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CFCF Industries

Materials · Fertilizers · NYSE
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The 10-K against last year's

293 changes: 75 added, 31 removed, 186 reworded, 1 quiet changes

10-K Feb 25, 2026 vs Feb 20, 2025
Risk FactorsRedline ↓
11.4%
of the text changed · 14,139 words now
41.2%
of the text changed · 18,579 words now
Accounting PoliciesRedline ↓
12.1%
of the text changed · 3,338 words now

10-K 0001324404-26-000007 (2026-02-25) vs 10-K 0001324404-25-000006 (2025-02-20) Not compared: Legal Proceedings.

The redline

The paragraph that changed most in each section

Marked against last year's 10-K: cut words struck through, new words highlighted and underlined.

MD&A 238 words changed in this paragraph; it is 35% similar to last year's version.
Our reportable segment structure reflects how our chief operating decision maker, as defined in accounting principles generally accepted in the United States (U.S. GAAP), assesses the performance segments consist of our reportable segments Ammonia, Granular Urea, UAN, AN and makes decisions about resource allocation. 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(1) Granular Urea(2) UAN(2) AN(2) Other(2) Consolidated (in millions) Year ended December 31, 2024 Net sales $ 1,736 $ 1,600 $ 1,678 $ 419 $ 503 $ 5,936 Cost of sales 1,243 926 1,069 340 302 3,880 Gross margin $ 493 $ 674 $ 609 $ 79 $ 201 $ 2,056 Gross margin percentage 28.4 % 42.1 % 36.3 % 18.9 % 40.0 % 34.6 % Year ended December 31, 2023 Net sales $ 1,679 $ 1,823 $ 2,068 $ 497 $ 564 $ 6,631 Cost of sales 1,138 1,010 1,251 359 328 4,086 Gross margin $ 541 $ 813 $ 817 $ 138 $ 236 $ 2,545 Gross margin percentage 32.2 % 44.6 % 39.5 % 27.8 % 41.8 % 38.4 % Year ended December 31, 2022 Net sales $ 3,090 $ 2,892 $ 3,572 $ 845 $ 787 $ 11,186 Cost of sales 1,491 1,328 1,489 597 420 5,325 Gross margin $ 1,599 $ 1,564 $ 2,083 $ 248 $ 367 $ 5,861 Gross margin percentage 51.7 % 54.1 % 58.3 % 29.3 % 46.6 % 52.4 % See Note 21—Segment Disclosures for additional information.

Source: Item 7, 10-K 0001324404-26-000007 vs Item 7, 10-K 0001324404-25-000006

Risk Factors 117 words changed in this paragraph; it is 65% similar to last year's version.
arrangements we may enter into may involve significant risks and uncertainties, including the ability of us and our strategic partners to cooperate, us and our strategic partners having inconsistent interests or goals, ours and our partners ability to realize tax, financial and other programs incentivizing low-carbon production, and the potential that our strategic partners may be unable or unwilling to meet their financial or other obligations to the joint venture, which may negatively impact the expected benefits of the joint venture and cause us to incur additional expense or suffer reputational damage. In addition, due to the nature of these arrangements, we may have limited ability to direct or influence the management of the joint venture, which may limit our ability to assist and oversee the design and implementation of the joint venture’s business as well as its accounting, legal, governance, human resources, information technology, and other administrative systems. This may expose us to additional risks and uncertainties because we may be dependent upon and subject to liability, losses, or reputational damage relating to systems, controls, and personnel that are not under our control. These risks may be exacerbated when the joint venture is operating outside the United States due to geopolitical and political uncertainty and differences in language, culture, and regulation, as well as the factors listed above that are relevant to our international operations.

Source: Item 1A, 10-K 0001324404-26-000007 vs Item 1A, 10-K 0001324404-25-000006

Accounting Policies 96 words changed in this paragraph; it is 44% similar to last year's version.
Natural gas is the principal raw material used to produce nitrogen-based products. We manage the risk of changes in natural gas prices primarily through the use of derivative financial instruments. The derivative instruments that we use are primarily natural gas fixed price swaps, basis swaps and options traded in the over-the-counter (OTC) markets. The derivatives reference primarily a NYMEX futures price index, which represent the basis for fair value at any given time. These derivatives are traded in months forward and settlements are scheduled to coincide with anticipated gas purchases during those future periods. From time to time, we may also use derivative financial instruments to reduce our exposure to changes in foreign currency exchange rates. We do not use derivatives for trading purposes and are not a party to any leveraged derivatives.

Source: Item 8, Note 2 – Summary of Significant Accounting Policies, 10-K 0001324404-26-000007 vs Item 8, Note 2 – Summary of Significant Accounting Policies, 10-K 0001324404-25-000006

Every change, by type

Sentences and paragraphs added, removed or reworded

Sentences and paragraphs of CF's Risk Factors and MD&A, 10-K 2026-02-25 against 10-K 2025-02-20. Each links to the text at sec.gov.

RemovedRisk Factors
The EU finalized its overall carbon border adjustment mechanism in May 2023. During the interim phase, covering imports, including nitrogenous fertilizers, entering the EU from the fourth quarter of 2023 through the fourth quarter of 2025, importers must file quarterly reports on the emissions intensity of covered products. For imports that enter the EU starting in 2026, charges will be required for emissions over certain thresholds, with the EU still to set forth additional details. Other governments are also considering border taxes for carbon intensive products. The imposition of any such taxes may impact investment and trade flows, which could adversely impact our business.

Read it in 10-K 2025-02-20 at sec.gov ↗

RemovedMD&A
•decarbonizing our existing network to accelerate the availability of low-carbon ammonia and upgraded nitrogen products for traditional agricultural and industrial applications;

Read it in 10-K 2025-02-20 at sec.gov ↗

RemovedMD&A
Our decarbonization projects also include front-end engineering and design (FEED) studies to inform our evaluation of whether, and how best, to invest in export-oriented, low-carbon ammonia capacity at our Blue Point complex in Ascension Parish, Louisiana, to supply developing clean energy markets and traditional ammonia markets where demand for low-carbon product is emerging.

Read it in 10-K 2025-02-20 at sec.gov ↗

RemovedMD&A
In the fourth quarter of 2024, we received results from a FEED study evaluating the use of autothermal reforming (ATR) ammonia production technology alongside CCS to enable the production of low-carbon ammonia. ATR technology, when combined with CCS to capture and sequester process CO2 emissions, is expected to reduce CO2 emissions from the ammonia

Read it in 10-K 2025-02-20 at sec.gov ↗

RemovedMD&A
production process by more than 90% compared to conventional ammonia plants. The FEED study results estimate the costs of a project with these attributes to be approximately $4 billion for the approximately 1.4 million metric ton capacity greenfield ATR ammonia facility and CCS technologies. Additionally, we estimate approximately $500 million would be required for the scalable common infrastructure for our Blue Point complex, such as ammonia storage and a vessel loading dock.

Read it in 10-K 2025-02-20 at sec.gov ↗

Show the other 5
RemovedMD&A
We have entered into joint development agreements (JDAs) with two potential partners, Mitsui & Co., Ltd. and JERA Co., Inc. for the development of the greenfield low-carbon ammonia capacity. Our evaluation includes assessing whether the ammonia production technology under consideration will satisfy carbon intensity and other requirements for potential end users. Should a positive final investment decision (FID) be reached to construct greenfield low-carbon ammonia capacity at our Blue Point complex, construction and commissioning is expected to take approximately four years from a positive FID.

Read it in 10-K 2025-02-20 at sec.gov ↗

RemovedMD&A
In January 2024, a winter storm produced extremely cold temperatures that impacted our operations, including the temporary shut-down and lost production at certain of our plants. Due to the impact of plant downtime resulting from the adverse weather and additional plant maintenance activity in the first quarter of 2024, we purchased and resold approximately 62,000 tons of ammonia and 48,000 tons of granular urea at near breakeven margins in order to fulfill sales commitments. The plant downtime led to approximately $75 million of additional costs in the first quarter of 2024 for maintenance, repairs and certain unabsorbed fixed costs.

Read it in 10-K 2025-02-20 at sec.gov ↗

RemovedMD&A
In the first quarter of 2024, warmer-than-normal average temperatures in North America drove lower heating demand for natural gas, in spite of a short-lived period of extremely cold temperatures in January 2024 that affected most of North America. North American natural gas supply remained strong through the quarter, with a decline in supply occurring near the end of the quarter as producers responded to a weaker price environment. In addition, although the higher cost for natural gas outside of North America incentivized liquefaction facilities in the United States to export domestic natural gas during the first quarter of 2024, an outage at the Freeport liquefied natural gas facility limited total gas exports, supporting domestic supply.

Read it in 10-K 2025-02-20 at sec.gov ↗

RemovedMD&A
During the second quarter of 2024, there was a decline in natural gas supply as producers responded to a weaker price environment, limiting the domestic supply available to be injected into storage during the quarter. In addition, natural gas demand for power generation reached record levels in the second quarter of 2024 as higher-than-normal temperatures drove increased cooling demand.

Read it in 10-K 2025-02-20 at sec.gov ↗

RemovedMD&A
In the third quarter of 2024, the decline in natural gas supply continued as producers curtailed production in response to low natural gas prices. Natural gas demand from the power generation sector set records despite increased solar and wind generation, as low natural gas prices increased demand for gas-fired power. Liquefied natural gas exports were steady through the quarter as delays on commissioning of new facilities and maintenance activities at existing plants held exports at levels reached during the second quarter of 2024. Natural gas in storage remained above historical levels despite continued below-average injections into storage during the third quarter.

Read it in 10-K 2025-02-20 at sec.gov ↗

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