and phrases, including references to assumptions, to identify forward-looking statements in this document. These forward-looking statements are made based on currently available competitive, financial and economic data, our current expectations, estimates, forecasts and projections about the industries and markets in which we operate and management’s beliefs and assumptions concerning future events affecting us. These statements are not guarantees of future performance and are subject to risks, uncertainties and factors relating to our operations and business environment, all of which are difficult to predict and many of which are beyond our control. Therefore, our actual results may differ materially from what is expressed in or implied by any forward-looking statements. We want to caution you not to place undue reliance on any forward-looking statements. We do not undertake any responsibility to release publicly any revisions to these forward-looking statements to take into account events or circumstances that occur after the date of this document. Additionally, we do not undertake any responsibility to provide updates regarding the occurrence of any unanticipated events which may cause actual results to differ from those expressed or implied by the forward-looking statements contained in this document.

Important factors that could cause actual results to differ materially from our expectations are disclosed under “Risk Factors” in Item 1A in our Annual Report on Form 10-K for the fiscal year ended December 31, 2022, filed with the SEC on February 23, 2023. Such factors include, among others:

•the risk that regulatory approvals required for the proposed transactions with Incitec Pivot Limited (IPL) are not obtained or that required approvals delay the transactions or cause the parties to abandon the transactions; the risk that other conditions to the closing of the proposed transactions with IPL are not satisfied; risks and uncertainties arising from the length of time necessary to consummate the proposed transactions with IPL and the possibility that the proposed transactions with IPL may be delayed or may not occur; the risk of obstacles to realization of the benefits of the proposed transactions with IPL;

•the risk that the synergies from the proposed transactions with IPL may not be fully realized or may take longer to realize than expected; the risk that the pendency or completion of the proposed transactions with IPL, including integration of the Waggaman ammonia production complex into the Company’s operations, disrupt current operations or harm relationships with customers, employees and suppliers; the risk that integration of the Waggaman ammonia

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production complex with the Company’s current operations will be more costly or difficult than expected or may otherwise be unsuccessful; diversion of management time and attention to issues relating to the proposed transactions with IPL; unanticipated costs or liabilities associated with the IPL transactions;

•the cyclical nature of our business and the impact of global supply and demand on our selling prices;

•the global commodity nature of our nitrogen products, the conditions in the international market for nitrogen products, and the intense global competition from other producers;

•conditions in the United States, Europe and other agricultural areas, including the influence of governmental policies and technological developments on the demand for our fertilizer products;

•the volatility of natural gas prices in North America and the United Kingdom;

•weather conditions and the impact of adverse weather events;

•the seasonality of the fertilizer business;

•the impact of changing market conditions on our forward sales programs;

•difficulties in securing the supply and delivery of raw materials, increases in their costs or delays or interruptions in their delivery;

•reliance on third party providers of transportation services and equipment;

•our reliance on a limited number of key facilities;

•risks associated with cybersecurity;

•acts of terrorism and regulations to combat terrorism;

•risks associated with international operations;

•the significant risks and hazards involved in producing and handling our products against which we may not be fully insured;

•our ability to manage our indebtedness and any additional indebtedness that may be incurred;

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~~CF INDUSTRIES HOLDINGS, INC.~~

•our ability to maintain compliance with covenants under our revolving credit agreement and the agreements governing our indebtedness;

•downgrades of our credit ratings;

•risks associated with changes in tax laws and disagreements with taxing authorities;

•risks involving derivatives and the effectiveness of our risk management and hedging activities;

•potential liabilities and expenditures related to environmental, health and safety laws and regulations and permitting requirements;

•regulatory restrictions and requirements related to greenhouse gas emissions;

•the development and growth of the market for green and blue (low-carbon) ammonia and the risks and uncertainties relating to the development and implementation of our green and blue ammonia projects;

•risks associated with expansions of our business, including unanticipated adverse consequences and the significant resources that could be required; and

•risks associated with the operation or management of the CHS strategic venture, risks and uncertainties relating to the market prices of the fertilizer products that are the subject of our supply agreement with CHS over the life of the supply agreement, and the risk that any challenges related to the CHS strategic venture will harm our other business relationships.

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CF INDUSTRIES HOLDINGS, INC.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.

We are exposed to the impact of changes in commodity prices, interest rates and foreign currency exchange rates.

Commodity Prices

Our ~~net sales,~~gross margin, cash flows and estimates of future cash flows related to nitrogen-based products are sensitive not only to selling prices of our products, but also to changes in ~~selling prices as well as changes in the~~market prices of natural gas and other raw materials ~~unless these costs~~except to the extent the prices we pay for those inputs have been fixed or hedged. A $1.00 per MMBtu change in the price of natural gas would change the cost to produce a ton of ammonia, granular urea, UAN (32%), and AN by approximately $32, $22, $14 and $15, respectively.

Natural gas is the largest and most volatile component of the manufacturing cost for nitrogen-based products. At certain times, we have managed the risk of changes in natural gas prices through the use of derivative financial instruments. The derivative instruments that we may use for this purpose are primarily natural gas fixed price swaps, basis swaps and options. These derivatives settle using primarily a NYMEX futures price index, which represents the basis for fair value at any given time. The contracts represent anticipated natural gas needs for future periods and settlements are scheduled to coincide with anticipated natural gas purchases during those future periods. As of ~~March 31,~~September 30, 2023, we had natural gas derivative contracts covering certain periods through March 2024.

As of ~~March 31,~~September 30, 2023 and December 31, 2022, we had open derivative contracts for ~~18.9~~65.3 million MMBtus and 66.3 million MMBtus, respectively. A $1.00 per MMBtu increase in the forward curve prices of natural gas at ~~March 31,~~September 30, 2023 would result in a favorable change in the fair value of these derivative positions of approximately ~~$17~~$62 million, and a $1.00 per MMBtu decrease in the forward curve prices of natural gas would change their fair value unfavorably by approximately ~~$17~~$63 million.

From time to time, we may purchase nitrogen products on the open market to augment or replace production at our facilities.

Interest Rates

As of ~~March 31,~~September 30, 2023, we had four series of senior notes totaling $3.00 billion of principal outstanding with maturity dates of December 1, 2026, March 15, 2034, June 1, 2043, and March 15, 2044. The senior notes have fixed interest rates. As of ~~March 31,~~September 30, 2023, the carrying value and fair value of our senior notes was approximately $2.97 billion and ~~$2.77~~$2.66 billion, respectively.

Borrowings under the Prior Revolving Credit Agreement bore current market rates of interest, and we were subject to interest rate risk on such borrowings. There were no borrowings outstanding under the Prior Revolving Credit Agreement as of September 30, 2023, as of December 31, 2022, or during the nine months ended September 30, 2023.

Borrowings under the New Revolving Credit Agreement bear current market rates of interest, and we are subject to interest rate risk on any such borrowings. ~~There were no borrowings outstanding under the Revolving Credit Agreement as of March 31, 2023, as of December 31, 2022, or during the three months ended March 31, 2023.~~

Foreign Currency Exchange Rates

We are directly exposed to changes in the value of the Canadian dollar, the British pound and the euro. We generally do not maintain any exchange rate derivatives or hedges related to these currencies.

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ITEM 4. CONTROLS AND PROCEDURES.

(a) Disclosure Controls and Procedures. The Company’s management, with the participation of the Company’s principal executive officer and principal financial officer, has evaluated the effectiveness of the Company’s disclosure controls and procedures (as such term is defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended (the Exchange Act)) as of the end of the period covered by this report. Based on such evaluation, the Company’s principal executive officer and principal financial officer have concluded that, as of the end of such period, the Company’s disclosure controls and procedures are effective in (i) ensuring that information required to be disclosed by the Company in the reports that it files or submits under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms and (ii) ensuring that information required to be disclosed by the Company in the reports that it files or submits under the Exchange Act is accumulated and communicated to the Company’s management, including the Company’s principal executive officer and principal financial officer, as appropriate to allow timely decisions regarding required disclosure.

(b) Changes in Internal Control Over Financial Reporting. ~~Other than changes due to the Company’s implementation of the upgrade of its enterprise resource planning (ERP) system for its North American operations to SAP S/4HANA, there~~There have not been any changes in the Company’s internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) during the quarter ended ~~March 31,~~September 30, 2023 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

PART II—OTHER INFORMATION

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS.

The following table sets forth share repurchases, on a trade date basis, for each of the three months of the quarter ended ~~March 31,~~September 30, 2023.

Issuer Purchases of Equity Securities
Period
Total
number
of shares
(or units)
purchased
Average
price paid
per share
(or unit)(1)
Total number of
shares (or units)
purchased as part of
publicly announced
plans or programs(2)
Maximum number (or
approximate dollar
value) of shares (or
units) that may yet be
purchased under the
plans or programs
(in thousands)(2)
January 1, 2023 - January 31, 2023 108,573 (3) $ 82.27 — $ 3,154,583
February 1, 2023 - February 28, 2023 154,488 (4) 85.89 — 3,154,583
March 1, 2023 - March 31, 2023 1,056,319 71.00 1,056,319 3,079,583
Total 1,319,380

$ 73.67 1,056,319


	Issuer Purchases of Equity Securities
Period	Total number of shares (or units) purchased		Average price paid per share (or unit)(1)		Total number of shares (or units) purchased as part of publicly announced plans or programs(2)	Maximum number (or approximate dollar value) of shares (or units) that may yet be purchased under the plans or programs (in thousands)(2)
July 1, 2023 - July 31, 2023	1,409	(3)	$	72.03	—	$	2,950,052
August 1, 2023 - August 31, 2023	1,910,238		78.52		1,910,238	2,800,052
September 1, 2023 - September 30, 2023	85	(4)	77.07		—	2,800,052
Total	1,911,732		$	78.52	1,910,238

(1)Average price paid per share of CF Industries Holdings, Inc. (CF Holdings) common stock repurchased under the ~~2021~~2022 Share Repurchase Program, as defined below, is the execution price, excluding commissions paid to brokers and excise taxes.

(2)On November 3, 2021, we announced that our Board of Directors (the Board) authorized the repurchase of up to $1.5 billion of CF Holdings common stock from January 1, 2022 through December 31, 2024 (the 2021 Share Repurchase Program). On November 2, 2022, we announced that the Board authorized the repurchase of up to $3 billion of CF Holdings common stock, ~~commencing upon completion of the 2021 Share Repurchase Program and~~which is effective through December 31, ~~2025. These~~2025 (the 2022 Share Repurchase Program). This share repurchase ~~programs are~~program is discussed in Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—Share Repurchase Programs in Part I of this Quarterly Report on Form 10-Q and in Note ~~13—~~15—Stockholders’ Equity, in the notes to ~~the~~ unaudited consolidated financial statements included in Item 1. ~~Financials~~Financial Statements in Part I of this Quarterly Report on Form 10-Q.

(3)Represents shares withheld to pay employee tax obligations upon the lapse of restrictions on restricted stock units.

(4)Represents shares withheld to pay employee tax obligations upon the lapse of restrictions on ~~both restricted stock units and performance~~ restricted stock units.

ITEM 5. OTHER INFORMATION.

During the quarter ended September 30, 2023, there were no Rule 10b5-1 trading arrangements (as defined in Item 408(a) of Regulation S-K) or non-Rule 10b5-1 trading arrangements (as defined in Item 408(c) of Regulation S-K) adopted or terminated by any director or officer (as defined in Rule 16a-1(f) under the Exchange Act) of CF Industries Holdings, Inc.

ITEM 6. EXHIBITS.


A list of exhibits filed with this Quarterly Report on Form 10-Q (or incorporated by reference to exhibits previously filed or furnished) is provided in the Exhibit Index on page 4254 of this report.

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EXHIBIT INDEX


Exhibit No.			Description






























































2 .10.1			~~Asset Purchase~~Revolving Credit Agreement, dated as of ~~March 20,~~October 26, 2023, by and among ~~Dyno Nobel Louisiana Ammonia, LLC~~CF Industries Holdings, Inc., CF Industries, ~~East Point, LLC,~~ Inc., Citibank, N.A., as administrative agent, the issuing banks from time to time party thereto, and ~~solely for~~ the ~~purposes of Article X,~~ ~~Incitec Pivot Limited~~lenders from time to time party thereto ~~and CF Industries Holdings, Inc.~~ ~~(incorporated~~(incorporated by reference to Exhibit ~~2.1~~10.1 to CF Industries Holdings, Inc.’s Current Report on Form 8-K filed with the SEC on ~~March 20,~~October 2 7 , 2023)
10.2			Change in Control Severance Agreement, effective as of October 17, 2023,)* by and between CF Industries Holdings, Inc. and Michael P. McGrane
31.1			Certification of Principal Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.2			Certification of Principal Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
32.1			Certification of Principal Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.2			Certification of Principal Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
101			The following financial information from CF Industries Holdings, Inc.’s Quarterly Report on Form 10-Q for the quarterly period ended ~~March 31,~~September 30, 2023, formatted in Inline XBRL (eXtensible Business Reporting Language): (1) Consolidated Statements of Operations, (2) Consolidated Statements of Comprehensive Income, (3) Consolidated Balance Sheets, (4) Consolidated Statements of Equity, (5) Consolidated Statements of Cash Flows, and (6) Notes to Unaudited Consolidated Financial Statements
104			Cover Page Interactive Data File (included in the Exhibit 101 Inline XBRL Document Set)

* Schedules (or similar attachments) have been omitted pursuant to Item 601(a)(5) of Regulation S-K.

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SIGNATURES

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


	CF INDUSTRIES HOLDINGS, INC.
Date: ~~May~~November 2, 2023	By:	/s/ W. ANTHONY WILL
		W. Anthony Will President and Chief Executive Officer (Principal Executive Officer)
Date: ~~May~~November 2, 2023	By:	/s/ CHRISTOPHER D. BOHN
		Christopher D. Bohn ~~Senior~~Executive Vice President and Chief Financial Officer ~~(Principal~~ (Principal Financial Officer)

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PART I.	Financial Information
	Item 1.	Financial Statements (unaudited)
		Consolidated Statements of Operations	1
		Consolidated Statements of Comprehensive Income	2
		Consolidated Balance Sheets	3
		Consolidated Statements of Equity	4
		Consolidated Statements of Cash Flows	56
		Notes to Unaudited Consolidated Financial Statements	67
	Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	1923
	Item 3.	Quantitative and Qualitative Disclosures About Market Risk	4052
	Item 4.	Controls and Procedures	4153
PART II.	Other Information


	Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	4153
	Item 5.	Other Information	53
	Item 6.	Exhibits	4153