[10-Q] CF Industries Holding, Inc. Quarterly Earnings Report
Filing Impact
Filing Sentiment
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10-Q
CF Industries delivered solid top-line growth for the quarter ended 30 Jun 2025: net sales rose 20% YoY to $1.89 bn on stronger volumes and pricing across Ammonia (+20%) and UAN (+28%). Gross margin expanded 11% to $755 m while operating earnings were broadly flat at $648 m. A higher effective tax rate (22.4% vs 19.5%) and a 33% jump in SG&A trimmed bottom-line growth; net income attributable to common shareholders declined 8% to $386 m. However, the share count fell 11% due to aggressive buybacks, lifting diluted EPS 3% to $2.37.
For the first six months, revenue increased 17% to $3.55 bn and net income to common rose 14% to $698 m, driving YTD EPS to $4.20 (+27%). Operating cash flow improved 25% to $1.15 bn, funding $377 m of capex and $636 m of share repurchases. Cash and equivalents closed at $1.69 bn; leverage remained low with long-term debt steady at $2.97 bn and the $750 m revolver undrawn. Strategically, the Donaldsonville carbon-capture unit (2 Mt CO₂/yr) entered service in July and a new Blue Point joint venture (40% CF stake) was formed to build a $3.7 bn low-carbon ammonia plant targeting 2029 start-up. These projects, together with continued supply-contract amortization ($15 m YTD), position CF to meet emerging clean-energy demand while supporting shareholder returns.
CF Industries ha registrato una solida crescita dei ricavi nel trimestre conclusosi il 30 giugno 2025: le vendite nette sono aumentate del 20% su base annua, raggiungendo 1,89 miliardi di dollari, grazie a volumi e prezzi più elevati per Ammoniaca (+20%) e UAN (+28%). Il margine lordo è cresciuto dell'11%, attestandosi a 755 milioni di dollari, mentre gli utili operativi sono rimasti sostanzialmente stabili a 648 milioni di dollari. Un aumento del tasso fiscale effettivo (22,4% contro 19,5%) e un incremento del 33% delle spese SG&A hanno limitato la crescita dell'utile netto; l'utile netto attribuibile agli azionisti ordinari è diminuito dell'8%, a 386 milioni di dollari. Tuttavia, il numero di azioni in circolazione è sceso dell'11% grazie a un programma aggressivo di riacquisto, facendo salire l'utile per azione diluito del 3%, a 2,37 dollari.
Nei primi sei mesi, i ricavi sono aumentati del 17%, raggiungendo 3,55 miliardi di dollari, mentre l'utile netto attribuibile agli azionisti ordinari è cresciuto del 14%, a 698 milioni di dollari, portando l'utile per azione da inizio anno a 4,20 dollari (+27%). Il flusso di cassa operativo è migliorato del 25%, a 1,15 miliardi di dollari, finanziando 377 milioni di dollari di investimenti e 636 milioni di dollari di riacquisti di azioni. La liquidità e le equivalenze si sono chiuse a 1,69 miliardi di dollari; la leva finanziaria è rimasta bassa con il debito a lungo termine stabile a 2,97 miliardi di dollari e una linea di credito da 750 milioni di dollari non utilizzata. Sul piano strategico, l’impianto di cattura del carbonio di Donaldsonville (2 Mt CO₂/anno) è entrato in funzione a luglio e una nuova joint venture Blue Point (con una partecipazione CF del 40%) è stata costituita per costruire un impianto di ammoniaca a basse emissioni di carbonio da 3,7 miliardi di dollari, con avvio previsto nel 2029. Questi progetti, insieme all’ammortamento continuo dei contratti di fornitura (15 milioni di dollari da inizio anno), posizionano CF per soddisfare la domanda emergente di energia pulita, supportando al contempo i ritorni per gli azionisti.
CF Industries registró un sólido crecimiento de ingresos en el trimestre finalizado el 30 de junio de 2025: las ventas netas aumentaron un 20% interanual hasta 1,89 mil millones de dólares, impulsadas por mayores volúmenes y precios en Amoníaco (+20%) y UAN (+28%). El margen bruto creció un 11% hasta 755 millones de dólares, mientras que las ganancias operativas se mantuvieron prácticamente estables en 648 millones de dólares. Un mayor tipo impositivo efectivo (22,4% frente a 19,5%) y un aumento del 33% en gastos SG&A redujeron el crecimiento del resultado neto; el ingreso neto atribuible a los accionistas comunes disminuyó un 8%, hasta 386 millones de dólares. Sin embargo, el número de acciones en circulación cayó un 11% debido a recompras agresivas, elevando las ganancias por acción diluidas un 3% hasta 2,37 dólares.
En los primeros seis meses, los ingresos aumentaron un 17% hasta 3,55 mil millones de dólares y el ingreso neto atribuible a los accionistas comunes creció un 14% hasta 698 millones de dólares, impulsando las ganancias por acción acumuladas a 4,20 dólares (+27%). El flujo de caja operativo mejoró un 25% hasta 1,15 mil millones de dólares, financiando 377 millones de dólares en gastos de capital y 636 millones de dólares en recompras de acciones. El efectivo y equivalentes cerraron en 1,69 mil millones de dólares; el apalancamiento se mantuvo bajo con deuda a largo plazo estable en 2,97 mil millones de dólares y la línea de crédito revolvente de 750 millones sin usar. Estratégicamente, la unidad de captura de carbono de Donaldsonville (2 Mt CO₂/año) entró en servicio en julio y se formó una nueva empresa conjunta Blue Point (con una participación del 40% de CF) para construir una planta de amoníaco bajo en carbono valorada en 3,7 mil millones de dólares, con inicio previsto para 2029. Estos proyectos, junto con la amortización continua de contratos de suministro (15 millones de dólares en lo que va del año), posicionan a CF para satisfacer la creciente demanda de energía limpia mientras apoyan los retornos para los accionistas.
CF Industries는 2025년 6월 30일로 종료된 분기에 견고한 매출 성장을 기록했습니다. 순매출은 암모니아(+20%)와 UAN(+28%)의 판매량 및 가격 상승에 힘입어 전년 대비 20% 증가한 18억 9천만 달러를 기록했습니다. 총이익은 11% 증가한 7억 5,500만 달러였으며, 영업이익은 6억 4,800만 달러로 거의 변동이 없었습니다. 유효 세율 상승(22.4% 대비 19.5%)과 SG&A 비용 33% 증가로 인해 순이익 성장에 제약이 있었으며, 보통주주 귀속 순이익은 8% 감소한 3억 8,600만 달러를 기록했습니다. 그러나 공격적인 자사주 매입으로 주식 수가 11% 감소해 희석 주당순이익은 3% 상승한 2.37달러가 되었습니다.
상반기 동안 매출은 17% 증가한 35억 5천만 달러, 보통주주 귀속 순이익은 14% 증가한 6억 9,800만 달러를 기록했으며, 연초 대비 주당순이익은 27% 증가한 4.20달러였습니다. 영업현금흐름은 25% 개선된 11억 5천만 달러로, 3억 7,700만 달러의 자본적 지출과 6억 3,600만 달러의 자사주 매입을 지원했습니다. 현금 및 현금성 자산은 16억 9천만 달러로 마감되었으며, 장기 부채는 29억 7천만 달러로 안정적이었고 7억 5천만 달러 규모의 신용 한도는 미사용 상태였습니다. 전략적으로는 도널드슨빌 탄소 포집 설비(연간 200만 톤 CO₂)가 7월에 가동을 시작했으며, 40%의 CF 지분을 가진 새로운 Blue Point 합작법인이 37억 달러 규모의 저탄소 암모니아 공장 건설을 위해 설립되어 2029년 가동을 목표로 하고 있습니다. 이 프로젝트들과 지속적인 공급 계약 상각(연초 이후 1,500만 달러)은 CF가 신흥 청정 에너지 수요를 충족하고 주주 수익을 지원할 수 있는 위치에 있음을 보여줍니다.
CF Industries a affiché une solide croissance du chiffre d'affaires pour le trimestre clos le 30 juin 2025 : les ventes nettes ont augmenté de 20 % en glissement annuel pour atteindre 1,89 milliard de dollars, grâce à des volumes et des prix plus élevés pour l'ammoniac (+20 %) et l'UAN (+28 %). La marge brute s'est accrue de 11 % pour atteindre 755 millions de dollars, tandis que le résultat opérationnel est resté globalement stable à 648 millions de dollars. Un taux d'imposition effectif plus élevé (22,4 % contre 19,5 %) et une hausse de 33 % des frais SG&A ont limité la croissance du résultat net ; le bénéfice net attribuable aux actionnaires ordinaires a diminué de 8 % pour s'établir à 386 millions de dollars. Cependant, le nombre d'actions en circulation a diminué de 11 % grâce à des rachats d'actions agressifs, ce qui a fait augmenter le BPA dilué de 3 % à 2,37 dollars.
Sur les six premiers mois, le chiffre d'affaires a progressé de 17 % pour atteindre 3,55 milliards de dollars et le bénéfice net attribuable aux actionnaires ordinaires a augmenté de 14 % pour atteindre 698 millions de dollars, portant le BPA cumulé à 4,20 dollars (+27 %). Les flux de trésorerie opérationnels se sont améliorés de 25 % pour s'établir à 1,15 milliard de dollars, finançant 377 millions de dollars d'investissements et 636 millions de dollars de rachats d'actions. La trésorerie et équivalents ont clôturé à 1,69 milliard de dollars ; l'endettement est resté faible avec une dette à long terme stable à 2,97 milliards de dollars et la ligne de crédit renouvelable de 750 millions non utilisée. Sur le plan stratégique, l'unité de capture de carbone de Donaldsonville (2 Mt CO₂/an) est entrée en service en juillet et une nouvelle coentreprise Blue Point (participation CF de 40 %) a été créée pour construire une usine d'ammoniac bas carbone de 3,7 milliards de dollars, avec un démarrage prévu en 2029. Ces projets, ainsi que l'amortissement continu des contrats d'approvisionnement (15 millions de dollars depuis le début de l'année), positionnent CF pour répondre à la demande émergente d'énergie propre tout en soutenant les rendements aux actionnaires.
CF Industries verzeichnete im Quartal zum 30. Juni 2025 ein solides Umsatzwachstum: Der Nettoumsatz stieg im Jahresvergleich um 20 % auf 1,89 Mrd. USD, getrieben durch höhere Mengen und Preise bei Ammoniak (+20 %) und UAN (+28 %). Die Bruttomarge wuchs um 11 % auf 755 Mio. USD, während das operative Ergebnis mit 648 Mio. USD weitgehend stabil blieb. Ein höherer effektiver Steuersatz (22,4 % vs. 19,5 %) und ein Anstieg der Vertriebs- und Verwaltungskosten (SG&A) um 33 % bremsten das Wachstum des Nettogewinns; der den Stammaktionären zurechenbare Nettogewinn sank um 8 % auf 386 Mio. USD. Aufgrund aggressiver Aktienrückkäufe sank die Anzahl der ausstehenden Aktien um 11 %, was das verwässerte Ergebnis je Aktie um 3 % auf 2,37 USD anhob.
Für die ersten sechs Monate stiegen die Umsatzerlöse um 17 % auf 3,55 Mrd. USD und der den Stammaktionären zurechenbare Nettogewinn um 14 % auf 698 Mio. USD, was zu einem Ergebnis je Aktie von 4,20 USD (+27 %) führte. Der operative Cashflow verbesserte sich um 25 % auf 1,15 Mrd. USD, finanzierte Investitionen in Höhe von 377 Mio. USD und Aktienrückkäufe von 636 Mio. USD. Die liquiden Mittel schlossen bei 1,69 Mrd. USD; die Verschuldung blieb mit langfristigen Schulden von 2,97 Mrd. USD stabil, und die revolvierende Kreditlinie von 750 Mio. USD wurde nicht in Anspruch genommen. Strategisch ging die Donaldsonville-Kohlenstoffabscheidungseinheit (2 Mt CO₂/Jahr) im Juli in Betrieb, und ein neues Joint Venture Blue Point (40 % CF-Anteil) wurde gegründet, um eine 3,7 Mrd. USD teure Niedrig-Kohlenstoff-Ammoniakanlage zu errichten, die 2029 in Betrieb gehen soll. Diese Projekte zusammen mit der fortlaufenden Amortisation von Lieferverträgen (15 Mio. USD seit Jahresbeginn) positionieren CF, um der aufkommenden Nachfrage nach sauberer Energie gerecht zu werden und gleichzeitig die Aktionärsrenditen zu unterstützen.
Positive
- Net sales up 20% YoY to $1.89 bn; all product lines grew, signalling robust market demand.
- Operating cash flow +25% to $1.15 bn, providing ample self-funding for capex and buybacks.
- Diluted EPS rose 3% to $2.37 despite lower net income, reflecting effective 11% share-count reduction.
- Donaldsonville CCS facility completed, enabling sequestration of up to 2 Mt CO₂ annually and qualifying for 45Q credits.
- Blue Point low-carbon ammonia JV launched with JERA & Mitsui, unlocking future clean-energy growth.
Negative
- Net earnings attributable to common fell 8% YoY due to higher tax expense and SG&A.
- Effective tax rate increased to 22.4% from 19.5% on audit-related reserve build.
- $636 m spent on share repurchases drained cash and reduced paid-in capital by $45 m year-to-date.
- SG&A jumped 33% to $101 m, pressuring operating leverage.
- Customer advances declined to $32 m (from $118 m), potentially signalling softer forward commitments.
Insights
TL;DR: Revenue beat and cash flow strong; EPS aided by buybacks; guidance unchanged—overall neutral.
Q2 top-line outpaced consensus with a 20% jump, driven by pricing gains across nitrogen products. Gross margin held at 40% despite higher gas costs, showing good cost discipline. Yet SG&A inflation and a 290 bp tax headwind compressed net income, leaving operating profit roughly flat. Share repurchases masked this in EPS terms, but cash outflow of $660 m on buybacks plus $377 m capex consumed 90% of OCF. Liquidity is ample, and no revolver usage keeps net debt/EBITDA under 1×. Market conditions remain cyclical; management did not issue new outlook, so shares may trade sideways pending fertilizer price signals.
TL;DR: First CCS unit online and Blue Point JV materially advance decarbonisation strategy.
The 2 Mt CO₂/yr Donaldsonville CCS start-up moves CF from planning to execution, qualifying for Section 45Q credits that should add ~$100 m annual after-tax cash. The Blue Point ATR project, backed by JERA and Mitsui, lowers capital risk and secures long-term offtake into Asian power markets. Together, these initiatives could shift 30%+ of CF’s portfolio to low-carbon ammonia by 2030, enhancing optionality and ESG profile. Execution and cost control will be key, but strategic momentum is clearly positive.
CF Industries ha registrato una solida crescita dei ricavi nel trimestre conclusosi il 30 giugno 2025: le vendite nette sono aumentate del 20% su base annua, raggiungendo 1,89 miliardi di dollari, grazie a volumi e prezzi più elevati per Ammoniaca (+20%) e UAN (+28%). Il margine lordo è cresciuto dell'11%, attestandosi a 755 milioni di dollari, mentre gli utili operativi sono rimasti sostanzialmente stabili a 648 milioni di dollari. Un aumento del tasso fiscale effettivo (22,4% contro 19,5%) e un incremento del 33% delle spese SG&A hanno limitato la crescita dell'utile netto; l'utile netto attribuibile agli azionisti ordinari è diminuito dell'8%, a 386 milioni di dollari. Tuttavia, il numero di azioni in circolazione è sceso dell'11% grazie a un programma aggressivo di riacquisto, facendo salire l'utile per azione diluito del 3%, a 2,37 dollari.
Nei primi sei mesi, i ricavi sono aumentati del 17%, raggiungendo 3,55 miliardi di dollari, mentre l'utile netto attribuibile agli azionisti ordinari è cresciuto del 14%, a 698 milioni di dollari, portando l'utile per azione da inizio anno a 4,20 dollari (+27%). Il flusso di cassa operativo è migliorato del 25%, a 1,15 miliardi di dollari, finanziando 377 milioni di dollari di investimenti e 636 milioni di dollari di riacquisti di azioni. La liquidità e le equivalenze si sono chiuse a 1,69 miliardi di dollari; la leva finanziaria è rimasta bassa con il debito a lungo termine stabile a 2,97 miliardi di dollari e una linea di credito da 750 milioni di dollari non utilizzata. Sul piano strategico, l’impianto di cattura del carbonio di Donaldsonville (2 Mt CO₂/anno) è entrato in funzione a luglio e una nuova joint venture Blue Point (con una partecipazione CF del 40%) è stata costituita per costruire un impianto di ammoniaca a basse emissioni di carbonio da 3,7 miliardi di dollari, con avvio previsto nel 2029. Questi progetti, insieme all’ammortamento continuo dei contratti di fornitura (15 milioni di dollari da inizio anno), posizionano CF per soddisfare la domanda emergente di energia pulita, supportando al contempo i ritorni per gli azionisti.
CF Industries registró un sólido crecimiento de ingresos en el trimestre finalizado el 30 de junio de 2025: las ventas netas aumentaron un 20% interanual hasta 1,89 mil millones de dólares, impulsadas por mayores volúmenes y precios en Amoníaco (+20%) y UAN (+28%). El margen bruto creció un 11% hasta 755 millones de dólares, mientras que las ganancias operativas se mantuvieron prácticamente estables en 648 millones de dólares. Un mayor tipo impositivo efectivo (22,4% frente a 19,5%) y un aumento del 33% en gastos SG&A redujeron el crecimiento del resultado neto; el ingreso neto atribuible a los accionistas comunes disminuyó un 8%, hasta 386 millones de dólares. Sin embargo, el número de acciones en circulación cayó un 11% debido a recompras agresivas, elevando las ganancias por acción diluidas un 3% hasta 2,37 dólares.
En los primeros seis meses, los ingresos aumentaron un 17% hasta 3,55 mil millones de dólares y el ingreso neto atribuible a los accionistas comunes creció un 14% hasta 698 millones de dólares, impulsando las ganancias por acción acumuladas a 4,20 dólares (+27%). El flujo de caja operativo mejoró un 25% hasta 1,15 mil millones de dólares, financiando 377 millones de dólares en gastos de capital y 636 millones de dólares en recompras de acciones. El efectivo y equivalentes cerraron en 1,69 mil millones de dólares; el apalancamiento se mantuvo bajo con deuda a largo plazo estable en 2,97 mil millones de dólares y la línea de crédito revolvente de 750 millones sin usar. Estratégicamente, la unidad de captura de carbono de Donaldsonville (2 Mt CO₂/año) entró en servicio en julio y se formó una nueva empresa conjunta Blue Point (con una participación del 40% de CF) para construir una planta de amoníaco bajo en carbono valorada en 3,7 mil millones de dólares, con inicio previsto para 2029. Estos proyectos, junto con la amortización continua de contratos de suministro (15 millones de dólares en lo que va del año), posicionan a CF para satisfacer la creciente demanda de energía limpia mientras apoyan los retornos para los accionistas.
CF Industries는 2025년 6월 30일로 종료된 분기에 견고한 매출 성장을 기록했습니다. 순매출은 암모니아(+20%)와 UAN(+28%)의 판매량 및 가격 상승에 힘입어 전년 대비 20% 증가한 18억 9천만 달러를 기록했습니다. 총이익은 11% 증가한 7억 5,500만 달러였으며, 영업이익은 6억 4,800만 달러로 거의 변동이 없었습니다. 유효 세율 상승(22.4% 대비 19.5%)과 SG&A 비용 33% 증가로 인해 순이익 성장에 제약이 있었으며, 보통주주 귀속 순이익은 8% 감소한 3억 8,600만 달러를 기록했습니다. 그러나 공격적인 자사주 매입으로 주식 수가 11% 감소해 희석 주당순이익은 3% 상승한 2.37달러가 되었습니다.
상반기 동안 매출은 17% 증가한 35억 5천만 달러, 보통주주 귀속 순이익은 14% 증가한 6억 9,800만 달러를 기록했으며, 연초 대비 주당순이익은 27% 증가한 4.20달러였습니다. 영업현금흐름은 25% 개선된 11억 5천만 달러로, 3억 7,700만 달러의 자본적 지출과 6억 3,600만 달러의 자사주 매입을 지원했습니다. 현금 및 현금성 자산은 16억 9천만 달러로 마감되었으며, 장기 부채는 29억 7천만 달러로 안정적이었고 7억 5천만 달러 규모의 신용 한도는 미사용 상태였습니다. 전략적으로는 도널드슨빌 탄소 포집 설비(연간 200만 톤 CO₂)가 7월에 가동을 시작했으며, 40%의 CF 지분을 가진 새로운 Blue Point 합작법인이 37억 달러 규모의 저탄소 암모니아 공장 건설을 위해 설립되어 2029년 가동을 목표로 하고 있습니다. 이 프로젝트들과 지속적인 공급 계약 상각(연초 이후 1,500만 달러)은 CF가 신흥 청정 에너지 수요를 충족하고 주주 수익을 지원할 수 있는 위치에 있음을 보여줍니다.
CF Industries a affiché une solide croissance du chiffre d'affaires pour le trimestre clos le 30 juin 2025 : les ventes nettes ont augmenté de 20 % en glissement annuel pour atteindre 1,89 milliard de dollars, grâce à des volumes et des prix plus élevés pour l'ammoniac (+20 %) et l'UAN (+28 %). La marge brute s'est accrue de 11 % pour atteindre 755 millions de dollars, tandis que le résultat opérationnel est resté globalement stable à 648 millions de dollars. Un taux d'imposition effectif plus élevé (22,4 % contre 19,5 %) et une hausse de 33 % des frais SG&A ont limité la croissance du résultat net ; le bénéfice net attribuable aux actionnaires ordinaires a diminué de 8 % pour s'établir à 386 millions de dollars. Cependant, le nombre d'actions en circulation a diminué de 11 % grâce à des rachats d'actions agressifs, ce qui a fait augmenter le BPA dilué de 3 % à 2,37 dollars.
Sur les six premiers mois, le chiffre d'affaires a progressé de 17 % pour atteindre 3,55 milliards de dollars et le bénéfice net attribuable aux actionnaires ordinaires a augmenté de 14 % pour atteindre 698 millions de dollars, portant le BPA cumulé à 4,20 dollars (+27 %). Les flux de trésorerie opérationnels se sont améliorés de 25 % pour s'établir à 1,15 milliard de dollars, finançant 377 millions de dollars d'investissements et 636 millions de dollars de rachats d'actions. La trésorerie et équivalents ont clôturé à 1,69 milliard de dollars ; l'endettement est resté faible avec une dette à long terme stable à 2,97 milliards de dollars et la ligne de crédit renouvelable de 750 millions non utilisée. Sur le plan stratégique, l'unité de capture de carbone de Donaldsonville (2 Mt CO₂/an) est entrée en service en juillet et une nouvelle coentreprise Blue Point (participation CF de 40 %) a été créée pour construire une usine d'ammoniac bas carbone de 3,7 milliards de dollars, avec un démarrage prévu en 2029. Ces projets, ainsi que l'amortissement continu des contrats d'approvisionnement (15 millions de dollars depuis le début de l'année), positionnent CF pour répondre à la demande émergente d'énergie propre tout en soutenant les rendements aux actionnaires.
CF Industries verzeichnete im Quartal zum 30. Juni 2025 ein solides Umsatzwachstum: Der Nettoumsatz stieg im Jahresvergleich um 20 % auf 1,89 Mrd. USD, getrieben durch höhere Mengen und Preise bei Ammoniak (+20 %) und UAN (+28 %). Die Bruttomarge wuchs um 11 % auf 755 Mio. USD, während das operative Ergebnis mit 648 Mio. USD weitgehend stabil blieb. Ein höherer effektiver Steuersatz (22,4 % vs. 19,5 %) und ein Anstieg der Vertriebs- und Verwaltungskosten (SG&A) um 33 % bremsten das Wachstum des Nettogewinns; der den Stammaktionären zurechenbare Nettogewinn sank um 8 % auf 386 Mio. USD. Aufgrund aggressiver Aktienrückkäufe sank die Anzahl der ausstehenden Aktien um 11 %, was das verwässerte Ergebnis je Aktie um 3 % auf 2,37 USD anhob.
Für die ersten sechs Monate stiegen die Umsatzerlöse um 17 % auf 3,55 Mrd. USD und der den Stammaktionären zurechenbare Nettogewinn um 14 % auf 698 Mio. USD, was zu einem Ergebnis je Aktie von 4,20 USD (+27 %) führte. Der operative Cashflow verbesserte sich um 25 % auf 1,15 Mrd. USD, finanzierte Investitionen in Höhe von 377 Mio. USD und Aktienrückkäufe von 636 Mio. USD. Die liquiden Mittel schlossen bei 1,69 Mrd. USD; die Verschuldung blieb mit langfristigen Schulden von 2,97 Mrd. USD stabil, und die revolvierende Kreditlinie von 750 Mio. USD wurde nicht in Anspruch genommen. Strategisch ging die Donaldsonville-Kohlenstoffabscheidungseinheit (2 Mt CO₂/Jahr) im Juli in Betrieb, und ein neues Joint Venture Blue Point (40 % CF-Anteil) wurde gegründet, um eine 3,7 Mrd. USD teure Niedrig-Kohlenstoff-Ammoniakanlage zu errichten, die 2029 in Betrieb gehen soll. Diese Projekte zusammen mit der fortlaufenden Amortisation von Lieferverträgen (15 Mio. USD seit Jahresbeginn) positionieren CF, um der aufkommenden Nachfrage nach sauberer Energie gerecht zu werden und gleichzeitig die Aktionärsrenditen zu unterstützen.
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, DC 20549
| FORM | |||||
| (Mark One) | |||||||||||
| QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 | |||||||||||
For the quarterly period ended June 30, 2025
| 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
(Exact name of registrant as specified in its charter)
| (State or other jurisdiction of incorporation or organization) | (I.R.S. Employer Identification No.) | ||||||||||||||||||||||
| (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 | ||||||||||||
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.
| ☒ | 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 ☒
Table of Contents
CF INDUSTRIES HOLDINGS, INC.
TABLE OF CONTENTS
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 | 6 | ||||||||||
Notes to Unaudited Consolidated Financial Statements | 7 | ||||||||||
Item 2. | Management’s Discussion and Analysis of Financial Condition and Results of Operations | 22 | |||||||||
Item 3. | Quantitative and Qualitative Disclosures About Market Risk | 48 | |||||||||
Item 4. | Controls and Procedures | 48 | |||||||||
PART II. | Other Information | ||||||||||
Item 2. | Unregistered Sales of Equity Securities and Use of Proceeds | 49 | |||||||||
Item 5. | Other Information | 49 | |||||||||
Item 6. | Exhibits | 49 | |||||||||
Table of Contents
CF INDUSTRIES HOLDINGS, INC.
PART I—FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS.
CONSOLIDATED STATEMENTS OF OPERATIONS
(Unaudited)
| Three months ended June 30, | Six months ended June 30, | ||||||||||||||||||||||
| 2025 | 2024 | 2025 | 2024 | ||||||||||||||||||||
| (in millions, except per share amounts) | |||||||||||||||||||||||
| Net sales | $ | $ | $ | $ | |||||||||||||||||||
| Cost of sales | |||||||||||||||||||||||
| Gross margin | |||||||||||||||||||||||
| Selling, general and administrative expenses | |||||||||||||||||||||||
| U.K. operations restructuring | |||||||||||||||||||||||
| Integration costs | |||||||||||||||||||||||
| Other operating—net | ( | ( | |||||||||||||||||||||
| Total other operating costs and expenses | |||||||||||||||||||||||
| Equity in earnings (losses) of operating affiliate | ( | ( | |||||||||||||||||||||
| Operating earnings | |||||||||||||||||||||||
| Interest expense | |||||||||||||||||||||||
| Interest income | ( | ( | ( | ( | |||||||||||||||||||
| Other non-operating—net | ( | ( | ( | ||||||||||||||||||||
| Earnings before income taxes | |||||||||||||||||||||||
| Income tax provision | |||||||||||||||||||||||
| Net earnings | |||||||||||||||||||||||
| Less: Net earnings attributable to noncontrolling interests | |||||||||||||||||||||||
| Net earnings attributable to common stockholders | $ | $ | $ | $ | |||||||||||||||||||
| Net earnings per share attributable to common stockholders: | |||||||||||||||||||||||
| Basic | $ | $ | $ | $ | |||||||||||||||||||
| Diluted | $ | $ | $ | $ | |||||||||||||||||||
| Weighted-average common shares outstanding: | |||||||||||||||||||||||
| Basic | |||||||||||||||||||||||
| Diluted | |||||||||||||||||||||||
| Dividends declared per common share | $ | $ | $ | $ | |||||||||||||||||||
See accompanying Notes to Unaudited Consolidated Financial Statements.
1
Table of Contents
CF INDUSTRIES HOLDINGS, INC.
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)
| Three months ended June 30, | Six months ended June 30, | ||||||||||||||||||||||
| 2025 | 2024 | 2025 | 2024 | ||||||||||||||||||||
| (in millions) | |||||||||||||||||||||||
| Net earnings | $ | $ | $ | $ | |||||||||||||||||||
| Other comprehensive income (loss): | |||||||||||||||||||||||
| Foreign currency translation adjustment—net of taxes | ( | ( | |||||||||||||||||||||
| Defined benefit plans—net of taxes | ( | ( | ( | ( | |||||||||||||||||||
| ( | ( | ||||||||||||||||||||||
| Comprehensive income | |||||||||||||||||||||||
| Less: Comprehensive income attributable to noncontrolling interests | |||||||||||||||||||||||
| Comprehensive income attributable to common stockholders | $ | $ | $ | $ | |||||||||||||||||||
See accompanying Notes to Unaudited Consolidated Financial Statements.
2
Table of Contents
CF INDUSTRIES HOLDINGS, INC.
CONSOLIDATED BALANCE SHEETS
| (Unaudited) | |||||||||||
| June 30, 2025 | December 31, 2024 | ||||||||||
| (in millions, except share and per share amounts) | |||||||||||
| Assets | |||||||||||
| Current assets: | |||||||||||
Cash and cash equivalents (amount related to variable interest entity (VIE)—2025: $ | $ | $ | |||||||||
| Accounts receivable—net | |||||||||||
| Inventories | |||||||||||
| Prepaid income taxes | |||||||||||
| Other current assets | |||||||||||
| Total current assets | |||||||||||
Property, plant and equipment—net (amount related to VIE—2025: $ | |||||||||||
| Investment in affiliate | |||||||||||
| Goodwill | |||||||||||
| Intangible assets—net | |||||||||||
| Operating lease right-of-use assets | |||||||||||
| Other assets | |||||||||||
| Total assets | $ | $ | |||||||||
| Liabilities and Equity | |||||||||||
| Current liabilities: | |||||||||||
Accounts payable and accrued expenses (amount related to VIE—2025: $ | $ | $ | |||||||||
| Income taxes payable | |||||||||||
| Customer advances | |||||||||||
| Current operating lease liabilities | |||||||||||
| Other current liabilities | |||||||||||
| Total current liabilities | |||||||||||
| Long-term debt | |||||||||||
| Deferred income taxes | |||||||||||
| Operating lease liabilities | |||||||||||
| Supply contract liability | |||||||||||
Other liabilities (amount related to VIE—2025: $ | |||||||||||
| Equity: | |||||||||||
| Stockholders’ equity: | |||||||||||
Preferred stock—$ | |||||||||||
Common stock—$ | |||||||||||
| Paid-in capital | |||||||||||
| Retained earnings | |||||||||||
Treasury stock—at cost, 2025— | ( | ||||||||||
| Accumulated other comprehensive loss | ( | ( | |||||||||
| Total stockholders’ equity | |||||||||||
| Noncontrolling interests | |||||||||||
| Total equity | |||||||||||
| Total liabilities and equity | $ | $ | |||||||||
See accompanying Notes to Unaudited Consolidated Financial Statements.
3
Table of Contents
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 Interests | Total Equity | ||||||||||||||||||||||||||||||||||||||||
| (in millions, except per share amounts) | |||||||||||||||||||||||||||||||||||||||||||||||
| Balance as of March 31, 2025 | $ | $ | ( | $ | $ | $ | ( | $ | $ | $ | |||||||||||||||||||||||||||||||||||||
| Net earnings | — | — | — | ||||||||||||||||||||||||||||||||||||||||||||
| Other comprehensive income | — | — | — | — | — | ||||||||||||||||||||||||||||||||||||||||||
| Purchases of treasury stock | — | ( | — | — | — | ( | — | ( | |||||||||||||||||||||||||||||||||||||||
| Retirement of treasury stock | — | ( | ( | — | — | ||||||||||||||||||||||||||||||||||||||||||
Issuance of $ | — | ( | — | — | — | ||||||||||||||||||||||||||||||||||||||||||
| Stock-based compensation expense | — | — | — | — | — | ||||||||||||||||||||||||||||||||||||||||||
Dividends and dividend equivalents ($ | — | — | — | ( | — | ( | — | ( | |||||||||||||||||||||||||||||||||||||||
| Contributions from noncontrolling interests | — | — | — | — | — | — | |||||||||||||||||||||||||||||||||||||||||
| Balance as of June 30, 2025 | $ | $ | $ | $ | $ | ( | $ | $ | $ | ||||||||||||||||||||||||||||||||||||||
| Balance as of December 31, 2024 | $ | $ | ( | $ | $ | $ | ( | $ | $ | $ | |||||||||||||||||||||||||||||||||||||
| Net earnings | — | — | — | — | |||||||||||||||||||||||||||||||||||||||||||
| Other comprehensive income | — | — | — | — | — | ||||||||||||||||||||||||||||||||||||||||||
| Purchases of treasury stock | — | ( | — | — | ( | — | ( | ||||||||||||||||||||||||||||||||||||||||
| Retirement of treasury stock | — | ( | ( | — | — | ||||||||||||||||||||||||||||||||||||||||||
| Acquisition of treasury stock under employee stock plans | — | ( | — | — | — | ( | — | ( | |||||||||||||||||||||||||||||||||||||||
Issuance of $ | — | ( | — | — | — | ||||||||||||||||||||||||||||||||||||||||||
| Stock-based compensation expense | — | — | — | — | — | ||||||||||||||||||||||||||||||||||||||||||
Dividends and dividend equivalents ($ | — | — | — | ( | — | ( | — | ( | |||||||||||||||||||||||||||||||||||||||
| Contributions from noncontrolling interests | — | — | — | — | — | — | |||||||||||||||||||||||||||||||||||||||||
| Distribution declared to noncontrolling interest | — | — | — | — | — | — | ( | ( | |||||||||||||||||||||||||||||||||||||||
| Balance as of June 30, 2025 | $ | $ | $ | $ | $ | ( | $ | $ | $ | ||||||||||||||||||||||||||||||||||||||
(Continued)
4
Table of Contents
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 March 31, 2024 | $ | $ | ( | $ | $ | $ | ( | $ | $ | $ | |||||||||||||||||||||||||||||||||||||
| Net earnings | — | — | — | — | |||||||||||||||||||||||||||||||||||||||||||
| Other comprehensive loss | — | — | — | — | ( | ( | — | ( | |||||||||||||||||||||||||||||||||||||||
| Purchases of treasury stock | — | ( | — | — | — | ( | — | ( | |||||||||||||||||||||||||||||||||||||||
| Retirement of treasury stock | — | ( | ( | — | — | — | — | ||||||||||||||||||||||||||||||||||||||||
Issuance of $ | — | ( | — | — | — | — | — | ||||||||||||||||||||||||||||||||||||||||
| Stock-based compensation expense | — | — | — | — | — | ||||||||||||||||||||||||||||||||||||||||||
Dividends and dividend equivalents ($ | — | — | — | ( | — | ( | — | ( | |||||||||||||||||||||||||||||||||||||||
| Balance as of June 30, 2024 | $ | $ | ( | $ | $ | $ | ( | $ | $ | $ | |||||||||||||||||||||||||||||||||||||
| Balance as of December 31, 2023 | $ | $ | $ | $ | $ | ( | $ | $ | $ | ||||||||||||||||||||||||||||||||||||||
| Net earnings | — | — | — | — | |||||||||||||||||||||||||||||||||||||||||||
| Other comprehensive loss | — | — | — | — | ( | ( | — | ( | |||||||||||||||||||||||||||||||||||||||
| Purchases of treasury stock | — | ( | — | — | — | ( | — | ( | |||||||||||||||||||||||||||||||||||||||
| Retirement of treasury stock | — | ( | ( | — | — | ||||||||||||||||||||||||||||||||||||||||||
| Acquisition of treasury stock under employee stock plans | — | ( | — | — | — | ( | — | ( | |||||||||||||||||||||||||||||||||||||||
Issuance of $ | — | ( | — | — | — | ||||||||||||||||||||||||||||||||||||||||||
| Stock-based compensation expense | — | — | — | — | — | ||||||||||||||||||||||||||||||||||||||||||
Dividends and dividend equivalents ($ | — | — | — | ( | — | ( | — | ( | |||||||||||||||||||||||||||||||||||||||
| Distribution declared to noncontrolling interest | — | — | — | — | — | — | ( | ( | |||||||||||||||||||||||||||||||||||||||
| Balance as of June 30, 2024 | $ | $ | ( | $ | $ | $ | ( | $ | $ | $ | |||||||||||||||||||||||||||||||||||||
See accompanying Notes to Unaudited Consolidated Financial Statements.
5
Table of Contents
CF INDUSTRIES HOLDINGS, INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
| Six months ended June 30, | |||||||||||||||||||||||
| 2025 | 2024 | ||||||||||||||||||||||
| (in millions) | |||||||||||||||||||||||
| Operating Activities: | |||||||||||||||||||||||
| Net earnings | $ | $ | |||||||||||||||||||||
| Adjustments to reconcile net earnings to net cash provided by operating activities: | |||||||||||||||||||||||
| Depreciation and amortization | |||||||||||||||||||||||
| Deferred income taxes | ( | ( | |||||||||||||||||||||
| Stock-based compensation expense | |||||||||||||||||||||||
| Unrealized net loss (gain) on natural gas derivatives | ( | ||||||||||||||||||||||
| Gain on sale of emission credits | ( | ||||||||||||||||||||||
| Loss on disposal of property, plant and equipment | |||||||||||||||||||||||
| Loss on sale of Ince facility | |||||||||||||||||||||||
| Undistributed (earnings) losses of affiliate—net of taxes | ( | ||||||||||||||||||||||
| Changes in assets and liabilities: | |||||||||||||||||||||||
| Accounts receivable—net | ( | ( | |||||||||||||||||||||
| Inventories | ( | ( | |||||||||||||||||||||
| Accrued and prepaid income taxes | |||||||||||||||||||||||
| Accounts payable and accrued expenses | ( | ||||||||||||||||||||||
| Customer advances | ( | ( | |||||||||||||||||||||
| Other—net | ( | ||||||||||||||||||||||
| Net cash provided by operating activities | |||||||||||||||||||||||
| Investing Activities: | |||||||||||||||||||||||
| Additions to property, plant and equipment | ( | ( | |||||||||||||||||||||
| Purchase of Waggaman ammonia production facility | |||||||||||||||||||||||
| Proceeds from sale of property, plant and equipment | |||||||||||||||||||||||
| Proceeds from sale of Ince facility | |||||||||||||||||||||||
| Proceeds from sale of investments held in nonqualified employee benefit trust | |||||||||||||||||||||||
| Purchase of emission credits | ( | ( | |||||||||||||||||||||
| Proceeds from sale of emission credits | |||||||||||||||||||||||
| Net cash used in investing activities | ( | ( | |||||||||||||||||||||
| Financing Activities: | |||||||||||||||||||||||
| Dividends paid on common stock | ( | ( | |||||||||||||||||||||
| Contributions from noncontrolling interests | |||||||||||||||||||||||
| Distributions to noncontrolling interest | ( | ( | |||||||||||||||||||||
| Purchases of treasury stock | ( | ( | |||||||||||||||||||||
| Proceeds from issuances of common stock under employee stock plans | |||||||||||||||||||||||
| Cash paid for shares withheld for taxes | ( | ( | |||||||||||||||||||||
| Net cash used in financing activities | ( | ( | |||||||||||||||||||||
| Effect of exchange rate changes on cash and cash equivalents | ( | ||||||||||||||||||||||
| Increase (decrease) in cash and cash equivalents | ( | ||||||||||||||||||||||
| Cash and cash equivalents at beginning of period | |||||||||||||||||||||||
| Cash and cash equivalents at end of period | $ | $ | |||||||||||||||||||||
See accompanying Notes to Unaudited Consolidated Financial Statements.
6
Table of Contents
CF INDUSTRIES HOLDINGS, INC.
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 low-carbon hydrogen and nitrogen products for energy, fertilizer, emissions abatement, and other industrial activities. Our 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, retailers, independent fertilizer distributors, traders, wholesalers and industrial users. Our core product is anhydrous ammonia (ammonia), which contains 82% nitrogen and 18% hydrogen. Products derived from ammonia that are most often used as nitrogen fertilizers include granular urea, urea ammonium nitrate solution (UAN) and ammonium nitrate (AN). AN is also used extensively by the commercial explosives industry as a component of explosives. Products derived from ammonia that are sold primarily to industrial customers include diesel exhaust fluid (DEF), urea liquor, nitric acid and aqua ammonia.
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 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.
The accompanying unaudited interim consolidated financial statements of CF Holdings include the accounts of CF Industries, all of CF Holdings’ majority-owned subsidiaries and a variable interest entity of which we are the primary beneficiary. All significant intercompany transactions and balances have been eliminated. See Note 12—Variable Interest Entity and Note 13—Noncontrolling Interests for additional information.
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, 2024, 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.
2. New Accounting Standards
In December 2023, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) No. 2023-09, Income Taxes (Topic 740): Improvements to Income Tax Disclosures. This ASU adds new guidance that further enhances income tax disclosures, primarily through standardization and disaggregation of rate reconciliation categories and income taxes paid by jurisdiction. The amendments are effective for fiscal years beginning after December 15, 2024. We are continuing to evaluate the impact that our adoption of this ASU will have on our income tax disclosures beginning with the consolidated financial statements that will be included in our Annual Report on Form 10-K for the fiscal year ending December 31, 2025.
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In November 2024, the FASB issued ASU No. 2024-03, Income Statement—Reporting Comprehensive Income—Expense Disaggregation Disclosures (Subtopic 220-40): Disaggregation of Income Statement Expenses. This ASU requires disclosure, within the footnotes to the financial statements, of specified costs and expenses disaggregated from the amounts presented on consolidated statements of operations. The guidance in this ASU is effective for fiscal years beginning after December 15, 2026, and interim periods within fiscal years beginning after December 15, 2027, with early adoption permitted. We are currently evaluating the impact that our adoption of this ASU will have on the disclosures in our consolidated financial statements.
3. Revenue Recognition
We track our revenue by product and by geography. See Note 15—Segment Disclosures for our revenue by reportable segment, which are Ammonia, Granular Urea, UAN, AN and Other. The following table summarizes our revenue by product and by geography (based on the destination of our shipment) for the three and six months ended June 30, 2025 and 2024:
| Ammonia | Granular Urea | UAN | AN | Other | Total | ||||||||||||||||||||||||||||||
| (in millions) | |||||||||||||||||||||||||||||||||||
| Three months ended June 30, 2025 | |||||||||||||||||||||||||||||||||||
| North America | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||
| Europe and other | |||||||||||||||||||||||||||||||||||
| Total revenue | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||
| Three months ended June 30, 2024 | |||||||||||||||||||||||||||||||||||
| North America | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||
| Europe and other | |||||||||||||||||||||||||||||||||||
| Total revenue | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||
| Six months ended June 30, 2025 | |||||||||||||||||||||||||||||||||||
| North America | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||
| Europe and other | |||||||||||||||||||||||||||||||||||
| Total revenue | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||
| Six months ended June 30, 2024 | |||||||||||||||||||||||||||||||||||
| North America | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||
| Europe and other | |||||||||||||||||||||||||||||||||||
| Total revenue | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||
As of June 30, 2025 and December 31, 2024, we had $32 million and $118 million, respectively, in customer advances on our consolidated balance sheets. During the six months ended June 30, 2025 and 2024, substantially all of the customer advances at the beginning of each respective period 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 June 30, 2025 and December 31, 2024 were not material.
We have certain customer contracts with performance obligations where 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 may vary based upon the terms and conditions of the applicable contract. As of June 30, 2025, 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 $2.3 billion. We expect to recognize approximately 12 % of these performance obligations as revenue in the remainder of 2025, approximately 38 17 1.2 billion as of June 30, 2025. Other than the performance obligations described above, any performance obligations with our customers that were unfulfilled or partially filled at December 31, 2024 will be satisfied in 2025.
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Supply Contract Liability
In connection with our December 1, 2023 acquisition of the Waggaman ammonia production facility, we entered into a long-term ammonia offtake agreement providing for us to supply up to 200,000 tons of ammonia per year to Dyno Nobel, Inc. (the Supply Contract). The terms of the Supply Contract were determined to be unfavorable compared to market as of the acquisition date. As a result, we recorded an intangible liability with an acquisition date fair value of $757 million, which is being amortized to net sales over the estimated life of the Supply Contract of 25 years. For both the three months ended June 30, 2025 and 2024, we amortized $8 15 709 million and $724 million, respectively, in Supply Contract liability on our consolidated balance sheets. Estimated amortization of the Supply Contract liability for the remainder of 2025 is approximately $15 million and for each of the fiscal years 2026 to 2030 is approximately $30
4. Net Earnings Per Share
Net earnings per share were computed as follows:
| Three months ended June 30, | Six months ended June 30, | ||||||||||||||||||||||
| 2025 | 2024 | 2025 | 2024 | ||||||||||||||||||||
| (in millions, except per share amounts) | |||||||||||||||||||||||
| Net earnings attributable to common stockholders | $ | $ | $ | $ | |||||||||||||||||||
| Basic earnings per common share: | |||||||||||||||||||||||
| Weighted-average common shares outstanding | |||||||||||||||||||||||
| Net earnings attributable to common stockholders | $ | $ | $ | $ | |||||||||||||||||||
| Diluted earnings per common share: | |||||||||||||||||||||||
| Weighted-average common shares outstanding | |||||||||||||||||||||||
| Dilutive common shares—stock-based awards | |||||||||||||||||||||||
| Diluted weighted-average common shares outstanding | |||||||||||||||||||||||
| Net earnings attributable to common stockholders | $ | $ | $ | $ | |||||||||||||||||||
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
5. Inventories
Inventories consist of the following:
| June 30, 2025 | December 31, 2024 | ||||||||||
| (in millions) | |||||||||||
| Finished goods | $ | $ | |||||||||
| Raw materials, spare parts and supplies | |||||||||||
| Total inventories | $ | $ | |||||||||
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6. Property, Plant and Equipment—Net
Property, plant and equipment—net consists of the following:
| June 30, 2025 | December 31, 2024 | ||||||||||
| (in millions) | |||||||||||
| Land | $ | $ | |||||||||
| Machinery and equipment | |||||||||||
| Buildings and improvements | |||||||||||
| Construction in progress | |||||||||||
Property, plant and equipment(1) | |||||||||||
| Less: Accumulated depreciation and amortization | |||||||||||
| Property, plant and equipment—net | $ | $ | |||||||||
_______________________________________________________________________________
Depreciation and amortization related to property, plant and equipment was $230 million and $450 million for the three and six months ended June 30, 2025, respectively, and $220 million and $472 million for the three and six months ended June 30, 2024, 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 plant turnarounds are capitalized in property, plant and equipment when incurred.
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. 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 plant turnarounds. Internal employee costs and overhead amounts are not considered plant turnaround costs and are not capitalized.
The following is a summary of capitalized plant turnaround costs:
| Six months ended June 30, | |||||||||||
| 2025 | 2024 | ||||||||||
| (in millions) | |||||||||||
| Net capitalized plant turnaround costs as of January 1 | $ | $ | |||||||||
| Additions | |||||||||||
| Depreciation | ( | ( | |||||||||
| Effect of exchange rate changes and other | ( | ||||||||||
Net capitalized plant turnaround costs as of June 30 | $ | $ | |||||||||
United Kingdom Operations
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. For property, plant and equipment within the Ince, U.K. asset group, an asset group planned for abandonment, we first considered use of a market or income-based valuation method. However, given that a secondary market did not exist and the assets had been idled with a planned abandonment and therefore would not generate future cash flows from operations, we estimated the fair value of the asset group by determining the replacement cost of the underlying assets and then adjusting each of the asset categories to an estimated salvage value utilizing industry recognized price publications. In the third quarter of 2022, the final restructuring plan was approved, and the facility was subsequently decommissioned.
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In the first quarter of 2025, the Ince facility was sold, including certain liabilities assumed by the buyer, and we recognized a loss of $23 million on the sale. The loss is reflected in U.K. operations restructuring in our consolidated statement of operations for the six months ended June 30, 2025.
7. Equity Method Investment
We have a 50 % ownership interest in Point Lisas Nitrogen Limited (PLNL), which operates an ammonia production facility in 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. As of June 30, 2025, the total carrying value of our equity method investment in PLNL was $35 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 $21 million and $55 million for the three and six months ended June 30, 2025, respectively, and $16 million and $46 million for the three and six months ended June 30, 2024, respectively.
8. Fair Value Measurements
Our cash and cash equivalents and other investments consist of the following:
| June 30, 2025 | |||||||||||||||||||||||
| Cost Basis | Unrealized Gains | Unrealized Losses | Fair Value | ||||||||||||||||||||
| (in millions) | |||||||||||||||||||||||
| Cash | $ | $ | — | $ | — | $ | |||||||||||||||||
| Cash equivalents: | |||||||||||||||||||||||
| U.S. and Canadian government obligations | |||||||||||||||||||||||
| Other debt securities | |||||||||||||||||||||||
| Total cash and cash equivalents | $ | $ | $ | $ | |||||||||||||||||||
| Nonqualified employee benefit trusts | |||||||||||||||||||||||
| December 31, 2024 | |||||||||||||||||||||||
| Cost Basis | Unrealized Gains | Unrealized Losses | Fair Value | ||||||||||||||||||||
| (in millions) | |||||||||||||||||||||||
| Cash | $ | $ | — | $ | — | $ | |||||||||||||||||
| Cash equivalents: | |||||||||||||||||||||||
| U.S. and Canadian government obligations | |||||||||||||||||||||||
| Other debt securities | |||||||||||||||||||||||
| Total cash and cash equivalents | $ | $ | $ | $ | |||||||||||||||||||
| Nonqualified employee benefit trusts | |||||||||||||||||||||||
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 and also in bank deposits. 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.
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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 June 30, 2025 and December 31, 2024 that are recognized at fair value on a recurring basis, and indicate the fair value hierarchy utilized to determine such fair value:
| June 30, 2025 | |||||||||||||||||||||||
| 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 | $ | $ | $ | $ | |||||||||||||||||||
| Nonqualified employee benefit trusts | |||||||||||||||||||||||
| Derivative assets | |||||||||||||||||||||||
| Derivative liabilities | ( | ( | |||||||||||||||||||||
| December 31, 2024 | |||||||||||||||||||||||
| 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 | $ | $ | $ | $ | |||||||||||||||||||
| Nonqualified employee benefit trusts | |||||||||||||||||||||||
| Derivative assets | |||||||||||||||||||||||
| Derivative liabilities | ( | ( | |||||||||||||||||||||
Cash Equivalents
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 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.
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Financial Instruments
The carrying amount and estimated fair value of our financial instruments are as follows:
| June 30, 2025 | December 31, 2024 | ||||||||||||||||||||||
| Carrying Amount | Fair Value | Carrying Amount | Fair Value | ||||||||||||||||||||
| (in millions) | |||||||||||||||||||||||
| Long-term debt | $ | $ | $ | $ | |||||||||||||||||||
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
9. Income Taxes
For the three months ended June 30, 2025, we recorded an income tax provision of $143 million on pre-tax income of $635 million, or an effective tax rate of 22.4 %, compared to an income tax provision of $123 million on pre-tax income of $629 million, or an effective tax rate of 19.5 %, for the three months ended June 30, 2024.
For the six months ended June 30, 2025, we recorded an income tax provision of $229 million on pre-tax income of $1.07 billion, or an effective tax rate of 21.3 %, compared to an income tax provision of $185 million on pre-tax income of $929 million, or an effective tax rate of 19.9 %, for the six months ended June 30, 2024.
Our income tax provision for the three and six months ended June 30, 2025 includes $21 3.4 percentage points and 2.0 percentage points, respectively.
Our effective tax rate is impacted by earnings attributable to the noncontrolling interests as our consolidated income tax provision does not include a tax provision on the earnings attributable to the noncontrolling interests. Our effective tax rate for the three months ended June 30, 2025 of 22.4 %, which is based on pre-tax income of $635 million, including $106 million of earnings attributable to the noncontrolling interests, would be 4.5 percentage points higher if based on pre-tax income exclusive of the $106 million of earnings attributable to the noncontrolling interests. Our effective tax rate for the three months ended June 30, 2024 of 19.5 %, which is based on pre-tax income of $629 million, including $86 million of earnings attributable to the noncontrolling interest, would be 3.1 percentage points higher if based on pre-tax income exclusive of the $86 million of earnings attributable to the noncontrolling interest.
Our effective tax rate for the six months ended June 30, 2025 of 21.3 %, which is based on pre-tax income of $1.07 billion, including $145 million of earnings attributable to the noncontrolling interests, would be 3.4 percentage points higher if based on pre-tax income exclusive of the $145 million of earnings attributable to the noncontrolling interests. Our effective tax rate for the six months ended June 30, 2024 of 19.9 %, which is based on pre-tax income of $929 million, including $130 million of earnings attributable to the noncontrolling interest, would be 3.2 percentage points higher if based on pre-tax income exclusive of the $130 million of earnings attributable to the noncontrolling interest.
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10. Financing Agreements
Revolving Credit Agreement
We have a senior unsecured revolving credit agreement (the Revolving Credit Agreement), which 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. Borrowings under the 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 Revolving Credit Agreement.
Borrowings under the Revolving Credit Agreement can be denominated in U.S. dollars, Canadian dollars, euros and British pounds. Borrowings in U.S. dollars bear interest at a per annum rate equal to, at our option, an applicable 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 Revolving Credit Agreement and customary letter of credit fees. The specified margin and the amount of the commitment fee depended on CF Holdings’ credit rating at the time.
As of June 30, 2025, we had unused borrowing capacity under the Revolving Credit Agreement of $750 million and no outstanding letters of credit under the Revolving Credit Agreement. In addition, there were no
The Revolving Credit Agreement contains representations and warranties and affirmative and negative covenants, including a financial covenant. As of June 30, 2025, we were in compliance with all covenants under the Revolving Credit Agreement.
Letters of Credit Under Bilateral Agreement
We are party to a bilateral agreement providing for the issuance of up to $425 million of letters of credit. As of June 30, 2025, approximately $342 million of letters of credit were outstanding under this agreement.
Senior Notes
Long-term debt presented on our consolidated balance sheets as of June 30, 2025 and December 31, 2024 consisted of the following debt securities issued by CF Industries:
| Effective Interest Rate | June 30, 2025 | December 31, 2024 | |||||||||||||||||||||||||||
| Principal Outstanding | Carrying Amount(1) | Principal Outstanding | Carrying Amount(1) | ||||||||||||||||||||||||||
| (in millions) | |||||||||||||||||||||||||||||
| Public Senior Notes: | |||||||||||||||||||||||||||||
| $ | $ | $ | $ | ||||||||||||||||||||||||||
| Senior Secured Notes: | |||||||||||||||||||||||||||||
| Total long-term debt | $ | $ | $ | $ | |||||||||||||||||||||||||
_______________________________________________________________________________
(1)Carrying amount is net of unamortized debt discount and deferred debt issuance costs. Total unamortized debt discount was $5 million and $6 million as of June 30, 2025 and December 31, 2024, respectively, and total deferred debt issuance costs were $22 million and $23 million as of June 30, 2025 and December 31, 2024, respectively.
(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 (the Public Senior Notes) and the 4.500 % senior secured notes due December 2026 (the 2026 Notes), each series of notes is guaranteed by CF Holdings.
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11. Interest Expense
Details of interest expense are as follows:
| Three months ended June 30, | Six months ended June 30, | ||||||||||||||||||||||
| 2025 | 2024 | 2025 | 2024 | ||||||||||||||||||||
| (in millions) | |||||||||||||||||||||||
Interest on borrowings(1) | $ | $ | $ | $ | |||||||||||||||||||
Fees on financing agreements(1) | |||||||||||||||||||||||
| Interest capitalized | ( | ( | ( | ( | |||||||||||||||||||
| Total interest expense | $ | $ | $ | $ | |||||||||||||||||||
_______________________________________________________________________________
(1)See Note 10—Financing Agreements for additional information.
12. Variable Interest Entity
On April 8, 2025, we announced that we formed a joint venture, Blue Point Number One, LLC, with JERA Co., Inc. (JERA), Japan’s largest energy company, and Mitsui & Co., Ltd. (Mitsui), a leading global investment and trading company, for the construction, production and offtake of low-carbon ammonia (the Blue Point joint venture). We hold 40 % ownership, JERA holds 35 % ownership, and Mitsui holds 25 % ownership in the Blue Point joint venture. Under the terms of the Blue Point joint venture’s limited liability company agreement, JERA has a conditional option to reduce its ownership percentage that expires on December 31, 2025. If the specified condition is met, JERA can reduce its ownership below 35 % but not lower than 20 %. We would have the right and obligation to increase our ownership by the same amount that JERA reduces its ownership.
At our Blue Point complex in Ascension Parish, Louisiana, the Blue Point joint venture is expected to construct an autothermal reforming (ATR) ammonia production facility with a carbon dioxide (CO2) dehydration and compression unit to prepare captured CO2 for transportation and sequestration. Engineering, equipment procurement and pre-construction activities at our Blue Point complex began in the second quarter of 2025. Construction of the ammonia production facility is expected to begin in 2026, with low-carbon ammonia production expected to begin in 2029. We will be responsible for the development, operation and maintenance of the ammonia production facility under contracts with the Blue Point joint venture. We, JERA and Mitsui are required to purchase low-carbon ammonia produced by the Blue Point joint venture in accordance with our respective ownership percentages.
Pursuant to periodic capital calls, the Blue Point joint venture members will fund the cost of the facility’s engineering, procurement and construction according to their respective ownership percentages. During the second quarter of 2025, we, JERA and Mitsui made initial capital contributions of $157 million, $137 million and $98 million, respectively, to the Blue Point joint venture. We funded $114 million of our contribution with cash and $43 million through a non-cash contribution of a license to use certain intellectual property.
In addition, we will build scalable infrastructure at our Blue Point complex to supply the ammonia production facility with services, including product storage and vessel loading.
We determined that the Blue Point joint venture is a variable interest entity (VIE) of which we are the primary beneficiary. We have a significant variable interest in the Blue Point joint venture through our 40 % equity interest. We are considered the primary beneficiary of the VIE as we have both the power to direct the day-to-day operations of the low-carbon ammonia production facility, which are the activities that most significantly impact the economic performance of the VIE, and the obligation to absorb losses or the right to receive benefits from the VIE that could potentially be significant to the VIE, due to our 40 % equity interest. As a result, we consolidate this VIE in our consolidated financial statements, with the combined 60 % equity interest owned by JERA and Mitsui recorded as noncontrolling interest.
The table below summarizes the assets and liabilities of the Blue Point joint venture included in our consolidated balance sheet as of June 30, 2025:
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| June 30, 2025 | ||||||||||||||||||||
| (in millions) | ||||||||||||||||||||
| Assets | ||||||||||||||||||||
| Cash and cash equivalents | $ | |||||||||||||||||||
| Property, plant and equipment, net | ||||||||||||||||||||
| Total assets | $ | |||||||||||||||||||
| Liabilities | ||||||||||||||||||||
| Accounts payable and accrued expenses | $ | |||||||||||||||||||
| Other liabilities | ||||||||||||||||||||
| Total liabilities | $ | |||||||||||||||||||
As of June 30, 2025, all assets of the Blue Point joint venture can only be used to settle the obligations of the Blue Point joint venture. In addition, as of June 30, 2025, all liabilities of the Blue Point joint venture are payable to creditors who do not have recourse to the general credit of CF Holdings.
CF Holdings has provided guarantees for certain financial commitments of the Blue Point joint venture to several third-party vendors; however, as of June 30, 2025, no liabilities had been incurred by the Blue Point joint venture to these third-party vendors.
13. Noncontrolling Interests
We have a strategic venture with CHS Inc. (CHS) under which CHS owns an equity interest in CF Industries Nitrogen, LLC (CFN), a subsidiary of CF Holdings. CHS’ equity interest 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. We also have a 40 % ownership interest in the Blue Point joint venture. JERA and Mitsui own the remaining membership interests. See Note 12—Variable Interest Entity for additional information on the Blue Point joint venture.
For financial reporting purposes, the assets, liabilities and earnings of CFN and the Blue Point joint venture are consolidated into our financial statements. CHS’ interest in CFN and each of JERA’s and Mitsui’s interests in the Blue Point joint venture are recorded in noncontrolling interests in our consolidated financial statements.
A reconciliation of the beginning and ending balances of noncontrolling interests and distributions payable to the noncontrolling interests in our consolidated balance sheets is provided below.
| 2025 | 2024 | ||||||||||||||||||||||||||||||||||
| CFN | Blue Point | Total | CFN | ||||||||||||||||||||||||||||||||
| (in millions) | |||||||||||||||||||||||||||||||||||
| Noncontrolling interests: | |||||||||||||||||||||||||||||||||||
| Balance as of January 1 | $ | $ | $ | $ | |||||||||||||||||||||||||||||||
| Issuance of noncontrolling interests in Blue Point Number One, LLC | |||||||||||||||||||||||||||||||||||
| Earnings attributable to noncontrolling interests | |||||||||||||||||||||||||||||||||||
| Declaration of distributions payable | ( | ( | ( | ||||||||||||||||||||||||||||||||
| Balance as of June 30 | $ | $ | $ | $ | |||||||||||||||||||||||||||||||
| Distributions payable to noncontrolling interest: | |||||||||||||||||||||||||||||||||||
| Balance as of January 1 | $ | $ | $ | $ | |||||||||||||||||||||||||||||||
| Declaration of distributions payable | |||||||||||||||||||||||||||||||||||
| Distributions to noncontrolling interest | ( | ( | ( | ||||||||||||||||||||||||||||||||
| Balance as of June 30 | $ | $ | $ | $ | |||||||||||||||||||||||||||||||
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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.
On July 31, 2025, the CFN Board of Managers approved semi-annual distribution payments for the distribution period ended June 30, 2025 in accordance with CFN’s limited liability company agreement, and CFN distributed $175 million to CHS for this distribution period.
14. Stockholders’ Equity
Common Stock
Our Board of Directors (the Board) has authorized certain programs to repurchase shares of our common stock. These programs have generally permitted repurchases to be made from time to time in the open market, through privately-negotiated transactions, through block transactions, through accelerated share repurchase programs 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.
On November 2, 2022, the Board authorized the repurchase of up to $3 billion of CF Holdings common stock, which is effective through December 31, 2025 (the 2022 Share Repurchase Program). On May 6, 2025, the Board authorized the repurchase of up to $2 billion of CF Holdings common stock commencing upon the completion of the 2022 Share Repurchase Program and effective through December 31, 2029.
The following table summarizes the share repurchases under the 2022 Share Repurchase Program.
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| Shares | Amounts(1) | |||||||||||||||||||||||||
| (in millions) | ||||||||||||||||||||||||||
| Shares repurchased in 2023 | $ | |||||||||||||||||||||||||
| Shares repurchased in 2024: | ||||||||||||||||||||||||||
| First quarter | ||||||||||||||||||||||||||
| Second quarter | ||||||||||||||||||||||||||
| Third quarter | ||||||||||||||||||||||||||
| Fourth quarter | ||||||||||||||||||||||||||
| Total shares repurchased in 2024 | ||||||||||||||||||||||||||
| Shares repurchased in 2025: | ||||||||||||||||||||||||||
| First quarter | ||||||||||||||||||||||||||
| Second quarter | ||||||||||||||||||||||||||
| Total shares repurchased in 2025 | ||||||||||||||||||||||||||
Shares repurchased as of June 30, 2025 | $ | |||||||||||||||||||||||||
(1)As defined in the 2022 Share Repurchase Program, amounts reflect the price paid for the shares of common stock repurchased, excluding commissions paid to brokers and excise taxes.
In the six months ended June 30, 2025, we repurchased approximately 8.2 million shares under the 2022 Share Repurchase Program for $636 million. In the six months ended June 30, 2024, we repurchased approximately 8.3 million shares under the 2022 Share Repurchase Program for $652 million, of which $14 million was accrued and unpaid as of June 30, 2024.
In the second quarter of 2025, we retired approximately 8.3 million shares of repurchased stock, and we held no shares of treasury stock as of June 30, 2025.
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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, 2024 | $ | ( | $ | $ | ( | $ | ( | ||||||||||||||||||||||
| Loss arising during the period | ( | ( | |||||||||||||||||||||||||||
| Effect of exchange rate changes and deferred taxes | ( | ||||||||||||||||||||||||||||
| Balance as of June 30, 2025 | $ | ( | $ | $ | ( | $ | ( | ||||||||||||||||||||||
| Balance as of December 31, 2023 | $ | ( | $ | $ | ( | $ | ( | ||||||||||||||||||||||
| Loss arising during the period | ( | ( | |||||||||||||||||||||||||||
| Effect of exchange rate changes and deferred taxes | ( | ( | |||||||||||||||||||||||||||
| Balance as of June 30, 2024 | $ | ( | $ | $ | ( | $ | ( | ||||||||||||||||||||||
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15. Segment Disclosures
Our reportable segments consist of Ammonia, Granular Urea, UAN, AN and Other. These segments are differentiated by products. Our chief operating decision maker (CODM) is our President and Chief Executive Officer, who uses gross margin to evaluate segment performance and allocate resources. The CODM meets periodically with other members of senior management to analyze segment performance, including comparing actual results to projected results, with consideration to the costs incurred to produce and deliver the product. In addition, our CODM uses gross margin by reportable segment to make key operating decisions, such as the determination of capital expenditures and the allocation of operating budgets, to help guide strategic decisions to align with company-wide goals. 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 the CODM. The ammonia and other products that are upgraded into Granular Urea, UAN, AN and Other products are transferred at cost into the results of those products.
| Three months ended June 30, | Six months ended June 30, | ||||||||||||||||||||||||||||
| 2025 | 2024 | 2025 | 2024 | ||||||||||||||||||||||||||
| (in millions) | |||||||||||||||||||||||||||||
| Ammonia | |||||||||||||||||||||||||||||
| Net sales | $ | $ | $ | $ | |||||||||||||||||||||||||
Cost of sales: | |||||||||||||||||||||||||||||
Natural gas, including the impact of realized derivatives(1) | |||||||||||||||||||||||||||||
| Unrealized net mark-to-market loss (gain) on natural gas derivatives | ( | ||||||||||||||||||||||||||||
Depreciation and amortization(2) | |||||||||||||||||||||||||||||
Distribution and storage(3) | |||||||||||||||||||||||||||||
Freight(4) | |||||||||||||||||||||||||||||
Other segment items(5) | |||||||||||||||||||||||||||||
Total cost of sales | |||||||||||||||||||||||||||||
| Gross margin | $ | $ | $ | $ | |||||||||||||||||||||||||
Granular Urea | |||||||||||||||||||||||||||||
| Net sales | $ | $ | $ | $ | |||||||||||||||||||||||||
Cost of sales: | |||||||||||||||||||||||||||||
Natural gas, including the impact of realized derivatives(1) | |||||||||||||||||||||||||||||
| Unrealized net mark-to-market gain on natural gas derivatives | ( | ||||||||||||||||||||||||||||
Depreciation and amortization(2) | |||||||||||||||||||||||||||||
Distribution and storage(3) | |||||||||||||||||||||||||||||
Freight(4) | |||||||||||||||||||||||||||||
Other segment items(5) | |||||||||||||||||||||||||||||
Total cost of sales | |||||||||||||||||||||||||||||
| Gross margin | $ | $ | $ | $ | |||||||||||||||||||||||||
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| Three months ended June 30, | Six months ended June 30, | ||||||||||||||||||||||||||||
| 2025 | 2024 | 2025 | 2024 | ||||||||||||||||||||||||||
| (in millions) | |||||||||||||||||||||||||||||
| UAN | |||||||||||||||||||||||||||||
| Net sales | $ | $ | $ | $ | |||||||||||||||||||||||||
Cost of sales: | |||||||||||||||||||||||||||||
Natural gas, including the impact of realized derivatives(1) | |||||||||||||||||||||||||||||
| Unrealized net mark-to-market loss (gain) on natural gas derivatives | ( | ||||||||||||||||||||||||||||
Depreciation and amortization(2) | |||||||||||||||||||||||||||||
Distribution and storage(3) | |||||||||||||||||||||||||||||
Freight(4) | |||||||||||||||||||||||||||||
Other segment items(5) | |||||||||||||||||||||||||||||
Total cost of sales | |||||||||||||||||||||||||||||
| Gross margin | $ | $ | $ | $ | |||||||||||||||||||||||||
| AN | |||||||||||||||||||||||||||||
| Net sales | $ | $ | $ | $ | |||||||||||||||||||||||||
Cost of sales: | |||||||||||||||||||||||||||||
Natural gas, including the impact of realized derivatives(1) | |||||||||||||||||||||||||||||
| Unrealized net mark-to-market gain on natural gas derivatives | ( | ||||||||||||||||||||||||||||
Depreciation and amortization(2) | |||||||||||||||||||||||||||||
Freight(4) | |||||||||||||||||||||||||||||
Other segment items(5) | |||||||||||||||||||||||||||||
Total cost of sales | |||||||||||||||||||||||||||||
| Gross margin | $ | $ | $ | $ | |||||||||||||||||||||||||
Other(6) | |||||||||||||||||||||||||||||
| Net sales | $ | $ | $ | $ | |||||||||||||||||||||||||
Cost of sales: | |||||||||||||||||||||||||||||
Natural gas, including the impact of realized derivatives(1) | |||||||||||||||||||||||||||||
| Unrealized net mark-to-market gain on natural gas derivatives | ( | ( | |||||||||||||||||||||||||||
Depreciation and amortization(2) | |||||||||||||||||||||||||||||
Distribution and storage(3) | |||||||||||||||||||||||||||||
Freight(4) | |||||||||||||||||||||||||||||
Other segment items(5) | |||||||||||||||||||||||||||||
Total cost of sales | |||||||||||||||||||||||||||||
| Gross margin | $ | $ | $ | $ | |||||||||||||||||||||||||
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| Three months ended June 30, | Six months ended June 30, | ||||||||||||||||||||||||||||
| 2025 | 2024 | 2025 | 2024 | ||||||||||||||||||||||||||
| (in millions) | |||||||||||||||||||||||||||||
| Consolidated | |||||||||||||||||||||||||||||
| Net sales | $ | $ | $ | $ | |||||||||||||||||||||||||
Cost of sales: | |||||||||||||||||||||||||||||
Natural gas, including the impact of realized derivatives(1) | |||||||||||||||||||||||||||||
| Unrealized net mark-to-market (gain) loss on natural gas derivatives | ( | ( | |||||||||||||||||||||||||||
Depreciation and amortization(2) | |||||||||||||||||||||||||||||
Distribution and storage(3) | |||||||||||||||||||||||||||||
Freight(4) | |||||||||||||||||||||||||||||
Other segment items(5) | |||||||||||||||||||||||||||||
Total cost of sales | |||||||||||||||||||||||||||||
| Gross margin | $ | $ | $ | $ | |||||||||||||||||||||||||
| Total other operating costs and expenses | |||||||||||||||||||||||||||||
| Equity in earnings (losses) of operating affiliate | ( | ( | |||||||||||||||||||||||||||
| Operating earnings | $ | $ | $ | $ | |||||||||||||||||||||||||
_______________________________________________________________________________
(1)Natural gas costs include the impact of realized gains and losses on natural gas derivatives settled during the period.
(2)For the three months ended June 30, 2025 and 2024, depreciation and amortization does not include $8 million and $9 million, respectively, of depreciation and amortization allocated to Corporate, which includes amortization of definite-lived intangible assets. For the six months ended June 30, 2025 and 2024, depreciation and amortization does not include $16 million and $19 million, respectively, of depreciation and amortization allocated to Corporate, which includes amortization of definite-lived intangible assets. For both the three months ended June 30, 2025 and 2024, depreciation and amortization does not include $8 15
(3)Distribution and storage costs consist of the cost of freight required to transport finished products from our manufacturing facilities to our distribution facilities and the costs to operate our network of distribution facilities in North America.
(4)Freight costs consist of the costs incurred by us to deliver products from one of our plants or distribution facilities to the customer. Freight costs are generally charged to the customer and included in net sales. In situations when control of the product transfers upon loading and the customer requests that we arrange delivery of the product, the amount of freight included in net sales is considered freight revenue.
(5)Other segment items is primarily comprised of payroll, services, materials and supplies, and utilities at our manufacturing facilities.
(6)Other consists of all other products not included in our Ammonia, Granular Urea, UAN or AN segments. All other products primarily include DEF, urea liquor, nitric acid and aqua ammonia.
Our assets, with the exception of goodwill, are not monitored by or reported to our CODM by segment; therefore, we do not present total assets by segment. The following table shows the carrying amount of goodwill by reportable segment as of June 30, 2025 and December 31, 2024:
| Ammonia | Granular Urea | UAN | AN | Other | Total | ||||||||||||||||||||||||||||||
| (in millions) | |||||||||||||||||||||||||||||||||||
| Goodwill as of June 30, 2025 | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||
| Goodwill as of December 31, 2024 | |||||||||||||||||||||||||||||||||||
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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, 2024, filed with the Securities and Exchange Commission (SEC) on February 20, 2025, 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. 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
•Market Conditions and Current Developments
•Financial Executive Summary
•Items Affecting Comparability of Results
•Consolidated Results of Operations
•Operating Results by Business Segment
•Liquidity and Capital Resources
•Critical Accounting Estimates
•Recent Accounting Pronouncements
•Forward-Looking Statements
Overview of CF Holdings
Our Company
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 low-carbon hydrogen and nitrogen products for energy, fertilizer, emissions abatement, and other industrial activities. Our 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, retailers, independent fertilizer distributors, traders, wholesalers and industrial users. Our core product is anhydrous ammonia (ammonia), which contains 82% nitrogen and 18% hydrogen. Products derived from ammonia that are most often used as nitrogen fertilizers include granular urea, urea ammonium nitrate solution (UAN) and ammonium nitrate (AN). AN is also used extensively by the commercial explosives industry as a component of explosives. Products derived from ammonia that are sold primarily to industrial customers include diesel exhaust fluid (DEF), urea liquor, nitric acid and aqua ammonia.
Our principal assets as of June 30, 2025 include:
•six U.S. manufacturing facilities located in: Donaldsonville, Louisiana (the largest ammonia production complex in the world); Sergeant Bluff, Iowa (our Port Neal complex); Yazoo City, Mississippi; Claremore, Oklahoma (our Verdigris complex); Woodward, Oklahoma; and Waggaman, Louisiana. The Waggaman facility is wholly owned by us, and the other five U.S. manufacturing 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 13—Noncontrolling Interests for additional information on our strategic venture with CHS);
•two Canadian manufacturing facilities located in: Medicine Hat, Alberta (the largest ammonia production complex in Canada); and Courtright, Ontario;
•a United Kingdom manufacturing facility located in Billingham;
•an extensive system of terminals and associated transportation equipment located primarily in the Midwestern United States;
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•a 50% interest in Point Lisas Nitrogen Limited (PLNL), an ammonia production joint venture located in Trinidad and Tobago (Trinidad) that we account for under the equity method; and
•a 40% interest in Blue Point Number One, LLC, a joint venture formed on April 8, 2025, that is a variable interest entity (VIE) of which we are the primary beneficiary. As a result, we consolidate this entity in our consolidated financial statements, with the combined 60% equity interest owned by our joint venture partners recorded as noncontrolling interest. See “Our Strategy—Blue Point joint venture,” below, for additional information.
Our Strategy
At our core, CF Industries is a producer of ammonia. We use the Haber-Bosch process to fix atmospheric nitrogen with hydrogen from natural gas to produce anhydrous ammonia, whose chemical composition is NH3. We sell the ammonia itself or upgrade it to products such as granular urea, UAN and DEF. A majority of the ammonia and ammonia-derived products we manufacture are used as fertilizer, as the nitrogen content provides energy essential for crop growth. Other important uses of our products include emissions control.
Our strategy is to leverage our unique capabilities to accelerate the world’s transition to clean energy. We believe this strategy builds upon our leadership in ammonia production to capture emerging opportunities to produce ammonia with a lower carbon intensity (“low-carbon ammonia”) than that of ammonia produced through traditional processes. These opportunities include traditional applications in agriculture to help reduce the carbon footprint of food production and the life cycle carbon intensity of ethanol production, enabling production of sustainable aviation fuel, among other purposes. These opportunities also include new growth opportunities from energy-intensive industries, such as power generation and marine shipping, as ammonia represents an efficient mechanism to both ship and store hydrogen, as well as a clean energy fuel source in its own right as ammonia does not contain or emit carbon when combusted. Our strategy also strengthens our existing business.
We execute our strategy across four dimensions:
•decarbonizing our existing network to accelerate the availability of low-carbon ammonia and upgraded nitrogen products for traditional agricultural and industrial applications;
•building new low-carbon ammonia capacity to supply emerging opportunities from power generation and marine shipping, among others;
•forging partnerships to accelerate our timeline, reducing risks and bridging gaps in areas where we do not have expertise; and
•collaborating to build understanding of ammonia’s clean energy capability, safety track record and regulatory environment.
Decarbonizing our existing network
At our Donaldsonville and Yazoo City complexes, our decarbonization projects are leveraging carbon capture and sequestration (CCS) to enable us to convert a portion of our existing ammonia production to low-carbon ammonia production. CCS requires the construction of carbon dioxide (CO2) dehydration and compression units to enable process CO2 captured from the ammonia production process to be transported and sequestered, which prevents approximately 60% of the CO2 generated by ammonia production from being emitted to the atmosphere. For each facility we have contracted with ExxonMobil to transport and permanently store the captured CO2.
In July 2025, construction, commissioning and start-up of the dehydration and compression unit at our Donaldsonville complex was completed for a total cost of approximately $200 million. This new facility enables the transportation and permanent geological sequestration of up to 2 million metric tons of CO2 annually that would otherwise have been emitted into the atmosphere. ExxonMobil, our CCS partner for this project, is transporting and permanently storing the CO2. The project qualifies for tax credits under Section 45Q of the Internal Revenue Code, which provides a tax credit per metric ton of CO2 captured and disposed of in secure geologic storage. As a result of the Donaldsonville CCS project, we expect to produce up to approximately 1.9 million tons of low-carbon ammonia annually at our Donaldsonville complex.
On an interim basis, ExxonMobil is storing CO2 from our Donaldsonville complex in permanent geologic sites through enhanced oil recovery. Upon receiving its Class VI permits, ExxonMobil plans to transition to dedicated permanent storage, starting with its Rose CCS project (Rose). Rose is one of many dedicated permanent storage sites ExxonMobil is developing along the Gulf Coast to expand its integrated CCS network. The U.S. Environmental Protection Agency issued a draft Class VI permit for Rose in July 2025, and final permits are expected later in 2025.
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Construction of the dehydration and compression unit at our Yazoo City complex is expected to cost approximately $100 million. At Yazoo City, CCS is expected to commence in 2028, following construction, commissioning and start-up, and annually is expected to enable the transportation and sequestration of up to approximately 500,000 metric tons of CO2 that would otherwise have been emitted into the atmosphere. The Yazoo City CCS project is expected to qualify for tax credits under Section 45Q of the Internal Revenue Code, which provides a tax credit per metric ton of CO2 captured and disposed of in secure geologic storage.
Blue Point joint venture
On April 8, 2025, we announced that we formed a joint venture, Blue Point Number One, LLC, with JERA Co., Inc. (JERA), Japan’s largest energy company, and Mitsui & Co., Ltd. (Mitsui), a leading global investment and trading company, for the construction, production and offtake of low-carbon ammonia (the Blue Point joint venture). We hold 40% ownership, JERA holds 35% ownership, and Mitsui holds 25% ownership in the Blue Point joint venture. Under the terms of the Blue Point joint venture’s limited liability company agreement, JERA has a conditional option to reduce its ownership percentage that expires on December 31, 2025. If the specified condition is met, JERA can reduce its ownership below 35% but not lower than 20%. We would have the right and obligation to increase our ownership by the same amount that JERA reduces its ownership.
At our Blue Point complex in Ascension Parish, Louisiana, the Blue Point joint venture is expected to construct an autothermal reforming (ATR) ammonia production facility with a CO2 dehydration and compression unit to prepare captured CO2 for transportation and sequestration. Engineering, equipment procurement and pre-construction activities at our Blue Point complex began in the second quarter of 2025. Construction of the ammonia production facility is expected to begin in 2026, with low-carbon ammonia production expected to begin in 2029. We will be responsible for the development, operation and maintenance of the ammonia production facility under contracts with the Blue Point joint venture. We, JERA and Mitsui are required to purchase low-carbon ammonia produced by the Blue Point joint venture in accordance with our respective ownership percentages.
We estimate that the cost of the low-carbon ATR ammonia production facility with CCS technologies will be approximately $3.7 billion. We anticipate that approximately one-third of the estimated cost is related to materials that will be imported to the United States, with the majority of imported materials expected to arrive in Louisiana in 2028. Pursuant to periodic capital calls, the Blue Point joint venture members will fund the cost of the facility’s engineering, procurement and construction according to their respective ownership percentages. During the second quarter of 2025, we, JERA and Mitsui made initial capital contributions of $157 million, $137 million and $98 million, respectively, to the Blue Point joint venture. We funded $114 million of our contribution with cash and $43 million through a non-cash contribution of a license to use certain intellectual property.
In June 2025, the Blue Point joint venture executed agreements, including a long-term supply agreement, for a subsidiary of Linde plc to design, construct, own, operate and maintain an air separation unit (ASU) at our Blue Point complex to supply oxygen and nitrogen to the low-carbon ATR ammonia production facility, eliminating the need for the Blue Point joint venture to construct an ASU. As a result, the total projected cost of the low-carbon ATR ammonia production facility was reduced from approximately $4.0 billion to $3.7 billion.
In addition, we will invest approximately $550 million to build scalable infrastructure at our Blue Point complex to supply the ammonia production facility with services, including product storage and vessel loading. We will own and operate this infrastructure, and the Blue Point joint venture will compensate us for these services.
The low-carbon ammonia production facility is designed with an annual nameplate capacity of approximately 1.4 million metric tons (approximately 1.5 million tons) and is expected to capture greater than 95% of the CO2 generated from its production of ammonia. The facility is expected to capture, compress and dehydrate approximately 2.3 million metric tons of CO2 annually. Pursuant to a long-term offtake agreement, a subsidiary of Occidental Petroleum Corporation would then transport the CO2 and permanently sequester it in a Class VI well at its Pelican Sequestration Hub in Louisiana, which is currently under development. The ammonia production facility is expected to qualify for tax credits under Section 45Q of the Internal Revenue Code, which provides a tax credit per metric ton of CO2 captured and disposed of in secure geologic storage.
We determined that the Blue Point joint venture is a VIE of which we are the primary beneficiary. As a result, we consolidate this VIE in our consolidated financial statements, with the combined 60% equity interest owned by JERA and Mitsui recorded as noncontrolling interest. See “Liquidity and Capital Resources—Blue Point Joint Venture,” below, and Note 12—Variable Interest Entity, for additional information on the Blue Point joint venture.
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Low-carbon ammonia demand
In addition to discussions with existing and potential customers who have interest in using low-carbon ammonia for traditional applications, we are engaged in discussions regarding the supply of low-carbon ammonia for new applications. We are evaluating and are in various stages of discussions with other companies for long-term offtake and/or potential joint investments related to new and traditional applications for low-carbon ammonia. These discussions continue to advance as we gain greater clarity regarding demand for low-carbon ammonia, including associated carbon intensity requirements, government incentives and regulatory developments.
Market Conditions and Current Developments
Government Policies
On March 4, 2025, U.S. tariffs on Canadian imports went into effect and were applicable to the portion of our products manufactured in Canada that are either shipped to customers with U.S. destinations or shipped to one of our U.S. terminals. However, on March 6, 2025, an executive order was issued that excluded from these tariffs any products that enter the United States duty-free as a good of Canada pursuant to the United States-Mexico-Canada Agreement (USMCA). As a result, the U.S. tariffs on Canadian imports are currently not applicable to our Canadian production and the cost of the tariffs for the three-day period from March 4, 2025 to March 6, 2025 were not significant to our consolidated results. Subsequent changes to tariffs on imports from Canada, including those announced on July 31, 2025, have maintained duty-free treatment for USMCA-compliant products and therefore U.S. tariffs on Canadian imports continue to not be applicable to our Canadian production.
On March 12, 2025, the Trump administration reimposed section 232 tariffs on U.S. imports of steel and aluminum products from countries that had negotiated exemptions from those U.S. tariffs (originally imposed in 2018) and applied tariffs to U.S. imports of specified steel and aluminum derivative products from all countries. Effective June 4, 2025, these tariffs were increased to 50%.
On April 2, 2025, additional U.S. tariffs were announced by the Trump administration, consisting of (1) a ten percent tariff on nearly all imports into the United States with certain country (including Canada, Mexico, and Russia) and product exceptions and (2) higher tariffs on more than 50 countries. In accordance with this order, the ten percent tariffs were imposed on April 5, 2025. The higher tariffs on more than 50 countries were imposed on April 9, 2025, and were subsequently paused and then further delayed to August 1, 2025.
On July 31, 2025, the Trump administration issued an executive order that made several changes to the tariffs imposed in prior executive orders. These changes, effective August 7, 2025, include: (1) increasing tariffs to 15% on certain imports from the European Union; (2) increasing tariffs to 19% or 20% on imports from several Asian countries, including Thailand and Vietnam; and (3) increasing tariffs on many countries that had not negotiated a trade deal with the United States, including 30% tariffs on imports from Algeria and 15% tariffs on imports from Trinidad. The Trump administration also increased tariffs to 50% on imports from Brazil. Additional U.S. tariffs on imports from China have fluctuated from 10% effective February 5, 2025, to up to 145% or more effective April 10, 2025, back to 30% or more effective May 14, 2025 through August 12, 2025, as negotiations continue.
Negotiations between the United States and several countries are ongoing that may change the magnitude, the timing or other aspects of all of these tariffs. In addition, these tariffs have been the subject of litigation, which is ongoing, and may result in the elimination of, or other changes to, these tariffs.
Any of these tariffs or other tariffs and changes to U.S. trading policies may be reinstituted, paused, removed or changed at any time and may be done unpredictably and without notice. Retaliatory tariffs or other imposition of taxes and duties on U.S. exports to trading partners may also be significant and unpredictable.
Any imposed tariffs or the prospect of any retaliatory tariffs on U.S. exports, changes in U.S. trade policy or changes in other countries’ trade policies with the United States has and may continue to lead to uncertainty in the global marketplace, impact the supply and demand balance in many regions, and increase the cost of capital equipment and other supplies, which could adversely affect our business, financial condition, results of operations and cash flows.
U.S. Tax Legislation
On July 4, 2025, H.R.1 - One Big Beautiful Bill Act (the Act) was enacted into law. The Act makes permanent certain elements of the Tax Cuts and Jobs Act, including 100% bonus depreciation, and modifies several international tax provisions, including the foreign-derived intangible income deduction. The Act also includes changes to clean energy tax credits, including the 45Q tax credit for carbon sequestration. We are currently evaluating the impact of the Act, and the results of such
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evaluations will be reflected in our consolidated financial statements beginning with the three months ending September 30, 2025.
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 products at a breakeven price or above, or else they would cease production and leave a portion of global demand unsatisfied.
In the second quarter of 2025, the average selling price for our products was $376 per ton, or 17% higher, compared to $322 per ton in the second quarter of 2024. This resulted in an increase in net sales of approximately $270 million for the second quarter of 2025 compared to the second quarter of 2024. Average selling prices for all of our major products were higher in the second quarter of 2025 than in the second quarter of 2024 as higher global energy costs and supply disruptions from unexpected production outages in Egypt, Iran and Russia, raised the global market clearing price required to meet global demand, including continued strong demand in India and the Northern Hemisphere. In the six months ended June 30, 2025, the average selling price for our products was $354 per ton, or 9% higher compared to $324 per ton in the six months ended June 30, 2024. This resulted in an increase in net sales of approximately $287 million for the six months ended June 30, 2025 compared to the six months ended June 30, 2024.
Nitrogen Sales Volume
Sales volume was 5.0 million tons in the second quarter of 2025 compared to 4.9 million tons in the second quarter of 2024. Higher sales volume resulted in an increase in net sales of approximately $48 million. The increase in sales volume was due primarily to higher supply availability resulting from higher beginning inventory entering the second quarter of 2025. Sales volume in the six months ended June 30, 2025 was 10.0 million tons compared to 9.4 million tons in the six months ended June 30, 2024. This resulted in an increase in net sales of approximately $224 million for the six months ended June 30, 2025 compared to the six months ended June 30, 2024. The increase was due to the higher supply availability as a result of increased production in the six months ended June 30, 2025 compared to the six months ended June 30, 2024, which was adversely impacted by production outages from a winter storm in the first quarter of 2024.
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 36% and 28% of our production costs in the first six months of 2025 and the year ended December 31, 2024, respectively. Most of our manufacturing facilities are located in the United States and Canada. As a result, the price of natural gas in North America, which has historically been volatile, directly impacts a substantial portion of our operating expenses.
In the first quarter of 2025, colder-than-normal temperatures increased the demand for heating across North America, driving natural gas prices higher compared to the first quarter of 2024. Additional demand arose from liquefaction facilities in the United States running near maximum levels through the first quarter of 2025, driven by elevated global price spreads. In addition, the newly commissioned Plaquemines liquefaction facility in Louisiana increased production, adding approximately 12% to total U.S. liquefied natural gas export volumes. Due to the low natural gas price environment throughout 2024, natural gas producers were reluctant to increase supply to match the elevated demand, resulting in higher natural gas prices through the first quarter of 2025.
During the second quarter of 2025, natural gas supply increased as higher prices throughout the first quarter of 2025 gave producers an incentive to increase production. Colder-than-normal temperatures raised demand for heating but lowered power generation demand for air conditioning, holding prices between $3.00 and $4.00 per MMBtu. The tighter supply and demand balance kept average prices in the second quarter of 2025 more than $1.00 per MMBtu higher than the second quarter of 2024. U.S. liquefaction facilities continued to run at full rates during the second quarter of 2025, taking advantage of global price economics. Weekly storage injections consistently tracked above historical averages, alleviating concerns for below average levels to end the summer injection season.
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 our cost of natural gas used for production, which includes the impact of realized natural gas derivatives:
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| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||||||||||||||||||||||||||
| 2025 | 2024 | 2025 v. 2024 | 2025 | 2024 | 2025 v. 2024 | ||||||||||||||||||||||||||||||||||||||||||
| Average daily market price of natural gas at the Henry Hub (per MMBtu) | $ | 3.16 | $ | 2.04 | $ | 1.12 | 55 | % | $ | 3.71 | $ | 2.24 | $ | 1.47 | 66 | % | |||||||||||||||||||||||||||||||
Cost of natural gas used for production in cost of sales(1) (per MMBtu) | 3.36 | 1.90 | 1.46 | 77 | % | 3.52 | 2.53 | 0.99 | 39 | % | |||||||||||||||||||||||||||||||||||||
___________________________________________________________________________
(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.
In the second quarter of 2025, our cost of natural gas used for production, which includes the impact of realized natural gas derivatives, increased 77% to $3.36 per MMBtu from $1.90 per MMBtu in the second quarter of 2024. This increase in natural gas costs resulted in a decrease in gross margin of $136 million compared to the second quarter of 2024. In the six months ended June 30, 2025, our cost of natural gas used for production, which includes the impact of realized natural gas derivatives, increased 39% to $3.52 per MMBtu from $2.53 per MMBtu in the six months ended June 30, 2024. This increase in natural gas costs resulted in a decrease in gross margin of $176 million.
Financial Executive Summary
We reported net earnings attributable to common stockholders of $386 million for the three months ended June 30, 2025 compared to $420 million for the three months ended June 30, 2024, a decrease in net earnings of $34 million, or 8%. The decrease in net earnings for the three months ended June 30, 2025 compared to the three months ended June 30, 2024 primarily reflects the gains on sales of emission credits in the second quarter of 2024 that did not recur in the second quarter of 2025, an increase in selling, general and administrative expenses, a higher income tax provision, and higher net earnings attributable to noncontrolling interests. These factors that reduced net earnings attributable to common stockholders were partially offset by an increase in gross margin of $76 million.
Gross margin increased by $76 million, or 11%, to $755 million for the three months ended June 30, 2025 compared to $679 million for the three months ended June 30, 2024. The increase in gross margin was due primarily to a 17% increase in average selling prices to $376 per ton in the second quarter of 2025 from $322 per ton in the second quarter of 2024, which increased gross margin by $270 million, partially offset by higher natural gas costs, including the impact of realized derivatives, which decreased gross margin by $136 million, and higher costs associated with maintenance activity in the three months ended June 30, 2025 compared to the three months ended June 30, 2024.
Diluted net earnings per share attributable to common stockholders increased $0.07 per share, or 3%, to $2.37 per share in the second quarter of 2025 compared to $2.30 per share in the second quarter of 2024, due to lower weighted-average common shares outstanding as a result of shares repurchased under our share repurchase program, partially offset by lower net earnings. Diluted weighted-average common shares outstanding were 163.1 million shares for the three months ended June 30, 2025, a decrease of 11% compared to diluted weighted-average common shares outstanding of 182.8 million shares for the three months ended June 30, 2024.
Items Affecting Comparability of Results
For the three months ended June 30, 2025 and 2024, we reported net earnings attributable to common stockholders of $386 million and $420 million, respectively. For the six months ended June 30, 2025 and 2024, we reported net earnings attributable to common stockholders of $698 million and $614 million, respectively. In addition to the impact of market conditions discussed above, certain items affected the comparability of our financial results for the three and six months ended June 30, 2025 and 2024. 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.
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| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||||||||||||||
| 2025 | 2024 | 2025 | 2024 | ||||||||||||||||||||||||||||||||
| Pre-Tax | After-Tax | Pre-Tax | After-Tax | Pre-Tax | After-Tax | Pre-Tax | After-Tax | ||||||||||||||||||||||||||||
| (in millions) | |||||||||||||||||||||||||||||||||||
Unrealized net mark-to-market (gain) loss on natural gas derivatives(1) | $ | — | $ | — | $ | (1) | $ | (1) | $ | 2 | $ | 1 | $ | (34) | $ | (26) | |||||||||||||||||||
(Gain) loss on foreign currency transactions(2)(3) | (3) | (3) | — | — | (1) | (3) | 1 | 1 | |||||||||||||||||||||||||||
Blue Point joint venture construction costs(2)(3) | 2 | 2 | — | — | 2 | 2 | — | — | |||||||||||||||||||||||||||
Loss on sale of Ince facility(4) | — | — | — | — | 23 | 21 | — | — | |||||||||||||||||||||||||||
| Integration costs | — | — | 1 | 1 | — | — | 4 | 3 | |||||||||||||||||||||||||||
______________________________________________________________________________
(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)Includes results related to the Blue Point joint venture, of which we have a 40% equity interest. The after-tax impact for amounts related to the Blue Point joint venture does not include a tax provision on the 60% attributable to noncontrolling interests.
(4)Included in U.K. operations restructuring in our consolidated statement of operations.
Unrealized net mark-to-market (gain) loss 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 June 30, 2024, we recognized an unrealized net mark-to-market gain on natural gas derivatives of $1 million. In the six months ended June 30, 2025, we recognized an unrealized net mark-to-market loss on natural gas derivatives of $2 million compared to a gain of $34 million in the six months ended June 30, 2024.
(Gain) loss on foreign currency transactions
In the three months ended June 30, 2025, we recognized a gain on foreign currency transactions of $3 million. In the six months ended June 30, 2025, we recognized a gain on foreign currency transactions of $1 million compared to a loss of $1 million in the six months ended June 30, 2024. (Gain) loss on foreign currency transactions consists of foreign currency exchange rate impacts on foreign currency denominated transactions, including cash held in a foreign currency.
Blue Point joint venture construction costs
In the three and six months ended June 30, 2025, the Blue Point joint venture incurred costs of approximately $2 million related to the construction of the low-carbon ammonia production facility at our Blue Point complex. See “Overview of CF Holdings—Our Strategy—Blue Point joint venture,” above, and Note 12—Variable Interest Entity, for additional information on the Blue Point joint venture.
Loss on sale of Ince facility
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. In the third quarter of 2022, the final restructuring plan was approved, and the facility was subsequently decommissioned. In the first quarter of 2025, we sold our Ince facility and recognized a loss of $23 million, which is reflected in U.K. operations restructuring in our consolidated statement of operations for the six months ended June 30, 2025. See Note 6—Property, Plant and Equipment—Net for additional information on the sale of our Ince facility.
Integration costs
In the three and six months ended June 30, 2024, we incurred integration costs of $1 million and $4 million, respectively, related to our December 1, 2023 acquisition of an ammonia production facility located in Waggaman, Louisiana. We did not incur integration costs in 2025.
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Consolidated Results of Operations
The following table presents our consolidated results of operations and certain supplemental data for the three and six months ended June 30, 2025 and 2024:
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||||||||||||||||||||||||||
| 2025 | 2024 | 2025 v. 2024 | 2025 | 2024 | 2025 v. 2024 | ||||||||||||||||||||||||||||||||||||||||||
| (dollars in millions, except per share and per MMBtu amounts) | |||||||||||||||||||||||||||||||||||||||||||||||
| Net sales | $ | 1,890 | $ | 1,572 | $ | 318 | 20 | % | $ | 3,553 | $ | 3,042 | $ | 511 | 17 | % | |||||||||||||||||||||||||||||||
| Cost of sales (COS) | 1,135 | 893 | 242 | 27 | % | 2,226 | 1,954 | 272 | 14 | % | |||||||||||||||||||||||||||||||||||||
| Gross margin | 755 | 679 | 76 | 11 | % | 1,327 | 1,088 | 239 | 22 | % | |||||||||||||||||||||||||||||||||||||
| Gross margin percentage | 39.9 | % | 43.2 | % | (3.3) | % | 37.3 | % | 35.8 | % | 1.5 | % | |||||||||||||||||||||||||||||||||||
| Selling, general and administrative expenses | 101 | 76 | 25 | 33 | % | 185 | 164 | 21 | 13 | % | |||||||||||||||||||||||||||||||||||||
| U.K. operations restructuring | — | — | — | — | % | 23 | — | 23 | N/M | ||||||||||||||||||||||||||||||||||||||
| Integration costs | — | 1 | (1) | (100) | % | — | 4 | (4) | (100) | % | |||||||||||||||||||||||||||||||||||||
| Other operating—net | 8 | (39) | 47 | N/M | 22 | (22) | 44 | N/M | |||||||||||||||||||||||||||||||||||||||
| Total other operating costs and expenses | 109 | 38 | 71 | 187 | % | 230 | 146 | 84 | 58 | % | |||||||||||||||||||||||||||||||||||||
| Equity in earnings (losses) of operating affiliate | 2 | (3) | 5 | N/M | 6 | (1) | 7 | N/M | |||||||||||||||||||||||||||||||||||||||
| Operating earnings | 648 | 638 | 10 | 2 | % | 1,103 | 941 | 162 | 17 | % | |||||||||||||||||||||||||||||||||||||
| Interest expense | 36 | 37 | (1) | (3) | % | 73 | 74 | (1) | (1) | % | |||||||||||||||||||||||||||||||||||||
| Interest income | (17) | (28) | 11 | 39 | % | (34) | (58) | 24 | 41 | % | |||||||||||||||||||||||||||||||||||||
| Other non-operating—net | (6) | — | (6) | N/M | (8) | (4) | (4) | (100) | % | ||||||||||||||||||||||||||||||||||||||
| Earnings before income taxes | 635 | 629 | 6 | 1 | % | 1,072 | 929 | 143 | 15 | % | |||||||||||||||||||||||||||||||||||||
| Income tax provision | 143 | 123 | 20 | 16 | % | 229 | 185 | 44 | 24 | % | |||||||||||||||||||||||||||||||||||||
| Net earnings | 492 | 506 | (14) | (3) | % | 843 | 744 | 99 | 13 | % | |||||||||||||||||||||||||||||||||||||
| Less: Net earnings attributable to noncontrolling interests | 106 | 86 | 20 | 23 | % | 145 | 130 | 15 | 12 | % | |||||||||||||||||||||||||||||||||||||
| Net earnings attributable to common stockholders | $ | 386 | $ | 420 | $ | (34) | (8) | % | $ | 698 | $ | 614 | $ | 84 | 14 | % | |||||||||||||||||||||||||||||||
Diluted net earnings per share attributable to common stockholders | $ | 2.37 | $ | 2.30 | $ | 0.07 | 3 | % | $ | 4.20 | $ | 3.31 | $ | 0.89 | 27 | % | |||||||||||||||||||||||||||||||
Diluted weighted-average common shares outstanding | 163.1 | 182.8 | (19.7) | (11) | % | 165.9 | 185.5 | (19.6) | (11) | % | |||||||||||||||||||||||||||||||||||||
| Dividends declared per common share | $ | 0.50 | $ | 0.50 | $ | — | — | % | $ | 1.00 | $ | 1.00 | $ | — | — | % | |||||||||||||||||||||||||||||||
| Natural gas supplemental data (per MMBtu) | |||||||||||||||||||||||||||||||||||||||||||||||
Natural gas costs in COS(1) | $ | 3.36 | $ | 1.90 | $ | 1.46 | 77 | % | $ | 3.53 | $ | 2.30 | $ | 1.23 | 53 | % | |||||||||||||||||||||||||||||||
Realized derivatives (gain) loss in COS(2) | — | — | — | — | % | (0.01) | 0.23 | (0.24) | N/M | ||||||||||||||||||||||||||||||||||||||
| Cost of natural gas used for production in COS | $ | 3.36 | $ | 1.90 | $ | 1.46 | 77 | % | $ | 3.52 | $ | 2.53 | $ | 0.99 | 39 | % | |||||||||||||||||||||||||||||||
| Average daily market price of natural gas at the Henry Hub | $ | 3.16 | $ | 2.04 | $ | 1.12 | 55 | % | $ | 3.71 | $ | 2.24 | $ | 1.47 | 66 | % | |||||||||||||||||||||||||||||||
| Unrealized net mark-to-market (gain) loss on natural gas derivatives | $ | — | $ | (1) | $ | 1 | 100 | % | $ | 2 | $ | (34) | $ | 36 | N/M | ||||||||||||||||||||||||||||||||
| Depreciation and amortization | $ | 232 | $ | 222 | $ | 10 | 5 | % | $ | 453 | $ | 475 | $ | (22) | (5) | % | |||||||||||||||||||||||||||||||
Capital expenditures | $ | 245 | $ | 84 | $ | 161 | 192 | % | $ | 377 | $ | 182 | $ | 195 | 107 | % | |||||||||||||||||||||||||||||||
| Sales volume by product tons (000s) | 5,021 | 4,875 | 146 | 3 | % | 10,025 | 9,399 | 626 | 7 | % | |||||||||||||||||||||||||||||||||||||
| Production volume by product tons (000s): | |||||||||||||||||||||||||||||||||||||||||||||||
Ammonia(3) | 2,557 | 2,602 | (45) | (2) | % | 5,174 | 4,750 | 424 | 9 | % | |||||||||||||||||||||||||||||||||||||
| Granular urea | 1,182 | 1,255 | (73) | (6) | % | 2,292 | 2,214 | 78 | 4 | % | |||||||||||||||||||||||||||||||||||||
UAN (32%)(4) | 1,725 | 1,833 | (108) | (6) | % | 3,581 | 3,464 | 117 | 3 | % | |||||||||||||||||||||||||||||||||||||
| AN | 341 | 333 | 8 | 2 | % | 663 | 674 | (11) | (2) | % | |||||||||||||||||||||||||||||||||||||
N/M—Not Meaningful
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(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.
(4)UAN product tons assume a 32% nitrogen content basis for production volume.
Second Quarter of 2025 Compared to Second Quarter of 2024
Net Sales
Our total net sales increased $318 million, or 20%, to $1.89 billion in the second quarter of 2025 compared to $1.57 billion in the second quarter of 2024, due to higher average selling prices and higher sales volume.
Our average selling price was $376 per ton in the second quarter of 2025 compared to $322 per ton in the second quarter of 2024, due to higher average selling prices across all of our segments as higher global energy costs raised the global market clearing price required to meet global demand. See “Market Conditions and Current Developments—Nitrogen Selling Prices,” above, for additional information about the factors impacting global energy costs. The impact of higher average selling prices was an increase in net sales of approximately $270 million for the second quarter of 2025 compared to the second quarter of 2024.
Our total sales volume was 5.0 million product tons in the second quarter of 2025 compared to 4.9 million product tons in the second quarter of 2024, as higher sales volume in our UAN, Ammonia and AN segments was partially offset by lower sales volume in our Other and Granular Urea segments. The impact of higher sales volume was an increase in net sales of approximately $48 million.
Cost of Sales
Our total cost of sales increased $242 million, or 27%, to $1.14 billion in the second quarter of 2025 from $893 million in the second quarter of 2024. The increase in our cost of sales primarily reflects higher costs for natural gas, including the impact of realized derivatives, which increased cost of sales by $136 million, higher costs in the second quarter of 2025 associated with maintenance activity and an increase in sales volume.
Cost of sales averaged $226 per ton in the second quarter of 2025, a 23% increase compared to $183 per ton in the second quarter of 2024. Our cost of natural gas, including the impact of realized derivatives, increased $1.46 per MMBtu, or 77%, to $3.36 per MMBtu in the second quarter of 2025 from $1.90 per MMBtu in the second quarter of 2024. See “Market Conditions and Current Developments—Natural Gas,” above, for additional information about the factors impacting natural gas prices.
Selling, General and Administrative Expenses
Selling, general and administrative expenses increased $25 million to $101 million in the second quarter of 2025 compared to $76 million in the second quarter of 2024. The increase was due primarily to higher incentive compensation due to strong operating performance and higher costs related to certain corporate initiatives.
Integration Costs
In the second quarter of 2024, we incurred integration costs of $1 million related to our December 1, 2023 acquisition of an ammonia production facility located in Waggaman, Louisiana. We did not incur integration costs in 2025.
Other Operating—Net
Other operating—net was $8 million of expense in the second quarter of 2025 compared to $39 million of income in the second quarter of 2024. The $8 million of expense in the second quarter of 2025 consists primarily of costs related to front-end engineering and design (FEED) studies for our clean energy initiatives. The $39 million of income in the second quarter of 2024 consists primarily of gains on sales of emission credits, partially offset by costs related to FEED studies for our clean energy initiatives. See “Our Strategy,” above, for additional information related to our clean energy initiatives.
Equity in Earnings (Losses) of Operating Affiliate
Equity in earnings (losses) of operating affiliate was $2 million of earnings in the second quarter of 2025 compared to a $3 million loss in the second quarter of 2024. Higher equity in earnings of operating affiliate in the second quarter of 2025 compared to the second quarter of 2024 reflects an increase in the operating results of PLNL due primarily to higher ammonia
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selling prices and a plant turnaround at the PLNL facility that occurred in the second quarter of 2024 that did not recur in 2025, partially offset by higher natural gas costs.
Interest Expense
Interest expense was $36 million in the second quarter of 2025 compared to $37 million in the second quarter of 2024.
Interest Income
Interest income was $17 million in the second quarter of 2025 compared to $28 million in the second quarter of 2024. The decrease of $11 million was due primarily to a decrease in short-term investments.
Income Tax Provision
For the second quarter of 2025, we recorded an income tax provision of $143 million on pre-tax income of $635 million, or an effective tax rate of 22.4%, compared to an income tax provision of $123 million on pre-tax income of $629 million, or an effective tax rate of 19.5%, for the second quarter of 2024. Our income tax provision for the second quarter of 2025 includes $21 million of income tax expense related to an increase in our unrecognized tax benefits resulting from ongoing tax audits, which increased our effective tax rate by 3.4 percentage points.
Our effective tax rate is impacted by earnings attributable to the noncontrolling interests as our consolidated income tax provision does not include a tax provision on the earnings attributable to the noncontrolling interests. Our effective tax rate for the second quarter of 2025 of 22.4%, which is based on pre-tax income of $635 million, including $106 million of earnings attributable to the noncontrolling interests, would be 4.5 percentage points higher, or 26.9%, if based on pre-tax income exclusive of the earnings attributable to the noncontrolling interests of $106 million. Our effective tax rate for the second quarter of 2024 of 19.5%, which is based on pre-tax income of $629 million, including $86 million of earnings attributable to the noncontrolling interest, would be 3.1 percentage points higher, or 22.6%, if based on pre-tax income exclusive of the earnings attributable to the noncontrolling interest of $86 million.
Net Earnings Attributable to Noncontrolling Interests
Net earnings attributable to noncontrolling interests increased $20 million to $106 million in the second quarter of 2025 compared to $86 million in the second quarter of 2024 due primarily to higher earnings of CFN driven by higher average selling prices, partially offset by higher natural gas costs. In addition, the increase also reflects the earnings attributable to the noncontrolling interests in the Blue Point joint venture, which was formed in the second quarter of 2025. See “Overview of CF Holdings—Our Strategy—Blue Point joint venture,” above, Note 12—Variable Interest Entity and Note 13—Noncontrolling Interests for additional information on the Blue Point joint venture.
Diluted Net Earnings Per Share Attributable to Common Stockholders
Diluted net earnings per share attributable to common stockholders increased $0.07, or 3%, to $2.37 per share in the second quarter of 2025 from $2.30 per share in the second quarter of 2024. This increase was due primarily to lower weighted-average common shares outstanding as a result of common shares repurchased under our share repurchase program, partially offset by lower net earnings. Diluted weighted-average common shares outstanding declined 11% from 182.8 million shares for the second quarter of 2024 to 163.1 million shares for the second quarter of 2025.
Six Months Ended June 30, 2025 Compared to Six Months Ended June 30, 2024
Net Sales
Our total net sales increased $511 million, or 17%, to $3.55 billion in the first six months of 2025 compared to $3.04 billion in the first six months of 2024, due to higher average selling prices and higher sales volume.
Our average selling price was $354 per ton in the first six months of 2025 compared to $324 per ton in the first six months of 2024, due to higher average selling prices across all of our segments as higher global energy costs raised the global market clearing price required to meet global demand. See “Market Conditions and Current Developments—Nitrogen Selling Prices,” above, for additional information about the factors impacting global energy costs. The impact of higher average selling prices was an increase in net sales of approximately $287 million for the six months ended June 30, 2025 compared to the six months ended June 30, 2024.
Our total sales volume was 10.0 million product tons in the first six months of 2025 compared to 9.4 million product tons in the first six months of 2024, as higher sales volume in our UAN and Ammonia segments was partially offset by lower sales
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volume in our Other, Granular Urea and AN segments. The impact of higher sales volume was an increase in net sales of approximately $224 million.
Cost of Sales
Our total cost of sales increased $272 million, or 14%, to $2.23 billion in the first six months of 2025 from $1.95 billion in the first six months of 2024. The increase in our cost of sales primarily reflects higher costs for natural gas, including the impact of realized derivatives, which increased cost of sales by $176 million, and an increase in sales volume, which increased cost of sales by $87 million. These factors that increased cost of sales in the first six months of 2025 were partially offset by lower costs associated with maintenance activity in the first six months of 2025 compared to the first six months of 2024, due in part to a winter storm in the first quarter of 2024 that produced extremely cold temperatures that impacted our operations. In the first six months of 2024, we incurred additional maintenance costs and lost production, including as a result of the adverse weather in the first quarter of 2024.
Cost of sales also includes the impact of a $2 million unrealized net mark-to-market loss on natural gas derivatives in the first six months of 2025 compared to a $34 million gain in the first six months of 2024.
Cost of sales averaged $222 per ton in the first six months of 2025, a 7% increase compared to $208 per ton in the first six months of 2024. Our cost of natural gas, including the impact of realized derivatives, increased $0.99 per MMBtu, or 39%, to $3.52 per MMBtu in the first six months of 2025 from $2.53 per MMBtu in the first six months of 2024. See “Market Conditions and Current Developments—Natural Gas,” above, for additional information about the factors impacting natural gas prices.
Selling, General and Administrative Expenses
Selling, general and administrative expenses increased $21 million to $185 million in the first six months of 2025 compared to $164 million in the first six months of 2024. The increase was due primarily to higher costs related to certain corporate initiatives, including our clean energy initiatives, and higher incentive compensation due to strong operating performance.
U.K. 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. In the third quarter of 2022, the final restructuring plan was approved, and the facility was subsequently decommissioned. In the first quarter of 2025, we sold our Ince facility and recognized a loss of $23 million. See Note 6—Property, Plant and Equipment—Net for additional information on the sale of our Ince facility.
Integration Costs
In the six months ended June 30, 2024, we incurred integration costs of $4 million related to our December 1, 2023 acquisition of an ammonia production facility located in Waggaman, Louisiana. We did not incur integration costs in 2025.
Other Operating—Net
Other operating—net was $22 million of expense in the first six months of 2025 compared to $22 million of income in the first six months of 2024. The $22 million of expense in the first six months of 2025 consists primarily of costs related to FEED studies for our clean energy initiatives. The $22 million of income in the six months ended June 30, 2024 consists primarily of gains on sales of emission credits, partially offset by costs related to FEED studies for our clean energy initiatives. See “Our Strategy,” above, for additional information related to our clean energy initiatives.
Equity in Earnings (Losses) of Operating Affiliate
Equity in earnings (losses) of operating affiliate was $6 million of earnings in the first six months of 2025 compared to a $1 million loss in the first six months of 2024. Equity in earnings of operating affiliate in the first six months of 2025 reflects an increase in the operating results of PLNL due primarily to higher ammonia selling prices and a plant turnaround at the PLNL facility that occurred in the second quarter of 2024 that did not recur in 2025, partially offset by higher natural gas costs.
Interest Expense
Interest expense was $73 million in the first six months of 2025 compared to $74 million in the first six months of 2024.
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Interest Income
Interest income was $34 million in the first six months of 2025 compared to $58 million in the first six months of 2024. The decrease of $24 million was due primarily to a decrease in short-term investments.
Income Tax Provision
For the six months ended June 30, 2025, we recorded an income tax provision of $229 million on pre-tax income of $1.07 billion, or an effective tax rate of 21.3%, compared to an income tax provision of $185 million on pre-tax income of $929 million, or an effective tax rate of 19.9%, for the six months ended June 30, 2024. Our income tax provision for the six months ended June 30, 2025 includes $21 million of income tax expense related to an increase in our unrecognized tax benefits resulting from ongoing tax audits, which increased our effective tax rate by 2.0 percentage points.
Our effective tax rate is impacted by earnings attributable to the noncontrolling interests as our consolidated income tax provision does not include a tax provision on the earnings attributable to the noncontrolling interests. Our effective tax rate for the six months ended June 30, 2025 of 21.3%, which is based on pre-tax income of $1.07 billion, including $145 million of earnings attributable to the noncontrolling interests, would be 3.4 percentage points higher, or 24.7%, if based on pre-tax income exclusive of the earnings attributable to the noncontrolling interests of $145 million. Our effective tax rate for the six months ended June 30, 2024 of 19.9%, which is based on pre-tax income of $929 million, including $130 million of earnings attributable to the noncontrolling interest, would be 3.2 percentage points higher, or 23.1%, if based on pre-tax income exclusive of the earnings attributable to the noncontrolling interest of $130 million.
Net Earnings Attributable to Noncontrolling Interests
Net earnings attributable to noncontrolling interests increased $15 million to $145 million in the first six months of 2025 compared to $130 million in the first six months of 2024 due primarily to higher earnings of CFN driven by higher average selling prices and the impact of higher sales volume, partially offset by higher natural gas costs. In addition, the increase also reflects the earnings attributable to the noncontrolling interests in the Blue Point joint venture, which was formed in the second quarter of 2025. See “Overview of CF Holdings—Our Strategy—Blue Point joint venture,” above, Note 12—Variable Interest Entity and Note 13—Noncontrolling Interests for additional information on the Blue Point joint venture.
Diluted Net Earnings Per Share Attributable to Common Stockholders
Diluted net earnings per share attributable to common stockholders increased $0.89, or 27%, to $4.20 per share in the first six months of 2025 from $3.31 per share in the first six months of 2024. This increase was due to higher net earnings driven by an increase in gross margin and lower weighted-average common shares outstanding. Diluted weighted-average common shares outstanding declined 11% from 185.5 million shares for the six months ended June 30, 2024 to 165.9 million shares for the six months ended June 30, 2025, due primarily to repurchases of common shares under our share repurchase program.
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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 | ||||||||||||||||||||||||||||||
| (dollars in millions) | |||||||||||||||||||||||||||||||||||
| Three months ended June 30, 2025 | |||||||||||||||||||||||||||||||||||
| Net sales | $ | 491 | $ | 547 | $ | 610 | $ | 117 | $ | 125 | $ | 1,890 | |||||||||||||||||||||||
| Cost of sales | 355 | 268 | 340 | 92 | 80 | 1,135 | |||||||||||||||||||||||||||||
| Gross margin | $ | 136 | $ | 279 | $ | 270 | $ | 25 | $ | 45 | $ | 755 | |||||||||||||||||||||||
| Gross margin percentage | 27.7 | % | 51.0 | % | 44.3 | % | 21.4 | % | 36.0 | % | 39.9 | % | |||||||||||||||||||||||
| Three months ended June 30, 2024 | |||||||||||||||||||||||||||||||||||
| Net sales | $ | 409 | $ | 457 | $ | 475 | $ | 98 | $ | 133 | $ | 1,572 | |||||||||||||||||||||||
| Cost of sales | 262 | 230 | 259 | 75 | 67 | 893 | |||||||||||||||||||||||||||||
| Gross margin | $ | 147 | $ | 227 | $ | 216 | $ | 23 | $ | 66 | $ | 679 | |||||||||||||||||||||||
| Gross margin percentage | 35.9 | % | 49.7 | % | 45.5 | % | 23.5 | % | 49.6 | % | 43.2 | % | |||||||||||||||||||||||
| Six months ended June 30, 2025 | |||||||||||||||||||||||||||||||||||
| Net sales | $ | 1,011 | $ | 986 | $ | 1,080 | $ | 218 | $ | 258 | $ | 3,553 | |||||||||||||||||||||||
| Cost of sales | 689 | 534 | 668 | 177 | 158 | 2,226 | |||||||||||||||||||||||||||||
| Gross margin | $ | 322 | $ | 452 | $ | 412 | $ | 41 | $ | 100 | $ | 1,327 | |||||||||||||||||||||||
| Gross margin percentage | 31.8 | % | 45.8 | % | 38.1 | % | 18.8 | % | 38.8 | % | 37.3 | % | |||||||||||||||||||||||
| Six months ended June 30, 2024 | |||||||||||||||||||||||||||||||||||
| Net sales | $ | 811 | $ | 864 | $ | 900 | $ | 212 | $ | 255 | $ | 3,042 | |||||||||||||||||||||||
| Cost of sales | 599 | 483 | 541 | 180 | 151 | 1,954 | |||||||||||||||||||||||||||||
| Gross margin | $ | 212 | $ | 381 | $ | 359 | $ | 32 | $ | 104 | $ | 1,088 | |||||||||||||||||||||||
| Gross margin percentage | 26.1 | % | 44.1 | % | 39.9 | % | 15.1 | % | 40.8 | % | 35.8 | % | |||||||||||||||||||||||
(1)The cost of ammonia and other products that are upgraded in the production of Granular Urea, UAN, AN and Other products is transferred at cost into the results of those products.
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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 June 30, | Six Months Ended June 30, | ||||||||||||||||||||||||||||||||||||||||||||||
| 2025 | 2024 | 2025 v. 2024 | 2025 | 2024 | 2025 v. 2024 | ||||||||||||||||||||||||||||||||||||||||||
| (dollars in millions, except per ton amounts) | |||||||||||||||||||||||||||||||||||||||||||||||
| Net sales | $ | 491 | $ | 409 | $ | 82 | 20 | % | $ | 1,011 | $ | 811 | $ | 200 | 25 | % | |||||||||||||||||||||||||||||||
| Cost of sales | 355 | 262 | 93 | 35 | % | 689 | 599 | 90 | 15 | % | |||||||||||||||||||||||||||||||||||||
| Gross margin | $ | 136 | $ | 147 | $ | (11) | (7) | % | $ | 322 | $ | 212 | $ | 110 | 52 | % | |||||||||||||||||||||||||||||||
| Gross margin percentage | 27.7 | % | 35.9 | % | (8.2) | % | 31.8 | % | 26.1 | % | 5.7 | % | |||||||||||||||||||||||||||||||||||
| Sales volume by product tons (000s) | 1,087 | 979 | 108 | 11 | % | 2,233 | 1,897 | 336 | 18 | % | |||||||||||||||||||||||||||||||||||||
Sales volume by nutrient tons (000s)(1) | 891 | 802 | 89 | 11 | % | 1,831 | 1,555 | 276 | 18 | % | |||||||||||||||||||||||||||||||||||||
| Average selling price per product ton | $ | 452 | $ | 418 | $ | 34 | 8 | % | $ | 453 | $ | 428 | $ | 25 | 6 | % | |||||||||||||||||||||||||||||||
Average selling price per nutrient ton(1) | $ | 551 | $ | 510 | $ | 41 | 8 | % | $ | 552 | $ | 522 | $ | 30 | 6 | % | |||||||||||||||||||||||||||||||
| Gross margin per product ton | $ | 125 | $ | 150 | $ | (25) | (17) | % | $ | 144 | $ | 112 | $ | 32 | 29 | % | |||||||||||||||||||||||||||||||
Gross margin per nutrient ton(1) | $ | 153 | $ | 183 | $ | (30) | (16) | % | $ | 176 | $ | 136 | $ | 40 | 29 | % | |||||||||||||||||||||||||||||||
| Depreciation and amortization | $ | 52 | $ | 49 | $ | 3 | 6 | % | $ | 100 | $ | 121 | $ | (21) | (17) | % | |||||||||||||||||||||||||||||||
| Unrealized net mark-to-market loss (gain) on natural gas derivatives | $ | — | $ | — | $ | — | — | % | $ | 1 | $ | (12) | $ | 13 | N/M | ||||||||||||||||||||||||||||||||
_______________________________________________________________________________
N/M—Not Meaningful
(1)Ammonia represents 82% nitrogen content. Nutrient tons represent the tons of nitrogen within the product tons.
Second Quarter of 2025 Compared to Second Quarter of 2024
Net Sales. Net sales in our Ammonia segment increased by $82 million, or 20%, to $491 million in the second quarter of 2025 from $409 million in the second quarter of 2024. The increase in our net sales reflects an 8% increase in average selling prices and an 11% increase in sales volume. Average selling prices increased to $452 per ton in the second quarter of 2025 compared to $418 per ton in the second quarter of 2024. The increase in our average selling price was due primarily to higher global energy costs that raised the global market clearing price required to meet global demand.
Ammonia sales volume in the second quarter of 2025 was 1.1 million tons, an increase of 11% compared to 1.0 million tons in the second quarter of 2024. The increase in sales volume was due primarily to favorable weather in the second quarter of 2025, which resulted in higher spring ammonia applications, supported by higher supply availability driven by higher beginning inventory entering the second quarter of 2025.
Cost of Sales. Cost of sales in our Ammonia segment averaged $327 per ton in the second quarter of 2025, a 22% increase from $268 per ton in the second quarter of 2024. The increase was due primarily to higher realized natural gas costs, including the impact of realized derivatives, and higher costs associated with maintenance activity in the second quarter of 2025 compared to the second quarter of 2024.
Gross Margin. Gross margin in our Ammonia segment decreased by $11 million, or 7%, to $136 million in the second quarter of 2025 from $147 million in the second quarter of 2024, and our gross margin percentage was 27.7% in the second quarter of 2025 compared to 35.9% in the second quarter of 2024. The decrease in gross margin was due primarily to an increase in realized natural gas costs, including the impact of realized derivatives, which reduced gross margin by $47 million and a net increase in manufacturing, maintenance and other costs, which decreased gross margin by $40 million. These factors that decreased gross margin were partially offset by an 8% increase in average selling prices, which increased gross margin by $52 million and an 11% increase in sales volume, which increased gross margin by $24 million.
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Six Months Ended June 30, 2025 Compared to Six Months Ended June 30, 2024
Net Sales. Net sales in our Ammonia segment increased by $200 million, or 25%, to $1.01 billion in the six months ended June 30, 2025 from $811 million in the six months ended June 30, 2024. The increase in our net sales reflects an 18% increase in sales volume and a 6% increase in average selling prices. Average selling prices increased to $453 per ton in the six months ended June 30, 2025 compared to $428 per ton in the six months ended June 30, 2024 as higher global energy costs, due in part to gas curtailments and higher gas costs in Europe, raised the global market clearing price required to meet global demand.
Ammonia sales volume in the six months ended June 30, 2025 was 2.2 million tons, an increase of 18% compared to 1.9 million tons in the six months ended June 30, 2024. The increase in sales volume was due primarily to higher supply availability as a result of increased production in the first quarter of 2025 compared to the first quarter of 2024, which was adversely impacted by production outages from a winter storm.
Cost of Sales. Cost of sales in our Ammonia segment averaged $309 per ton in the six months ended June 30, 2025, a 2% decrease from $316 per ton in the six months ended June 30, 2024. The decrease was due primarily to lower costs for maintenance activity in the six months ended June 30, 2025 compared to the six months ended June 30, 2024, which included higher costs for maintenance, repairs and certain unabsorbed fixed costs as a result of plant downtime, including the impact of the adverse weather in the first quarter of 2024 as discussed above, partially offset by higher realized natural gas costs, including the impact of realized derivatives.
Gross Margin. Gross margin in our Ammonia segment increased by $110 million, or 52%, to $322 million in the six months ended June 30, 2025 from $212 million in the six months ended June 30, 2024, and our gross margin percentage was 31.8% in the six months ended June 30, 2025 compared to 26.1% in the six months ended June 30, 2024. The increase in gross margin was due primarily to an 18% increase in sales volume, which increased gross margin by $83 million, a 6% increase in average selling prices, which increased gross margin by $64 million, and a net decrease in manufacturing, maintenance and other costs, which increased gross margin by $26 million. These factors that increased gross margin were partially offset by the impact of an increase in realized natural gas costs, including the impact of realized derivatives, which reduced gross margin by $50 million. Gross margin also includes the impact of a $1 million unrealized net mark-to-market loss on natural gas derivatives in the six months ended June 30, 2025 compared to a $12 million gain in the six months ended June 30, 2024.
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 complexes.
The following table presents summary operating data for our Granular Urea segment:
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||||||||||||||||||||||||||
| 2025 | 2024 | 2025 v. 2024 | 2025 | 2024 | 2025 v. 2024 | ||||||||||||||||||||||||||||||||||||||||||
| (dollars in millions, except per ton amounts) | |||||||||||||||||||||||||||||||||||||||||||||||
| Net sales | $ | 547 | $ | 457 | $ | 90 | 20 | % | $ | 986 | $ | 864 | $ | 122 | 14 | % | |||||||||||||||||||||||||||||||
| Cost of sales | 268 | 230 | 38 | 17 | % | 534 | 483 | 51 | 11 | % | |||||||||||||||||||||||||||||||||||||
| Gross margin | $ | 279 | $ | 227 | $ | 52 | 23 | % | $ | 452 | $ | 381 | $ | 71 | 19 | % | |||||||||||||||||||||||||||||||
| Gross margin percentage | 51.0 | % | 49.7 | % | 1.3 | % | 45.8 | % | 44.1 | % | 1.7 | % | |||||||||||||||||||||||||||||||||||
| Sales volume by product tons (000s) | 1,188 | 1,251 | (63) | (5) | % | 2,313 | 2,343 | (30) | (1) | % | |||||||||||||||||||||||||||||||||||||
Sales volume by nutrient tons (000s)(1) | 548 | 576 | (28) | (5) | % | 1,065 | 1,078 | (13) | (1) | % | |||||||||||||||||||||||||||||||||||||
| Average selling price per product ton | $ | 460 | $ | 365 | $ | 95 | 26 | % | $ | 426 | $ | 369 | $ | 57 | 15 | % | |||||||||||||||||||||||||||||||
Average selling price per nutrient ton(1) | $ | 998 | $ | 793 | $ | 205 | 26 | % | $ | 926 | $ | 801 | $ | 125 | 16 | % | |||||||||||||||||||||||||||||||
| Gross margin per product ton | $ | 235 | $ | 181 | $ | 54 | 30 | % | $ | 195 | $ | 163 | $ | 32 | 20 | % | |||||||||||||||||||||||||||||||
Gross margin per nutrient ton(1) | $ | 509 | $ | 394 | $ | 115 | 29 | % | $ | 424 | $ | 353 | $ | 71 | 20 | % | |||||||||||||||||||||||||||||||
| Depreciation and amortization | $ | 72 | $ | 76 | $ | (4) | (5) | % | $ | 143 | $ | 145 | $ | (2) | (1) | % | |||||||||||||||||||||||||||||||
| Unrealized net mark-to-market gain on natural gas derivatives | $ | — | $ | — | $ | — | — | % | $ | — | $ | (9) | $ | 9 | 100 | % | |||||||||||||||||||||||||||||||
_______________________________________________________________________________
(1)Granular urea represents 46% nitrogen content. Nutrient tons represent the tons of nitrogen within the product tons.
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Second Quarter of 2025 Compared to Second Quarter of 2024
Net Sales. Net sales in our Granular Urea segment increased $90 million, or 20%, to $547 million in the second quarter of 2025 from $457 million in the second quarter of 2024. The increase in our net sales reflects a 26% increase in average selling prices, partially offset by a 5% decrease in sales volume. Average selling prices increased to $460 per ton in the second quarter of 2025 compared to $365 per ton in the second quarter of 2024. The increase in our average selling price was due primarily to higher global energy costs and natural gas availability-related supply disruptions in Egypt and Iran, which raised the global market clearing price required to meet global demand, including continued strong demand in India and the Northern Hemisphere. The decrease in sales volume was due primarily to decreased supply availability as a result of lower production in the second quarter of 2025 compared to the second quarter of 2024.
Cost of Sales. Cost of sales in our Granular Urea segment averaged $225 per ton in the second quarter of 2025, a 22% increase from $184 per ton in the second quarter of 2024. The increase was due primarily to higher realized natural gas costs, including the impact of realized derivatives, and higher costs associated with maintenance activity in the second quarter of 2025 compared to the second quarter of 2024.
Gross Margin. Gross margin in our Granular Urea segment increased by $52 million, or 23%, to $279 million in the second quarter of 2025 from $227 million in the second quarter of 2024, and our gross margin percentage was 51.0% in the second quarter of 2025 compared to 49.7% in the second quarter of 2024. The increase in gross margin was due primarily to a 26% increase in average selling prices, which increased gross margin by $108 million. This increase in gross margin was partially offset by an increase in realized natural gas costs, including the impact of realized derivatives, which reduced gross margin by $34 million, a net increase in manufacturing, maintenance and other costs, which decreased gross margin by $16 million, and a 5% decrease in sales volume, which decreased gross margin by $6 million.
Six Months Ended June 30, 2025 Compared to Six Months Ended June 30, 2024
Net Sales. Net sales in our Granular Urea segment increased $122 million, or 14%, to $986 million in the six months ended June 30, 2025 from $864 million in the six months ended June 30, 2024 due primarily to a 15% increase in average selling prices, partially offset by a 1% decrease in sales volume. Average selling prices increased to $426 per ton in the six months ended June 30, 2025 compared to $369 per ton in the six months ended June 30, 2024 as higher global energy costs and natural gas availability-related supply disruptions in Egypt and Iran, which raised the global market clearing price required to meet global demand, including continued strong demand in India and the Northern Hemisphere.
Cost of Sales. Cost of sales in our Granular Urea segment averaged $231 per ton in the six months ended June 30, 2025, a 12% increase from $206 per ton in the six months ended June 30, 2024. The increase was due primarily to higher realized natural gas costs, including the impact of realized derivatives.
Gross Margin. Gross margin in our Granular Urea segment increased by $71 million, or 19%, to $452 million in the six months ended June 30, 2025 from $381 million in the six months ended June 30, 2024, and our gross margin percentage was 45.8% in the six months ended June 30, 2025 compared to 44.1% in the six months ended June 30, 2024. The increase in gross margin was due primarily to a 15% increase in average selling prices, which increased gross margin by $127 million, and a net decrease in manufacturing, maintenance and other costs, which increased gross margin by $4 million. These factors that increased gross margin were partially offset by an increase in realized natural gas costs, including the impact of realized derivatives, which reduced gross margin by $50 million, and a 1% decrease in sales volume, which decreased gross margin by $1 million. Gross margin also includes the impact of a $9 million unrealized net mark-to-market gain on natural gas derivatives in the six months ended June 30, 2024.
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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 complexes.
The following table presents summary operating data for our UAN segment:
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||||||||||||||||||||||||||
| 2025 | 2024 | 2025 v. 2024 | 2025 | 2024 | 2025 v. 2024 | ||||||||||||||||||||||||||||||||||||||||||
| (dollars in millions, except per ton amounts) | |||||||||||||||||||||||||||||||||||||||||||||||
| Net sales | $ | 610 | $ | 475 | $ | 135 | 28 | % | $ | 1,080 | $ | 900 | $ | 180 | 20 | % | |||||||||||||||||||||||||||||||
| Cost of sales | 340 | 259 | 81 | 31 | % | 668 | 541 | 127 | 23 | % | |||||||||||||||||||||||||||||||||||||
| Gross margin | $ | 270 | $ | 216 | $ | 54 | 25 | % | $ | 412 | $ | 359 | $ | 53 | 15 | % | |||||||||||||||||||||||||||||||
| Gross margin percentage | 44.3 | % | 45.5 | % | (1.2) | % | 38.1 | % | 39.9 | % | (1.8) | % | |||||||||||||||||||||||||||||||||||
| Sales volume by product tons (000s) | 1,902 | 1,748 | 154 | 9 | % | 3,777 | 3,359 | 418 | 12 | % | |||||||||||||||||||||||||||||||||||||
Sales volume by nutrient tons (000s)(1) | 602 | 553 | 49 | 9 | % | 1,195 | 1,062 | 133 | 13 | % | |||||||||||||||||||||||||||||||||||||
| Average selling price per product ton | $ | 321 | $ | 272 | $ | 49 | 18 | % | $ | 286 | $ | 268 | $ | 18 | 7 | % | |||||||||||||||||||||||||||||||
Average selling price per nutrient ton(1) | $ | 1,013 | $ | 859 | $ | 154 | 18 | % | $ | 904 | $ | 847 | $ | 57 | 7 | % | |||||||||||||||||||||||||||||||
| Gross margin per product ton | $ | 142 | $ | 124 | $ | 18 | 15 | % | $ | 109 | $ | 107 | $ | 2 | 2 | % | |||||||||||||||||||||||||||||||
Gross margin per nutrient ton(1) | $ | 449 | $ | 391 | $ | 58 | 15 | % | $ | 345 | $ | 338 | $ | 7 | 2 | % | |||||||||||||||||||||||||||||||
| Depreciation and amortization | $ | 72 | $ | 68 | $ | 4 | 6 | % | $ | 145 | $ | 137 | $ | 8 | 6 | % | |||||||||||||||||||||||||||||||
| Unrealized net mark-to-market loss (gain) on natural gas derivatives | $ | — | $ | — | $ | — | — | % | $ | 1 | $ | (10) | $ | 11 | N/M | ||||||||||||||||||||||||||||||||
_______________________________________________________________________________
N/M—Not Meaningful
(1)UAN represents between 28% and 32% of nitrogen content, depending on the concentration specified by the customer. Nutrient tons represent the tons of nitrogen within the product tons.
Second Quarter of 2025 Compared to Second Quarter of 2024
Net Sales. Net sales in our UAN segment increased $135 million, or 28%, to $610 million in the second quarter of 2025 from $475 million in the second quarter of 2024 due primarily to an 18% increase in average selling prices and a 9% increase in sales volume. Average selling prices increased to $321 per ton in the second quarter of 2025 compared to $272 per ton in the second quarter of 2024 due primarily to higher global energy costs, which raised the global market clearing price required to meet global demand. Sales volume was higher due primarily to inventory drawdown to meet strong domestic and international demand.
Cost of Sales. Cost of sales in our UAN segment averaged $179 per ton in the second quarter of 2025, a 21% increase from $148 per ton in second quarter of 2024, due primarily to higher realized natural gas costs, including the impact of realized derivatives, and higher costs associated with maintenance activity in the second quarter of 2025 compared to the second quarter of 2024.
Gross Margin. Gross margin in our UAN segment increased by $54 million, or 25%, to $270 million in the second quarter of 2025 from $216 million in the second quarter of 2024, and our gross margin percentage was 44.3% in the second quarter of 2025 compared to 45.5% in the second quarter of 2024. The increase in gross margin was due primarily to an 18% increase in average selling prices, which increased gross margin by $86 million, and a 9% increase in sales volume, which increased gross margin by $32 million. These factors that increased gross margin were partially offset by an increase in realized natural gas costs, including the impact of realized derivatives, which reduced gross margin by $43 million, and a net increase in manufacturing, maintenance and other costs, which decreased gross margin by $21 million.
Six Months Ended June 30, 2025 Compared to Six Months Ended June 30, 2024
Net Sales. Net sales in our UAN segment increased $180 million, or 20%, to $1.08 billion in the six months ended June 30, 2025 from $900 million in the six months ended June 30, 2024 due primarily to a 12% increase in sales volume and a 7% increase in average selling prices. The increase in sales volume was due primarily to inventory drawdown to meet strong domestic and international demand and higher supply availability as a result of higher production in the six months ended June 30, 2025 compared to the six months ended June 30, 2024 and higher beginning inventory entering 2025. Average selling prices
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increased to $286 per ton in the six months ended June 30, 2025 compared to $268 per ton in the six months ended June 30, 2024 due primarily to higher global energy costs, which raised the global market clearing price required to meet global demand.
Cost of Sales. Cost of sales in our UAN segment averaged $177 per ton in the six months ended June 30, 2025, a 10% increase from $161 per ton in the six months ended June 30, 2024, due primarily to higher realized natural gas costs, including the impact of realized derivatives.
Gross Margin. Gross margin in our UAN segment increased by $53 million, or 15%, to $412 million in the six months ended June 30, 2025 from $359 million in the six months ended June 30, 2024, and our gross margin percentage was 38.1% in the six months ended June 30, 2025 compared to 39.9% in the six months ended June 30, 2024. The increase in gross margin was due primarily to a 7% increase in average selling prices, which increased gross margin by $63 million, and a 12% increase in sales volume, which increased gross margin by $63 million. These factors that increased gross margin were partially offset by an increase in realized natural gas costs, including the impact of realized derivatives, which reduced gross margin by $59 million, and a net increase in manufacturing, maintenance and other costs, which decreased gross margin by $3 million. Gross margin also includes the impact of a $1 million unrealized net mark-to-market loss on natural gas derivatives in the six months ended June 30, 2025 compared to a $10 million gain in the six months ended June 30, 2024.
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 extensively by the commercial explosives industry as a component of explosives. AN is produced at our Yazoo City and Billingham complexes.
The following table presents summary operating data for our AN segment:
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||||||||||||||||||||||||||
| 2025 | 2024 | 2025 v. 2024 | 2025 | 2024 | 2025 v. 2024 | ||||||||||||||||||||||||||||||||||||||||||
| (dollars in millions, except per ton amounts) | |||||||||||||||||||||||||||||||||||||||||||||||
| Net sales | $ | 117 | $ | 98 | $ | 19 | 19 | % | $ | 218 | $ | 212 | $ | 6 | 3 | % | |||||||||||||||||||||||||||||||
| Cost of sales | 92 | 75 | 17 | 23 | % | 177 | 180 | (3) | (2) | % | |||||||||||||||||||||||||||||||||||||
| Gross margin | $ | 25 | $ | 23 | $ | 2 | 9 | % | $ | 41 | $ | 32 | $ | 9 | 28 | % | |||||||||||||||||||||||||||||||
| Gross margin percentage | 21.4 | % | 23.5 | % | (2.1) | % | 18.8 | % | 15.1 | % | 3.7 | % | |||||||||||||||||||||||||||||||||||
| Sales volume by product tons (000s) | 378 | 340 | 38 | 11 | % | 706 | 730 | (24) | (3) | % | |||||||||||||||||||||||||||||||||||||
Sales volume by nutrient tons (000s)(1) | 130 | 116 | 14 | 12 | % | 243 | 250 | (7) | (3) | % | |||||||||||||||||||||||||||||||||||||
| Average selling price per product ton | $ | 310 | $ | 288 | $ | 22 | 8 | % | $ | 309 | $ | 290 | $ | 19 | 7 | % | |||||||||||||||||||||||||||||||
Average selling price per nutrient ton(1) | $ | 900 | $ | 845 | $ | 55 | 7 | % | $ | 897 | $ | 848 | $ | 49 | 6 | % | |||||||||||||||||||||||||||||||
| Gross margin per product ton | $ | 66 | $ | 68 | $ | (2) | (3) | % | $ | 58 | $ | 44 | $ | 14 | 32 | % | |||||||||||||||||||||||||||||||
Gross margin per nutrient ton(1) | $ | 192 | $ | 198 | $ | (6) | (3) | % | $ | 169 | $ | 128 | $ | 41 | 32 | % | |||||||||||||||||||||||||||||||
| Depreciation and amortization | $ | 10 | $ | 7 | $ | 3 | 43 | % | $ | 18 | $ | 20 | $ | (2) | (10) | % | |||||||||||||||||||||||||||||||
| Unrealized net mark-to-market gain on natural gas derivatives | $ | — | $ | — | $ | — | — | % | $ | — | $ | (1) | $ | 1 | 100 | % | |||||||||||||||||||||||||||||||
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(1)AN represents between 29% and 35% of nitrogen content. Nutrient tons represent the tons of nitrogen within the product tons.
Second Quarter of 2025 Compared to Second Quarter of 2024
Net Sales. Net sales in our AN segment increased $19 million, or 19%, to $117 million in the second quarter of 2025 from $98 million in the second quarter of 2024 due to an 8% increase in average selling prices and an 11% increase in sales volume. Average selling prices increased to $310 per ton in the second quarter of 2025 compared to $288 per ton in the second quarter of 2024 as higher global energy costs raised the global market clearing price required to meet global demand. Sales volume was higher due primarily to higher beginning inventory entering the second quarter of 2025.
Cost of Sales. Cost of sales in our AN segment averaged $244 per ton in the second quarter of 2025, an 11% increase from $220 per ton in the second quarter of 2024. The increase was due primarily to higher realized natural gas costs, including the impact of realized derivatives.
Gross Margin. Gross margin in our AN segment increased $2 million, or 9%, to $25 million in the second quarter of 2025 from $23 million in the second quarter of 2024, and our gross margin percentage was 21.4% in the second quarter of 2025
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compared to 23.5% in the second quarter of 2024. The increase in gross margin was due primarily to an 8% increase in average selling prices, which increased gross margin by $11 million, and an 11% increase in sales volume, which increased gross margin by $5 million. These factors that increased gross margin were partially offset by an increase in realized natural gas costs, including the impact of realized derivatives, which reduced gross margin by $7 million, and a net increase in manufacturing, maintenance and other costs, which decreased gross margin by $7 million.
Six Months Ended June 30, 2025 Compared to Six Months Ended June 30, 2024
Net Sales. Net sales in our AN segment increased $6 million, or 3%, to $218 million in the six months ended June 30, 2025 from $212 million in the six months ended June 30, 2024 due to a 7% increase in average selling prices, partially offset by a 3% decrease in sales volume. Average selling prices increased to $309 per ton in the six months ended June 30, 2025 compared to $290 per ton in the six months ended June 30, 2024 as higher global energy costs raised the global market clearing price required to meet global demand. Sales volume was lower due primarily to lower supply availability due to lower beginning inventory entering 2025 and lower production in the six months ended June 30, 2025.
Cost of Sales. Cost of sales in our AN segment averaged $251 per ton in the six months ended June 30, 2025, a 2% increase from $246 per ton in the six months ended June 30, 2024. The increase was due primarily to higher realized natural gas costs, including the impact of realized derivatives, partially offset by lower costs for maintenance activity in North America.
Gross Margin. Gross margin in our AN segment increased $9 million, or 28%, to $41 million in the six months ended June 30, 2025 from $32 million in the six months ended June 30, 2024, and our gross margin percentage was 18.8% in the six months ended June 30, 2025 compared to 15.1% in the six months ended June 30, 2024. The increase in gross margin was due primarily to a 7% increase in average selling prices, which increased gross margin by $14 million, a net decrease in manufacturing, maintenance and other costs, which increased gross margin by $3 million, and favorable product mix, which increased gross margin by $2 million. These factors that increased gross margin were partially offset by an increase in realized natural gas costs, including the impact of realized derivatives, which reduced gross margin by $9 million. Gross margin also includes the impact of a $1 million unrealized net mark-to-market gain on natural gas derivatives in the six months ended June 30, 2024.
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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% high-purity urea as a chemical 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 June 30, | Six Months Ended June 30, | ||||||||||||||||||||||||||||||||||||||||||||||
| 2025 | 2024 | 2025 v. 2024 | 2025 | 2024 | 2025 v. 2024 | ||||||||||||||||||||||||||||||||||||||||||
| (dollars in millions, except per ton amounts) | |||||||||||||||||||||||||||||||||||||||||||||||
| Net sales | $ | 125 | $ | 133 | $ | (8) | (6) | % | $ | 258 | $ | 255 | $ | 3 | 1 | % | |||||||||||||||||||||||||||||||
| Cost of sales | 80 | 67 | 13 | 19 | % | 158 | 151 | 7 | 5 | % | |||||||||||||||||||||||||||||||||||||
| Gross margin | $ | 45 | $ | 66 | $ | (21) | (32) | % | $ | 100 | $ | 104 | $ | (4) | (4) | % | |||||||||||||||||||||||||||||||
| Gross margin percentage | 36.0 | % | 49.6 | % | (13.6) | % | 38.8 | % | 40.8 | % | (2.0) | % | |||||||||||||||||||||||||||||||||||
| Sales volume by product tons (000s) | 466 | 557 | (91) | (16) | % | 996 | 1,070 | (74) | (7) | % | |||||||||||||||||||||||||||||||||||||
Sales volume by nutrient tons (000s)(1) | 94 | 109 | (15) | (14) | % | 200 | 208 | (8) | (4) | % | |||||||||||||||||||||||||||||||||||||
| Average selling price per product ton | $ | 268 | $ | 239 | $ | 29 | 12 | % | $ | 259 | $ | 238 | $ | 21 | 9 | % | |||||||||||||||||||||||||||||||
Average selling price per nutrient ton(1) | $ | 1,330 | $ | 1,220 | $ | 110 | 9 | % | $ | 1,290 | $ | 1,226 | $ | 64 | 5 | % | |||||||||||||||||||||||||||||||
| Gross margin per product ton | $ | 97 | $ | 118 | $ | (21) | (18) | % | $ | 100 | $ | 97 | $ | 3 | 3 | % | |||||||||||||||||||||||||||||||
Gross margin per nutrient ton(1) | $ | 479 | $ | 606 | $ | (127) | (21) | % | $ | 500 | $ | 500 | $ | — | — | % | |||||||||||||||||||||||||||||||
| Depreciation and amortization | $ | 17 | $ | 13 | $ | 4 | 31 | % | $ | 30 | $ | 33 | $ | (3) | (9) | % | |||||||||||||||||||||||||||||||
| Unrealized net mark-to-market gain on natural gas derivatives | $ | — | $ | (1) | $ | 1 | 100 | % | $ | — | $ | (2) | $ | 2 | 100 | % | |||||||||||||||||||||||||||||||
(1)Nutrient tons represent the tons of nitrogen within the product tons.
Second Quarter of 2025 Compared to Second Quarter of 2024
Net Sales. Net sales in our Other segment decreased by $8 million, or 6%, to $125 million in the second quarter of 2025 from $133 million in the second quarter of 2024 due to a 16% decrease in sales volume, partially offset by a 12% increase in average selling prices. The decrease in sales volume primarily reflected lower DEF and nitric acid shipments. Average selling prices increased by 12% as higher global energy costs raised the global market clearing price required to meet global demand.
Cost of Sales. Cost of sales in our Other segment averaged $171 per ton in the second quarter of 2025, a 41% increase from $121 per ton in the second quarter of 2024, due primarily to higher costs associated with maintenance activity, and higher realized natural gas costs, including the impact of realized derivatives, in the second quarter of 2025 compared to the second quarter of 2024.
Gross Margin. Gross margin in our Other segment decreased by $21 million, or 32%, to $45 million in the second quarter of 2025 from $66 million in the second quarter of 2024, and our gross margin percentage was 36.0% in the second quarter of 2025 compared to 49.6% in the second quarter of 2024. The decrease in gross margin was due primarily to a net increase in manufacturing, maintenance and other costs, which decreased gross margin by $14 million, a 16% decrease in sales volume, which decreased gross margin by $14 million, and an increase in realized natural gas costs, including the impact of realized derivatives, which decreased gross margin by $5 million. These factors that decreased gross margin were partially offset by a 12% increase in average selling prices, which increased gross margin by $13 million. Gross margin also includes the impact of a $1 million unrealized net mark-to-market gain on natural gas derivatives in the second quarter of 2024.
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Six Months Ended June 30, 2025 Compared to Six Months Ended June 30, 2024
Net Sales. Net sales in our Other segment increased by $3 million, or 1%, to $258 million in the six months ended June 30, 2025 from $255 million in the six months ended June 30, 2024 due to a 9% increase in average selling prices, partially offset by a 7% decrease in sales volume. Average selling prices increased as higher global energy costs raised the global market clearing price required to meet global demand. The decrease in sales volume was due primarily to lower nitric acid and DEF sales volume.
Cost of Sales. Cost of sales in our Other segment averaged $159 per ton in the six months ended June 30, 2025, a 13% increase from $141 per ton in the six months ended June 30, 2024, due primarily to the impact of higher realized natural gas costs, including the impact of realized derivatives, and higher costs associated with maintenance activity in the six months ended June 30, 2025 compared to the six months ended June 30, 2024.
Gross Margin. Gross margin in our Other segment decreased by $4 million, or 4%, to $100 million in the six months ended June 30, 2025 from $104 million in the six months ended June 30, 2024, and our gross margin percentage was 38.8% in the six months ended June 30, 2025 compared to 40.8% in the six months ended June 30, 2024. The decrease in gross margin was due primarily to a 7% decrease in sales volume, which decreased gross margin by $10 million, an increase in realized natural gas costs, including the impact of realized derivatives, which decreased gross margin by $8 million, and a net increase in manufacturing, maintenance and other costs, which decreased gross margin by $3 million. These factors that decreased gross margin were partially offset by a 9% increase in average selling prices, which increased gross margin by $19 million. Gross margin also includes the impact of a $2 million unrealized net mark-to-market gain on natural gas derivatives in the six months ended June 30, 2024.
Liquidity and Capital Resources
Our primary uses of cash are generally for operating costs, working capital, capital expenditures, debt service, investments, taxes, share repurchases, dividends, and our clean energy initiatives. 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. At June 30, 2025, 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.
As of June 30, 2025, our cash and cash equivalents balance was $1.69 billion, an increase of $72 million from $1.61 billion at December 31, 2024, and consisted of the following:
| June 30, 2025 | December 31, 2024 | ||||||||||
| (in millions) | |||||||||||
| Cash and cash equivalents, excluding amounts related to Blue Point Number One, LLC | $ | 1,422 | $ | 1,614 | |||||||
| Cash and cash equivalents—Blue Point Number One, LLC | 264 | — | |||||||||
| Total cash and cash equivalents | $ | 1,686 | $ | 1,614 | |||||||
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.
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Blue Point Joint Venture
On April 8, 2025, we announced that we formed a joint venture, Blue Point Number One, LLC, with JERA and Mitsui for the construction, production and offtake of low-carbon ammonia. We hold 40% ownership, JERA holds 35% ownership, and Mitsui holds 25% ownership in the Blue Point joint venture. Under the terms of the Blue Point joint venture’s limited liability company agreement, JERA has a conditional option to reduce its ownership percentage that expires on December 31, 2025. If the specified condition is met, JERA can reduce its ownership below 35% but not lower than 20%. We would have the right and obligation to increase our ownership by the same amount that JERA reduces its ownership.
At our Blue Point complex in Ascension Parish, Louisiana, the Blue Point joint venture is expected to construct an ATR ammonia production facility with a CO2 dehydration and compression unit to prepare captured CO2 for transportation and sequestration. Engineering, equipment procurement and pre-construction activities at our Blue Point complex began in the second quarter of 2025. Construction of the ammonia production facility is expected to begin in 2026, with low-carbon ammonia production expected to begin in 2029.
We estimate that the cost of the low-carbon ATR ammonia production facility with CCS technologies will be approximately $3.7 billion. We anticipate that approximately one-third of the estimated cost is related to materials that will be imported to the United States, with the majority of imported materials expected to arrive in Louisiana in 2028. Pursuant to periodic capital calls, the Blue Point joint venture members will fund the cost of the facility’s engineering, procurement and construction according to their respective ownership percentages. During the second quarter of 2025, we, JERA and Mitsui made initial capital contributions of $157 million, $137 million and $98 million, respectively, to the Blue Point joint venture. We funded $114 million of our contribution with cash and $43 million through a non-cash contribution of a license to use certain intellectual property.
In June 2025, the Blue Point joint venture executed agreements, including a long-term supply agreement, for a subsidiary of Linde plc to design, construct, own, operate and maintain an ASU at our Blue Point complex to supply oxygen and nitrogen to the low-carbon ATR ammonia production facility, eliminating the need for the Blue Point joint venture to construct an ASU. As a result, the total projected cost of the low-carbon ATR ammonia production facility was reduced from approximately $4.0 billion to $3.7 billion.
In addition, we will invest approximately $550 million to build scalable infrastructure at our Blue Point complex to supply the ammonia production facility with services, including product storage and vessel loading. This infrastructure will be constructed with a similar timeline as the ammonia production facility noted above.
See “Overview of CF Holdings—Our Strategy—Blue Point joint venture,” above, and Note 12—Variable Interest Entity, for additional information on the Blue Point joint venture.
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 $377 million in the first six months of 2025 compared to $182 million in the first six months of 2024. Our capital expenditures for the first six months of 2025 included $90 million related to the Blue Point joint venture.
The Blue Point joint venture is consolidated in our financial statements, including our statements of cash flows. We currently anticipate that our consolidated capital expenditures for the full year 2025 to be in the range of $800 million to $900 million, consisting of approximately $500 million for our existing operations and approximately $300 million to $400 million representing the Blue Point joint venture’s planned capital expenditures related to construction of the low-carbon ATR ammonia production facility at our Blue Point complex. Also, we anticipate our 2025 capital spending will include up to $25 million related to our construction of the Blue Point complex scalable infrastructure.
Of the Blue Point joint venture’s $300 million to $400 million of planned 2025 capital expenditures, approximately $120 million to $160 million has been, and is expected to be, funded by us, representing our 40% equity interest in the Blue Point joint venture, and approximately $180 million to $240 million has been, and is expected to be, funded by our partners in the joint venture, representing their combined 60% equity interest in the Blue Point joint venture.
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, engineering and construction change orders, performance of third parties, delays in the receipt of equipment, adverse weather, defects in materials and workmanship, labor or material shortages, impact of tariffs, retaliatory measures or other changes in trade policy, transportation constraints, acceleration or delays in the timing of the work and other unforeseen difficulties. Any of these changes in planned capital
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expenditures, individually or in the aggregate, could have a material impact on our results of operations and cash flows. See “—Forward-Looking Statements” for additional risks related to our planned capital expenditures.
Share Repurchase Programs
Our Board of Directors (the Board) has authorized certain programs to repurchase shares of our common stock. These programs have generally permitted repurchases to be made from time to time in the open market, through privately-negotiated transactions, through block transactions, through accelerated share repurchase programs 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.
On November 2, 2022, the Board authorized the repurchase of up to $3 billion of CF Holdings common stock (the 2022 Share Repurchase Program), which commenced in the second quarter of 2023 upon completion of our previous share repurchase program and is effective through December 31, 2025. On May 6, 2025, the Board authorized the repurchase of up to $2 billion of CF Holdings common stock commencing upon the completion of the 2022 Share Repurchase Program and effective through December 31, 2029. The following table summarizes the share repurchases under the 2022 Share Repurchase Program.
______________________________________________________________________________
| Shares | Amounts(1) | ||||||||||||||||||||||
| (in millions) | |||||||||||||||||||||||
| Shares repurchased in 2023 | 5.6 | $ | 425 | ||||||||||||||||||||
| Shares repurchased in 2024: | |||||||||||||||||||||||
| First quarter | 4.3 | 347 | |||||||||||||||||||||
| Second quarter | 4.0 | 305 | |||||||||||||||||||||
| Third quarter | 6.1 | 476 | |||||||||||||||||||||
| Fourth quarter | 4.4 | 385 | |||||||||||||||||||||
| Total shares repurchased in 2024 | 18.8 | 1,513 | |||||||||||||||||||||
| Shares repurchased in 2025: | |||||||||||||||||||||||
| First quarter | 5.4 | 434 | |||||||||||||||||||||
| Second quarter | 2.8 | 202 | |||||||||||||||||||||
| Total shares repurchased in 2025 | 8.2 | 636 | |||||||||||||||||||||
Shares repurchased as of June 30, 2025 | 32.6 | $ | 2,574 | ||||||||||||||||||||
(1)As defined in the 2022 Share Repurchase Program, amounts reflect the price paid for the shares of common stock repurchased, excluding commissions paid to brokers and excise taxes.
In the six months ended June 30, 2025, we repurchased approximately 8.2 million shares under the 2022 Share Repurchase Program for $636 million. In the six months ended June 30, 2024, we repurchased approximately 8.3 million shares under the 2022 Share Repurchase Program for $652 million, of which $14 million was accrued and unpaid as of June 30, 2024.
Canada Revenue Agency Competent Authority Matter
In the second half of 2022, as a result of the conclusion of arbitration proceedings and the settlement provisions between the United States and Canadian competent authorities related to tax years 2006 through 2011, we paid additional income taxes and related interest of $124 million and $100 million, respectively, to the Canada Revenue Agency (CRA) and Alberta Tax and Revenue Administration (Alberta TRA). In the third quarter of 2024, we were informed that the CRA granted us discretionary interest relief for certain tax years from 2006 through 2011. In the fourth quarter of 2024, we received interest relief from the CRA consisting of interest refunds of $21 million and related interest of $2 million. In addition, interest relief from the Alberta TRA is estimated to be approximately $16 million, consisting of interest refunds of $15 million and related interest of $1 million, based on current estimates and foreign currency exchange rates as of June 30, 2025. We expect to receive the interest refunds from the Alberta TRA in the second half of 2025.
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Debt
Revolving Credit Agreement
We have a senior unsecured revolving credit agreement (the Revolving Credit Agreement), which 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. Borrowings under the 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 Revolving Credit Agreement.
Borrowings under the Revolving Credit Agreement can be denominated in U.S. dollars, Canadian dollars, euros and British pounds. Borrowings in U.S. dollars bear interest at a per annum rate equal to, at our option, an applicable 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 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. The Revolving Credit Agreement contains representations and warranties and affirmative and negative covenants, including one financial covenant.
As of June 30, 2025, we had unused borrowing capacity under the Revolving Credit Agreement of $750 million and no outstanding letters of credit under the Revolving Credit Agreement. In addition, there were no borrowings outstanding under the Revolving Credit Agreement as of December 31, 2024, or during the six months ended June 30, 2025 or 2024.
Letters of Credit Under Bilateral Agreement
We are party to a bilateral agreement providing for the issuance of up to $425 million of letters of credit. As of June 30, 2025, approximately $342 million of letters of credit were outstanding under this agreement.
Senior Notes
Long-term debt presented on our consolidated balance sheets as of June 30, 2025 and December 31, 2024 consisted of the following debt securities issued by CF Industries:
| Effective Interest Rate | June 30, 2025 | December 31, 2024 | |||||||||||||||||||||||||||
| Principal Outstanding | Carrying Amount(1) | Principal Outstanding | Carrying Amount(1) | ||||||||||||||||||||||||||
| (in millions) | |||||||||||||||||||||||||||||
| Public Senior Notes: | |||||||||||||||||||||||||||||
| 5.150% due March 2034 | 5.293% | $ | 750 | $ | 743 | $ | 750 | $ | 742 | ||||||||||||||||||||
| 4.950% due June 2043 | 5.040% | 750 | 742 | 750 | 742 | ||||||||||||||||||||||||
| 5.375% due March 2044 | 5.478% | 750 | 741 | 750 | 741 | ||||||||||||||||||||||||
| Senior Secured Notes: | |||||||||||||||||||||||||||||
4.500% due December 2026(2) | 4.783% | 750 | 747 | 750 | 746 | ||||||||||||||||||||||||
| Total long-term debt | $ | 3,000 | $ | 2,973 | $ | 3,000 | $ | 2,971 | |||||||||||||||||||||
_______________________________________________________________________________
(1)Carrying amount is net of unamortized debt discount and deferred debt issuance costs. Total unamortized debt discount was $5 million and $6 million as of June 30, 2025 and December 31, 2024, respectively, and total deferred debt issuance costs were $22 million and $23 million as of June 30, 2025 and December 31, 2024, respectively.
(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 (the Public Senior Notes) and the 4.500% senior secured notes due December 2026 (the 2026 Notes), each series of notes is guaranteed by CF Holdings.
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.
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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 June 30, 2025 and December 31, 2024, we had $32 million and $118 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. Additionally, borrowing under the 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
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. Volatility in reported quarterly earnings can result from the unrealized mark-to-market adjustments in the value of the derivatives. As of June 30, 2025, our open natural gas derivative contracts consisted of natural gas basis swaps for 13.6 million MMBtus of natural gas. As of December 31, 2024, our open natural gas derivative contracts consisted of natural gas fixed price swaps and basis swaps for 16.0 million MMBtus of natural gas.
Defined Benefit Pension Plans
We did not contribute any amounts to our pension plans in the six months ended June 30, 2025. Over the remainder of 2025, we expect to contribute approximately $7 million to our pension plans. In 2026 and 2027, we expect to contribute approximately $15 million and $4 million, respectively, to our U.K. pension plans, as currently agreed with the plans’ trustees.
Distributions to Noncontrolling Interest in CFN
On January 31, 2025, CFN distributed $129 million to CHS for the distribution period ended December 31, 2024. On July 31, 2025, the CFN Board of Managers approved semi-annual distribution payments for the distribution period ended June 30, 2025 in accordance with CFN’s limited liability company agreement, and CFN distributed $175 million to CHS for this distribution period.
Cash Flows
Net cash provided by operating activities during the first six months of 2025 was $1.15 billion, an increase of $229 million, compared to $920 million in the first six months of 2024. The increase in cash flow from operations was due primarily to an increase in gross margin, driven by higher sales volume and increased average selling prices, partially offset by higher natural gas costs.
Net cash used in investing activities was $368 million in the first six months of 2025 compared to $134 million in the first six months of 2024. Capital expenditures totaled $377 million during the first six months of 2025 compared to $182 million in the first six months of 2024. Our capital expenditures for the first six months of 2025 included $90 million related to the Blue Point joint venture.
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Net cash used in financing activities was $733 million in the first six months of 2025 compared to $998 million in the first six months of 2024. The decrease was due primarily to contributions from noncontrolling interests of $235 million in the first six months of 2025 and a decrease in dividends paid on common stock due to lower shares outstanding as a result of common shares repurchased under our share repurchase program. In the first six months of 2025, dividends paid on common stock was $167 million compared to $188 million in the first six months of 2024.
Critical Accounting Estimates
During the first six months of 2025, 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, 2024.
Recent Accounting Pronouncements
See Note 2—New Accounting Standards for a discussion of recent accounting pronouncements.
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 use 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. 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 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, 2024, filed with the SEC on February 20, 2025. Such factors include, among others:
•our ability to complete the projects at our Blue Point complex, including the construction of a low-carbon ammonia production facility with our joint venture partners and scalable infrastructure on schedule and on budget or at all;
•our ability to fund the capital expenditure needs related to the joint venture at our Blue Point complex, which may exceed our current estimates;
•the cyclical nature of our business and the impact of global supply and demand on our selling prices and operating results;
•the global commodity nature of our nitrogen products, the conditions in the global market for nitrogen products, and the intense global competition from other producers;
•announced or future tariffs, retaliatory measures, and global trade relations, including the potential impact of tariffs and retaliatory measures on the price and availability of materials for our capital projects and maintenance;
•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 globally;
•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 or utilities, 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;
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•the significant risks and hazards involved in producing and handling our products against which we may not be fully insured;
•risks associated with international operations;
•our ability to manage our indebtedness and any additional indebtedness that may be incurred;
•risks associated with changes in tax laws and adverse determinations by taxing authorities, including any potential changes in tax regulations and our qualification for tax credits;
•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, including announced or future changes in environmental or climate change laws;
•the development and growth of the market for low-carbon ammonia and the risks and uncertainties relating to the development and implementation of our low-carbon ammonia projects;
•risks associated with investments in and expansions of our business, including unanticipated adverse consequences and the significant resources that could be required; and
•failure of technologies to perform, develop or be available as expected, including the low-carbon ATR ammonia production facility with carbon capture and sequestration technologies being constructed at our Blue Point complex.
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.
See Item 7A of our Annual Report on Form 10-K for the fiscal year ended December 31, 2024 for information on our market risk exposure due to changes in commodity prices, interest rates and foreign currency exchange rates, and our utilization of natural gas derivatives and an analysis of the sensitivity of these derivatives. As of June 30, 2025, we had natural gas derivative contracts for 13.6 million MMBtus covering certain periods through March 2026.
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 a new procurement and plant asset management system, which began in the second quarter of 2025, 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 June 30, 2025 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.
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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 June 30, 2025.
| 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) | |||||||||||||||||||
| April 1, 2025 - April 30, 2025 | 2,562,542 | (3) | $ | 73.27 | 2,562,394 | $ | 440,347 | ||||||||||||||||
| May 1, 2025 - May 31, 2025 | 93,878 | (4) | 79.43 | 93,827 | 432,894 | ||||||||||||||||||
| June 1, 2025 - June 30, 2025 | 72,925 | (5) | 95.01 | 69,158 | 426,350 | ||||||||||||||||||
| Total | 2,729,345 | $ | 74.06 | 2,725,379 | |||||||||||||||||||
_______________________________________________________________________________
(1)Average price paid per share of CF Industries Holdings, Inc. (CF Holdings) common stock repurchased under the 2022 Share Repurchase Program, as defined below, is the execution price, excluding commissions paid to brokers and excise taxes.
(2)On November 2, 2022, we announced that our Board of Directors (the Board) authorized the repurchase of up to $3 billion of CF Holdings common stock, which is effective through December 31, 2025 (the 2022 Share Repurchase Program). On May 6, 2025, we announced that the Board authorized the repurchase of up to $2 billion of CF Holdings common stock commencing upon completion of the 2022 Share Repurchase Program and effective through December 31, 2029. These share repurchase programs are 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 14—Stockholders’ Equity, in the Notes to Unaudited Consolidated Financial Statements included in Item 1. Financial Statements in Part I of this Quarterly Report on Form 10-Q.
(3)Includes 148 shares withheld to pay employee tax obligations upon the lapse of restrictions on restricted stock units.
(4)Includes 51 shares withheld to pay employee tax obligations upon the lapse of restrictions on restricted stock units.
(5)Includes 3,767 shares withheld to pay employee tax obligations upon the lapse of restrictions on restricted stock units.
ITEM 5. OTHER INFORMATION.
During the quarter ended June 30, 2025, 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 terminated
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 below. | ||||||||
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EXHIBIT INDEX
| Exhibit No. | Description | ||||
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 June 30, 2025, 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 (embed within the Inline XBRL document and included in Exhibit 101) | ||||
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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: August 7, 2025 | By: | /s/ W. ANTHONY WILL | |||||||||
W. Anthony Will President and Chief Executive Officer (Principal Executive Officer) | |||||||||||
| Date: August 7, 2025 | By: | /s/ GREGORY D. CAMERON | |||||||||
Gregory D. Cameron Executive Vice President and Chief Financial Officer (Principal Financial Officer) | |||||||||||
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FAQ
How did CF Industries' Q2 2025 revenue compare with Q2 2024?
Net sales increased 20% to $1.89 billion, driven by higher volumes and pricing in Ammonia and UAN.
What was CF (CF) diluted EPS for the quarter ended 30 Jun 2025?
Diluted EPS was $2.37, up 3% from $2.30 a year earlier, aided by share repurchases.
How much cash does CF Industries have on its balance sheet?
Cash and cash equivalents totaled $1.69 billion as of 30 Jun 2025, up from $1.61 billion at year-end.
What is the status of CF's carbon-capture projects?
The Donaldsonville CCS unit began operating in July 2025; Yazoo City CCS is slated for 2028.
What is the Blue Point joint venture mentioned in CF's 10-Q?
Formed with JERA (35%) and Mitsui (25%), the JV will build a $3.7 billion low-carbon ammonia plant targeting 2029 start-up; CF holds 40%.
CF Industries
NYSE:CF
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14.56B
160.86M
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104.42%
4.92%
Agricultural Inputs
Agricultural Chemicals
United States
NORTHBROOK