UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
Form 10-Q | | | | | | | | |
| (Mark One) |
| ☑ | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
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| For the quarterly period ended | JuneSeptember 30, 2022 |
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| OR |
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| ☐ | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
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For the transition period from to |
Commission file number: 001-33492
CVR ENERGY, INC.
(Exact name of registrant as specified in its charter) | | | | | | | | | | | | | | |
| Delaware | | | | 61-1512186 |
(State or other jurisdiction of incorporation or organization) | | | (I.R.S. Employer
Identification No.) |
2277 Plaza Drive, Suite 500, Sugar Land, Texas 77479
(Address of principal executive offices) (Zip Code)
(281) 207-3200
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
| | | | | | | | |
| Title of each class | Trading Symbol(s) | Name of each exchange on which registered |
| Common Stock, $0.01 par value per share | CVI | The New York Stock Exchange |
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☑ No ☐
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☑ No ☐
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
| | | | | | | | | | | | | | | | | |
| Large accelerated filer | ☐ | Accelerated filer | ☑ | Non-accelerated filer | ☐ |
| Smaller reporting company | ☐ | Emerging growth company | ☐ | | |
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Indicate by check mark whether the registrant is a shell company (as defined by Rule 12b-2 of the Exchange Act). Yes ☐ No ☑
There were 100,530,599 shares of the registrant’s common stock outstanding at July 29,October 28, 2022.
TABLE OF CONTENTS
CVR Energy, Inc. - Quarterly Report on Form 10-Q
JuneSeptember 30, 2022
| | PART I. Financial Information | PART I. Financial Information | | PART II. Other Information | | PART I. Financial Information | | PART II. Other Information | |
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This Quarterly Report on Form 10-Q (including documents incorporated by reference herein) contains statements with respect to our expectations or beliefs as to future events. These types of statements are “forward-looking” and subject to uncertainties. See “Important Information Regarding Forward-Looking Statements” section of this filing.
JuneSeptember 30, 2022 | 2
Important Information Regarding Forward-Looking Statements
This Quarterly Report on Form 10-Q (this “Report”) contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), including, but not limited to, those under Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations. These forward-looking statements are subject to a number of risks and uncertainties, many of which are beyond our control. All statements other than statements of historical fact, including without limitation, statements regarding future operations, financial position, estimated revenues and losses, growth, capital projects, stock or unit repurchases, impacts of legal proceedings, projected costs, prospects, plans and objectives of management are forward-looking statements. The words “could,” “believe,” “anticipate,” “intend,” “estimate,” “expect,” “may,” “continue,” “predict,” “potential,” “project,” and similar terms and phrases are intended to identify forward-looking statements.
Although we believe our assumptions concerning future events are reasonable, a number of risks, uncertainties, and other factors could cause actual results and trends to differ materially from those projected or forward looking. Forward looking statements, as well as certain risks, contingencies or uncertainties that may impact our forward looking statements, include but are not limited to the following:
•volatile margins in the refining industry and exposure to the risks associated with volatile crude oil, refined product and feedstock prices;
•the availability of adequate cash and other sources of liquidity for the capital needs of our businesses;
•the severity, magnitude, duration, and impact of the novel coronavirus 2019 and any variant thereof (collectively, “COVID-19”) pandemic and of businesses’ and governments’ responses to such pandemic on our operations, personnel, commercial activity, and supply and demand across our and our customers’ and suppliers’ business;
•changes in market conditions and market volatility arising from the COVID-19 pandemic, inflation or potential economic recession, including crude oil and other commodity prices, demand for those commodities, storage and transportation capacities, and the impact of such changes on our operating results and financial position;
•expectations regarding our business and the economic recovery relating to the COVID-19 pandemic, including beliefs regarding future customer activity and the timing of the recovery;
•the ability to forecast our future financial condition, results of operations, revenues and expenses;
•the effects of transactions involving forward or derivative instruments;
•the effects of inflation;
•changes in laws, regulations and policies with respect to the export of crude oil, refined products, other hydrocarbons or renewable feedstocks or products including, without limitation, the actions of the Biden Administration that impact oil and gas operations in the U.S.;
•interruption in pipelines supplying feedstocks or distributing the petroleum business’ products;
•competition in the petroleum and nitrogen fertilizer businesses, including potential impacts of domestic and global supply and demand and/or domestic or international duties, tariffs, or similar costs;
•capital expenditures;
•changes in our or our segments’ credit profiles;profiles and the effects of higher interest rates;
•the cyclical and seasonal nature of the petroleum and nitrogen fertilizer businesses;
•the supply, availability and price levels of essential raw materials and feedstocks, and the effects of inflation thereupon;
•our production levels, including the risk of a material decline in those levels;
•accidents or other unscheduled shutdowns or interruptions affecting our facilities, machinery, or equipment, or those of our suppliers or customers;
•existing and future laws, regulations or rulings, including but not limited to those relating to the environment, climate change, renewables, safety, security and/or the transportation of production of hazardous chemicals like ammonia, including potential liabilities or capital requirements arising from such laws, regulations or rulings;
•erosion of demand for our products due to increasing focus on climate change and environmental, social and governance (“ESG”) initiatives;
•potential operating hazards from accidents, fire, severe weather, tornadoes, floods, or other natural disasters;
•the impact of weather on commodity supply and/or pricing and on the nitrogen fertilizer business including our ability to produce, market or sell fertilizer products profitability or at all;
•rulings, judgments or settlements in litigation, tax or other legal or regulatory matters;
•the dependence of the nitrogen fertilizer business on customers and distributors including to transport goods and equipment;
•the reliance on, or the ability to procure economically or at all, pet coke for our nitrogen fertilizer business purchases from Coffeyville Resources Refining & Marketing, LLC (“CRRM”) and third-party suppliers or the natural gas, electricity, oxygen, nitrogen, sulfur processing and compressed dry air and other products purchased from third parties by the nitrogen fertilizer and petroleum businesses;
•risks associated with third party operation of or control over important facilities necessary for operation of our refineries and nitrogen fertilizer facilities;
•risks of terrorism, cybersecurity attacks, and the security of chemical manufacturing facilities and other matters beyond our control;
•political disturbances, geopolitical instability and tensions, and associated changes in global trade policies and economic sanctions, including, but not limited to, in connection with Russia’s invasion of Ukraine in February 2022 and any ongoing conflicts in the region;
•our lack of diversification of assets or operating and supply areas;
•the petroleum business’ and nitrogen fertilizer business’ dependence on significant customers and the creditworthiness and performance by counterparties;
•the potential loss of the nitrogen fertilizer business’ transportation cost advantage over its competitors;
•the potential inability to successfully implement our business strategies at all or on time and within our anticipated budgets, including significant capital programs or projects, turnarounds or renewable or carbon reduction initiatives at our refineries and fertilizer facilities, including pretreater, carbon sequestration, segregation of our renewables business and other projects;
•our ability to continue to license the technology used for our operations;
•our petroleum business’ purchase of, or ability to purchase, renewable identification numbers (“RINs”) on a timely and cost effective basis or at all;
•the impact of refined product demand and declining inventories and Winter Storm Uri on refined product prices and crack spreads;
•Organization of Petroleum Exporting Countries’ and its allies’ (“OPEC”OPEC+”) production levels and pricing;
•the impact of RINs pricing, our blending and purchasing activities and governmental actions, including by the U.S. Environmental Protection Agency (the “EPA”) on our RIN obligations, open RINs positions, small refinery exemptions, and our estimated consolidated cost to comply with our Renewable Fuel Standard (“RFS”) obligations;
•our businesses’ ability to obtain, retain or renew environmental and other governmental permits, licenses or authorizations necessary for the operation of its business;
•our ability to successfully complete our restructuring initiative and the benefits thereof;
•existing and proposed laws, regulations or rulings, including but not limited to those relating to climate change, alternative energy or fuel sources, and existing and future regulations related to the end-use of our products or the application of fertilizers;
•Environmental, Social and Governance (“ESG”)ESG including but not limited to compliance with ESG-related recommendations or directives and risks or impacts relating thereto, whether from regulators, rating agencies, lenders, investors, litigants, customers, vendors, the public or others;
•refinery and nitrogen fertilizer facilities’ operating hazards and interruptions, including unscheduled maintenance or downtime and the availability of adequate insurance coverage;
•risks related to services provided by or competition among our subsidiaries, including conflicts of interests and control of CVR Partners, LP’s general partner;
•instability and volatility in the capital, credit and commodities markets and in the global economy, including due to the ongoing Russia-Ukraine conflict;
•restrictions in our debt agreements;
•asset impairments and impacts thereof;
•the variable nature of CVR Partners, LP’s distributions, including the ability of its general partner to modify or revoke its distribution policy, or to cease making cash distributions on its common units;
•changes in tax and other laws, regulations and policies, including, without limitation, actions of the Biden Administration that impact conventional fuel operations or favor renewable energy projects in the U.S.;
•changes in CVR Partners’ treatment as a partnership for U.S. federal income or state tax purposes;
•our ability to recover under our insurance policies for damages or losses in full or at all; and
•the factors described in greater detail under “Risk Factors” in Item 1A of our Annual Report on Form 10-K for the year ended December 31, 2021 and our other filings with the U.S. Securities and Exchange Commission (the “SEC”).
All forward-looking statements contained in this Report only speak as of the date of this Report. We undertake no obligation to publicly update or revise any forward-looking statements to reflect events or circumstances that occur after the date of this Report, or to reflect the occurrence of unanticipated events, except to the extent required by law.
Information About Us
Investors should note that we make available, free of charge on our website at cvrenergy.com, our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and any amendments to those reports as soon as reasonably practicable after we electronically file such material with, or furnish it to, the SEC. We also post announcements, updates, events, investor information and presentations on our website in addition to copies of all recent news releases. We may use the Investor Relations section of our website to communicate with investors. It is possible that the financial and other information posted there could be deemed to be material information. Documents and information on our website are not incorporated by reference herein.
The SEC maintains a website at www.sec.gov that contains reports, proxy and information statements, and other information regarding issuers, including us, that file electronically with the SEC.
JuneSeptember 30, 2022 | 4
PART I. FINANCIAL INFORMATION
Item 1. Financial Statements
CVR ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(unaudited) | | (in millions) | (in millions) | June 30, 2022 | | December 31, 2021 | (in millions) | September 30, 2022 | | December 31, 2021 |
ASSETS | | Current assets: | Current assets: | | Current assets: | |
| Cash and cash equivalents (including $156 and $113, respectively, of consolidated variable interest entity (“VIE”)) | $ | 893 | | | $ | 510 | | |
| Accounts receivable (including $36 and $88, respectively, of VIE) | 418 | | | 299 | | |
| Cash and cash equivalents (including $119 and $113, respectively, of consolidated variable interest entity (“VIE”)) | | Cash and cash equivalents (including $119 and $113, respectively, of consolidated variable interest entity (“VIE”)) | $ | 618 | | | $ | 510 | |
| Accounts receivable (including $54 and $88, respectively, of VIE) | | Accounts receivable (including $54 and $88, respectively, of VIE) | 320 | | | 299 | |
| | Inventories (including $85 and $52, respectively, of VIE) | 722 | | | 484 | | |
| Prepaid expenses and other current assets (including $6 and $9, respectively, of VIE) | 86 | | | 76 | | |
| Inventories (including $65 and $52, respectively, of VIE) | | Inventories (including $65 and $52, respectively, of VIE) | 632 | | | 484 | |
| Prepaid expenses and other current assets (including $3 and $9, respectively, of VIE) | | Prepaid expenses and other current assets (including $3 and $9, respectively, of VIE) | 88 | | | 76 | |
| | Total current assets | Total current assets | 2,119 | | | 1,369 | | Total current assets | 1,658 | | | 1,369 | |
| Property, plant and equipment, net (including $821 and $850, respectively, of VIE) | 2,252 | | | 2,273 | | |
| Property, plant and equipment, net (including $826 and $850, respectively, of VIE) | | Property, plant and equipment, net (including $826 and $850, respectively, of VIE) | 2,267 | | | 2,273 | |
| | Other long-term assets (including $14 and $14, respectively, of VIE) | 300 | | | 264 | | |
| Other long-term assets (including $15 and $14, respectively, of VIE) | | Other long-term assets (including $15 and $14, respectively, of VIE) | 281 | | | 264 | |
| Total assets | Total assets | $ | 4,671 | | | $ | 3,906 | | Total assets | $ | 4,206 | | | $ | 3,906 | |
| LIABILITIES AND EQUITY | | Current liabilities: | Current liabilities: | | Current liabilities: | |
| | Accounts payable (including $62 and $50, respectively, of VIE) | $ | 666 | | | $ | 409 | | |
| Accounts payable (including $79 and $50, respectively, of VIE) | | Accounts payable (including $79 and $50, respectively, of VIE) | $ | 557 | | | $ | 409 | |
| | Other current liabilities (including $34 and $111, respectively, of VIE) | 1,029 | | | 747 | | |
| Other current liabilities (including $105 and $111, respectively, of VIE) | | Other current liabilities (including $105 and $111, respectively, of VIE) | 974 | | | 747 | |
| Total current liabilities | Total current liabilities | 1,695 | | | 1,156 | | Total current liabilities | 1,531 | | | 1,156 | |
| Long-term liabilities: | Long-term liabilities: | | Long-term liabilities: | |
| Long-term debt and finance lease obligations, net of current portion (including $547 and $611, respectively, of VIE) | Long-term debt and finance lease obligations, net of current portion (including $547 and $611, respectively, of VIE) | 1,588 | | | 1,654 | | Long-term debt and finance lease obligations, net of current portion (including $547 and $611, respectively, of VIE) | 1,587 | | | 1,654 | |
| | Deferred income taxes | Deferred income taxes | 257 | | | 268 | | Deferred income taxes | 245 | | | 268 | |
| Other long-term liabilities (including $15 and $12, respectively, of VIE) | 71 | | | 58 | | |
| Other long-term liabilities (including $17 and $12, respectively, of VIE) | | Other long-term liabilities (including $17 and $12, respectively, of VIE) | 72 | | | 58 | |
| Total long-term liabilities | Total long-term liabilities | 1,916 | | | 1,980 | | Total long-term liabilities | 1,904 | | | 1,980 | |
| | 0 | | 0 | | |
| CVR stockholders’ equity | CVR stockholders’ equity | | CVR stockholders’ equity | |
| CVR Energy stockholders’ equity: | CVR Energy stockholders’ equity: | | CVR Energy stockholders’ equity: | |
| Common stock, $0.01 par value per share; 350,000,000 shares authorized; 100,629,209 and 100,629,209 shares issued as of June 30, 2022 and December 31, 2021, respectively | 1 | | | 1 | | |
| Common stock, $0.01 par value per share; 350,000,000 shares authorized; 100,629,209 and 100,629,209 shares issued as of September 30, 2022 and December 31, 2021, respectively | | Common stock, $0.01 par value per share; 350,000,000 shares authorized; 100,629,209 and 100,629,209 shares issued as of September 30, 2022 and December 31, 2021, respectively | 1 | | | 1 | |
| Additional paid-in-capital | Additional paid-in-capital | 1,508 | | | 1,510 | | Additional paid-in-capital | 1,508 | | | 1,510 | |
| Accumulated deficit | Accumulated deficit | (738) | | | (956) | | Accumulated deficit | (947) | | | (956) | |
| Treasury stock, 98,610 shares at cost | Treasury stock, 98,610 shares at cost | (2) | | | (2) | | Treasury stock, 98,610 shares at cost | (2) | | | (2) | |
| | Total CVR stockholders’ equity | Total CVR stockholders’ equity | 769 | | | 553 | | Total CVR stockholders’ equity | 560 | | | 553 | |
| Noncontrolling interest | Noncontrolling interest | 291 | | | 217 | | Noncontrolling interest | 211 | | | 217 | |
| Total equity | Total equity | 1,060 | | | 770 | | Total equity | 771 | | | 770 | |
| Total liabilities and equity | Total liabilities and equity | $ | 4,671 | | | $ | 3,906 | | Total liabilities and equity | $ | 4,206 | | | $ | 3,906 | |
The accompanying notes are an integral part of these condensed consolidated financial statements.
JuneSeptember 30, 2022 | 5
CVR ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(unaudited) | | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | Three Months Ended
September 30, | | Nine Months Ended
September 30, |
| (in millions, except per share data) | (in millions, except per share data) | 2022 | | 2021 | | 2022 | | 2021 | (in millions, except per share data) | 2022 | | 2021 | | 2022 | | 2021 |
| Net sales | Net sales | $ | 3,144 | | | $ | 1,783 | | | $ | 5,517 | | | $ | 3,246 | | Net sales | $ | 2,699 | | | $ | 1,883 | | | $ | 8,216 | | | $ | 5,129 | |
| Operating costs and expenses: | Operating costs and expenses: | | Operating costs and expenses: | |
| Cost of materials and other | Cost of materials and other | 2,465 | | | 1,539 | | | 4,352 | | | 2,908 | | Cost of materials and other | 2,267 | | | 1,473 | | | 6,619 | | | 4,381 | |
| Direct operating expenses (exclusive of depreciation and amortization) | Direct operating expenses (exclusive of depreciation and amortization) | 167 | | | 136 | | | 327 | | | 272 | | Direct operating expenses (exclusive of depreciation and amortization) | 218 | | | 137 | | | 545 | | | 409 | |
| Depreciation and amortization | Depreciation and amortization | 71 | | | 70 | | | 136 | | | 134 | | Depreciation and amortization | 74 | | | 65 | | | 210 | | | 199 | |
| Cost of sales | Cost of sales | 2,703 | | | 1,745 | | | 4,815 | | | 3,314 | | Cost of sales | 2,559 | | | 1,675 | | | 7,374 | | | 4,989 | |
| | Selling, general and administrative expenses (exclusive of depreciation and amortization) | Selling, general and administrative expenses (exclusive of depreciation and amortization) | 37 | | | 28 | | | 75 | | | 55 | | Selling, general and administrative expenses (exclusive of depreciation and amortization) | 35 | | | 30 | | | 110 | | | 85 | |
| Depreciation and amortization | Depreciation and amortization | 2 | | | 2 | | | 4 | | | 4 | | Depreciation and amortization | 1 | | | 2 | | | 5 | | | 6 | |
| Loss on asset disposal | Loss on asset disposal | — | | | 2 | | | — | | | 2 | | Loss on asset disposal | 1 | | | 1 | | | 1 | | | 3 | |
| | Operating income (loss) | 402 | | | 6 | | | 623 | | | (129) | | |
| Operating income | | Operating income | 103 | | | 175 | | | 726 | | | 46 | |
| Other (expense) income: | Other (expense) income: | | Other (expense) income: | |
| Interest expense, net | Interest expense, net | (23) | | | (38) | | | (48) | | | (69) | | Interest expense, net | (19) | | | (23) | | | (67) | | | (92) | |
| | Investment income on marketable securities | — | | | 21 | | | — | | | 83 | | |
| Other (expense) income, net | (74) | | | 3 | | | (84) | | | 10 | | |
| Investment (loss) income on marketable securities | | Investment (loss) income on marketable securities | — | | | (1) | | | — | | | 82 | |
| Other income (expense), net | | Other income (expense), net | 3 | | | 2 | | | (81) | | | 12 | |
| | Income (loss) before income tax expense | 305 | | | (8) | | | 491 | | | (105) | | |
| Income before income tax expense | | Income before income tax expense | 87 | | | 153 | | | 578 | | | 48 | |
| Income tax expense (benefit) | Income tax expense (benefit) | 66 | | | (6) | | | 99 | | | (48) | | Income tax expense (benefit) | 7 | | | 47 | | | 106 | | | (1) | |
| Net income (loss) | 239 | | | (2) | | | 392 | | | (57) | | |
| Less: Net income (loss) attributable to noncontrolling interest | 74 | | | 4 | | | 134 | | | (12) | | |
| Net income (loss) attributable to CVR Energy stockholders | $ | 165 | | | $ | (6) | | | $ | 258 | | | $ | (45) | | |
| Net income | | Net income | 80 | | | 106 | | | 472 | | | 49 | |
| Less: Net (loss) income attributable to noncontrolling interest | | Less: Net (loss) income attributable to noncontrolling interest | (13) | | | 22 | | | 121 | | | 10 | |
| Net income attributable to CVR Energy stockholders | | Net income attributable to CVR Energy stockholders | $ | 93 | | | $ | 84 | | | $ | 351 | | | $ | 39 | |
| | Basic and diluted earnings (loss) per share | $ | 1.64 | | | $ | (0.06) | | | $ | 2.57 | | | $ | (0.45) | | |
| Basic and diluted earnings per share | | Basic and diluted earnings per share | $ | 0.92 | | | $ | 0.83 | | | $ | 3.49 | | | $ | 0.38 | |
| | Dividends declared per share | $ | 0.40 | | | $ | 4.89 | | | $ | 0.40 | | | $ | 4.89 | | |
| | | Weighted-average common shares outstanding: | Weighted-average common shares outstanding: | | Weighted-average common shares outstanding: | |
| Basic and diluted | Basic and diluted | 100.5 | | | 100.5 | | | 100.5 | | | 100.5 | | Basic and diluted | 100.5 | | | 100.5 | | | 100.5 | | | 100.5 | |
|
The accompanying notes are an integral part of these condensed consolidated financial statements.
JuneSeptember 30, 2022 | 6
CVR ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
(unaudited) | | | Common Stockholders | | | Common Stockholders | |
| (in millions, except share data) | (in millions, except share data) | Shares
Issued | | $0.01 Par Value Common Stock | | Additional
Paid-In
Capital | | Accumulated Deficit | | Treasury
Stock | | | Total CVR
Stockholders’
Equity | | Noncontrolling
Interest | | Total
Equity | (in millions, except share data) | Shares
Issued | | $0.01 Par Value Common Stock | | Additional
Paid-In
Capital | | Accumulated Deficit | | Treasury
Stock | | | Total CVR
Stockholders’
Equity | | Noncontrolling
Interest | | Total
Equity |
| Balance at December 31, 2021 | Balance at December 31, 2021 | 100,629,209 | | | $ | 1 | | | $ | 1,510 | | | $ | (956) | | | $ | (2) | | | | $ | 553 | | | $ | 217 | | | $ | 770 | | Balance at December 31, 2021 | 100,629,209 | | | $ | 1 | | | $ | 1,510 | | | $ | (956) | | | $ | (2) | | | | $ | 553 | | | $ | 217 | | | $ | 770 | |
| | Distributions from CVR Partners to its public unitholders | Distributions from CVR Partners to its public unitholders | — | | | — | | | — | | | — | | | — | | | | — | | | (36) | | | (36) | | Distributions from CVR Partners to its public unitholders | — | | | — | | | — | | | — | | | — | | | | — | | | (36) | | | (36) | |
| | Changes in equity due to CVR Partners’ common unit repurchases | Changes in equity due to CVR Partners’ common unit repurchases | — | | | — | | | (2) | | | — | | | — | | | | (2) | | | (9) | | | (11) | | Changes in equity due to CVR Partners’ common unit repurchases | — | | | — | | | (2) | | | — | | | — | | | | (2) | | | (9) | | | (11) | |
| Other | Other | — | | | — | | | — | | | (1) | | | — | | | | (1) | | | 1 | | | — | | Other | — | | | — | | | — | | | (1) | | | — | | | | (1) | | | 1 | | | — | |
| Net income | Net income | — | | | — | | | — | | | 94 | | | — | | | | 94 | | | 59 | | | 153 | | Net income | — | | | — | | | — | | | 94 | | | — | | | | 94 | | | 59 | | | 153 | |
| Balance at March 31, 2022 | Balance at March 31, 2022 | 100,629,209 | | | $ | 1 | | | $ | 1,508 | | | $ | (863) | | | $ | (2) | | | | $ | 644 | | | $ | 232 | | | $ | 876 | | Balance at March 31, 2022 | 100,629,209 | | | 1 | | | 1,508 | | | (863) | | | (2) | | | | 644 | | | 232 | | | 876 | |
| Dividends paid to CVR Energy stockholders | Dividends paid to CVR Energy stockholders | — | | | — | | | — | | | (40) | | | — | | | | (40) | | | — | | | (40) | | Dividends paid to CVR Energy stockholders | — | | | — | | | — | | | (40) | | | — | | | | (40) | | | — | | | (40) | |
| | Distributions from CVR Partners to its public unitholders | Distributions from CVR Partners to its public unitholders | — | | | — | | | — | | | — | | | — | | | | — | | | (15) | | | (15) | | Distributions from CVR Partners to its public unitholders | — | | | — | | | — | | | — | | | — | | | | — | | | (15) | | | (15) | |
| | Net income | Net income | — | | | — | | | — | | | 165 | | | — | | | | 165 | | | 74 | | | 239 | | Net income | — | | | — | | | — | | | 165 | | | — | | | | 165 | | | 74 | | | 239 | |
| Balance at June 30, 2022 | Balance at June 30, 2022 | 100,629,209 | | | $ | 1 | | | $ | 1,508 | | | $ | (738) | | | $ | (2) | | | | $ | 769 | | | $ | 291 | | | $ | 1,060 | | Balance at June 30, 2022 | 100,629,209 | | | 1 | | | 1,508 | | | (738) | | | (2) | | | | 769 | | | 291 | | | 1,060 | |
| Dividends paid to CVR Energy stockholders | | Dividends paid to CVR Energy stockholders | — | | | — | | | — | | | (302) | | | — | | | | (302) | | | — | | | (302) | |
| Distributions from CVR Partners to its public unitholders | | Distributions from CVR Partners to its public unitholders | — | | | — | | | — | | | — | | | — | | | | — | | | (67) | | | (67) | |
| | Net income (loss) | | Net income (loss) | — | | | — | | | — | | | 93 | | | — | | | | 93 | | | (13) | | | 80 | |
| Balance at September 30, 2022 | | Balance at September 30, 2022 | 100,629,209 | | | $ | 1 | | | $ | 1,508 | | | $ | (947) | | | $ | (2) | | | | $ | 560 | | | $ | 211 | | | $ | 771 | |
| | | Common Stockholders | | | Common Stockholders | |
| (in millions, except share data) | (in millions, except share data) | Shares
Issued | | $0.01 Par Value Common Stock | | Additional
Paid-In
Capital | | Accumulated Deficit | | Treasury
Stock | | | Total CVR
Stockholders’
Equity | | Noncontrolling
Interest | | Total
Equity | (in millions, except share data) | Shares
Issued | | $0.01 Par Value Common Stock | | Additional
Paid-In
Capital | | Accumulated Deficit | | Treasury
Stock | | | Total CVR
Stockholders’
Equity | | Noncontrolling
Interest | | Total
Equity |
| Balance at December 31, 2020 | Balance at December 31, 2020 | 100,629,209 | | | $ | 1 | | | $ | 1,510 | | | $ | (490) | | | $ | (2) | | | | $ | 1,019 | | | $ | 200 | | | $ | 1,219 | | Balance at December 31, 2020 | 100,629,209 | | | $ | 1 | | | $ | 1,510 | | | $ | (490) | | | $ | (2) | | | | $ | 1,019 | | | $ | 200 | | | $ | 1,219 | |
| Changes in equity due to CVR
Partners’ common unit repurchases | Changes in equity due to CVR
Partners’ common unit repurchases | — | | | — | | | — | | | — | | | — | | | | — | | | (1) | | | (1) | | Changes in equity due to CVR
Partners’ common unit repurchases | — | | | — | | | — | | | — | | | — | | | | — | | | (1) | | | (1) | |
| Other | Other | — | | | — | | | — | | | 1 | | | — | | | | 1 | | | — | | | 1 | | Other | — | | | — | | | — | | | 1 | | | — | | | | 1 | | | — | | | 1 | |
| Net loss | Net loss | — | | | — | | | — | | | (39) | | | — | | | | (39) | | | (16) | | | (55) | | Net loss | — | | | — | | | — | | | (39) | | | — | | | | (39) | | | (16) | | | (55) | |
| Balance at March 31, 2021 | Balance at March 31, 2021 | 100,629,209 | | | $ | 1 | | | $ | 1,510 | | | $ | (528) | | | $ | (2) | | | | $ | 981 | | | $ | 183 | | | $ | 1,164 | | Balance at March 31, 2021 | 100,629,209 | | | 1 | | | 1,510 | | | (528) | | | (2) | | | | 981 | | | 183 | | | 1,164 | |
| Dividends paid to CVR Energy stockholders | Dividends paid to CVR Energy stockholders | — | | | — | | | — | | | (492) | | | — | | | | (492) | | | — | | | (492) | | Dividends paid to CVR Energy stockholders | — | | | — | | | — | | | (492) | | | — | | | | (492) | | | — | | | (492) | |
| | Net (loss) income | Net (loss) income | — | | | — | | | — | | | (6) | | | — | | | | (6) | | | 4 | | | (2) | | Net (loss) income | — | | | — | | | — | | | (6) | | | — | | | | (6) | | | 4 | | | (2) | |
| Balance at June 30, 2021 | Balance at June 30, 2021 | 100,629,209 | | | $ | 1 | | | $ | 1,510 | | | $ | (1,026) | | | $ | (2) | | | | $ | 483 | | | $ | 187 | | | $ | 670 | | Balance at June 30, 2021 | 100,629,209 | | | 1 | | | 1,510 | | | (1,026) | | | (2) | | | | 483 | | | 187 | | | 670 | |
| | Distributions from CVR Partners to its public unitholders | | Distributions from CVR Partners to its public unitholders | — | | | — | | | — | | | — | | | — | | | | — | | | (11) | | | (11) | |
| | Net income | | Net income | — | | | — | | | — | | | 84 | | | — | | | | 84 | | | 22 | | | 106 | |
| Balance at September 30, 2021 | | Balance at September 30, 2021 | 100,629,209 | | | $ | 1 | | | $ | 1,510 | | | $ | (942) | | | $ | (2) | | | | $ | 567 | | | $ | 198 | | | $ | 765 | |
The accompanying notes are an integral part of these condensed consolidated financial statements.
JuneSeptember 30, 2022 | 7
CVR ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(unaudited) | | | Six Months Ended June 30, | | Nine Months Ended September 30, |
| (in millions) | (in millions) | 2022 | | 2021 | (in millions) | 2022 | | 2021 |
| Cash flows from operating activities: | Cash flows from operating activities: | | | | Cash flows from operating activities: | | | |
| Net income (loss) | $ | 392 | | | $ | (57) | | |
| Adjustments to reconcile net income (loss) to net cash provided by operating activities: | |
| Net income | | Net income | $ | 472 | | | $ | 49 | |
| Adjustments to reconcile net income to net cash provided by operating activities: | | Adjustments to reconcile net income to net cash provided by operating activities: |
| Depreciation and amortization | Depreciation and amortization | 140 | | | 138 | | Depreciation and amortization | 215 | | | 205 | |
| | Gain on marketable securities | Gain on marketable securities | — | | | (83) | | Gain on marketable securities | — | | | (82) | |
| Deferred income taxes | Deferred income taxes | (10) | | | (102) | | Deferred income taxes | (22) | | | (34) | |
| Loss on asset disposal | Loss on asset disposal | — | | | 2 | | Loss on asset disposal | 1 | | | 3 | |
| Loss on extinguishment of debt | Loss on extinguishment of debt | 1 | | | 8 | | Loss on extinguishment of debt | 1 | | | 8 | |
| Share-based compensation | Share-based compensation | 36 | | | 20 | | Share-based compensation | 49 | | | 31 | |
| Loss on derivatives, net | 15 | | | 7 | | |
| Unrealized gain on derivatives, net | | Unrealized gain on derivatives, net | (5) | | | (16) | |
| | Other items | Other items | 2 | | | 4 | | Other items | 3 | | | 4 | |
| Changes in assets and liabilities: | Changes in assets and liabilities: | | Changes in assets and liabilities: | |
| Current assets and liabilities | Current assets and liabilities | 135 | | | 301 | | Current assets and liabilities | 157 | | | 209 | |
| | Non-current assets and liabilities | Non-current assets and liabilities | 1 | | | 5 | | Non-current assets and liabilities | (3) | | | 5 | |
| | Net cash provided by operating activities | Net cash provided by operating activities | 712 | | | 243 | | Net cash provided by operating activities | 868 | | | 382 | |
| Cash flows from investing activities: | Cash flows from investing activities: | | | | Cash flows from investing activities: | | | |
| Capital expenditures | Capital expenditures | (88) | | | (126) | | Capital expenditures | (145) | | | (188) | |
| | Turnaround expenditures | Turnaround expenditures | (68) | | | (2) | | Turnaround expenditures | (74) | | | (3) | |
| Acquisition of pipeline assets | Acquisition of pipeline assets | — | | | (20) | | Acquisition of pipeline assets | — | | | (20) | |
| | Proceeds from sale of assets | Proceeds from sale of assets | — | | | 6 | | Proceeds from sale of assets | — | | | 7 | |
| | Other investing activities | Other investing activities | — | | | 1 | | Other investing activities | 2 | | | — | |
| | Net cash used in investing activities | Net cash used in investing activities | (156) | | | (141) | | Net cash used in investing activities | (217) | | | (204) | |
| Cash flows from financing activities: | Cash flows from financing activities: | | | | Cash flows from financing activities: | | | |
| | Proceeds from issuance of senior secured notes | Proceeds from issuance of senior secured notes | — | | | 550 | | Proceeds from issuance of senior secured notes | — | | | 550 | |
| Principal payments on senior secured notes | Principal payments on senior secured notes | (65) | | | (552) | | Principal payments on senior secured notes | (65) | | | (567) | |
| | Repurchase of common units by CVR Partners | Repurchase of common units by CVR Partners | (12) | | | (1) | | Repurchase of common units by CVR Partners | (12) | | | (1) | |
| | Dividends to CVR Energy’s stockholders | Dividends to CVR Energy’s stockholders | (40) | | | (241) | | Dividends to CVR Energy’s stockholders | (342) | | | (241) | |
| Distributions to CVR Partners’ noncontrolling interest holders | Distributions to CVR Partners’ noncontrolling interest holders | (51) | | | — | | Distributions to CVR Partners’ noncontrolling interest holders | (118) | | | (11) | |
| Other financing activities | Other financing activities | (5) | | | (6) | | Other financing activities | (6) | | | (9) | |
| Net cash used in financing activities | Net cash used in financing activities | (173) | | | (250) | | Net cash used in financing activities | (543) | | | (279) | |
| Net increase (decrease) in cash, cash equivalents and restricted cash | Net increase (decrease) in cash, cash equivalents and restricted cash | 383 | | | (148) | | Net increase (decrease) in cash, cash equivalents and restricted cash | 108 | | | (101) | |
| Cash, cash equivalents and restricted cash, beginning of period | Cash, cash equivalents and restricted cash, beginning of period | 517 | | | 674 | | Cash, cash equivalents and restricted cash, beginning of period | 517 | | | 674 | |
| Cash, cash equivalents and restricted cash, end of period | Cash, cash equivalents and restricted cash, end of period | $ | 900 | | | $ | 526 | | Cash, cash equivalents and restricted cash, end of period | $ | 625 | | | $ | 573 | |
|
The accompanying notes are an integral part of these condensed consolidated financial statements.
JuneSeptember 30, 2022 | 8
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(unaudited)
(1) Organization and Nature of Business
Organization
CVR Energy, Inc. (“CVR Energy,” “CVR,” “we,” “us,” “our,” or the “Company”) is a diversified holding company primarily engaged in the petroleum refining and nitrogen fertilizer manufacturing industries through its holdings in CVR Refining, LP (the “Petroleum Segment” or “CVR Refining”) and CVR Partners, LP (the “Nitrogen Fertilizer Segment” or “CVR Partners”). CVR Refining is an independent petroleum refiner and marketer of high value transportation fuels.fuels primarily in the form of gasoline and diesel fuels, as well as renewable diesel. CVR Partners produces and markets nitrogen fertilizers primarily in the form of urea ammonium nitrate (“UAN”) and ammonia. CVR’s common stock is listed on the New York Stock Exchange under the symbol “CVI.” Icahn Enterprises L.P. and its affiliates (“IEP”) owned approximately 71% of the Company’s outstanding common stock as of JuneSeptember 30, 2022.
CVR Partners, LP
Interest Holders - As of JuneSeptember 30, 2022, public common unitholders held approximately 63% of CVR Partners’ outstanding common units and CVR Services, LLC (“CVR Services”), a wholly owned subsidiary of CVR Energy, held the remaining approximately 37% of CVR Partners’ outstanding common units. In addition, CVR Services held 100% of the interests in CVR Partners’ general partner, CVR GP, LLC (“CVR GP”), which held a non-economic general partner interest in CVR Partners as of JuneSeptember 30, 2022. The noncontrolling interest reflected on the condensed consolidated balance sheets of CVR is only impacted by the net income of, and distributions from, CVR Partners.
Unit Repurchase Program - On May 6, 2020, the board of directors of CVR Partners’ general partner (the “UAN GP Board”), on behalf of CVR Partners, authorized a unit repurchase program (the “Unit Repurchase Program”), which was increased on February 22, 2021. The Unit Repurchase Program, as increased, authorized CVR Partners to repurchase up to $20 million of the CVR Partners’ common units. During the three months ended JuneSeptember 30, 2022 and 2021, CVR Partners did not repurchase any common units. During the sixnine months ended JuneSeptember 30, 2022 and 2021, CVR Partners repurchased 111,695 and 24,378 common units, respectively, on the open market in accordance with a repurchase agreement under Rules 10b5-1 and 10b-18 of the Securities Exchange Act of 1934, as amended, at a cost of $12 million and $1 million, respectively, exclusive of transaction costs, or an average price of $110.98 and $21.69 per common unit, respectively. As of JuneSeptember 30, 2022, CVR Partners, considering all repurchases made since inception of the Unit Repurchase Program, had a 0minalnominal amount in authority remaining under the Unit Repurchase Program. This Unit Repurchase Program does not obligate CVR Partners to repurchase any common units and may be cancelled or terminated by the UAN GP Board at any time.
As a result of these repurchases, and the resulting change in CVR Energy’s ownership of CVR Partners while maintaining control, CVR Energy recognized a decrease of $2 million to additional paid-in capital from the reduction of non-controlling interests totaling $3 million and a related reduction of a deferred tax liability totaling $1 million from changes in its book versus tax basis in CVR Partners as of JuneSeptember 30, 2022. CVR Energy recognized a nominal increase to additional paid-in capital from the non-cash reduction of non-controlling interests totaling $0.1 million and the recognition of a deferred tax liability totaling $0.1 million from changes in its book versus tax basis in CVR Partners as of December 31, 2021.
(2) Basis of Presentation
The accompanying condensed consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”). These condensed consolidated financial statements should be read in conjunction with the December 31, 2021 audited consolidated financial statements and notes thereto included in CVR Energy’s Annual Report on Form 10-K for the year ended December 31, 2021 (the “2021 Form 10-K”).
Our condensed consolidated financial statements include the consolidated results of CVR Partners, which is defined as a variable interest entity.
In the opinion of the Company’s management, the accompanying condensed consolidated financial statements reflect all adjustments that are necessary for fair presentation of the financial position and results of operations of the Company for the periods presented. Such adjustments are of a normal recurring nature, unless otherwise disclosed.
JuneSeptember 30, 2022 | 9
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
Certain reclassifications have been made within the condensed consolidated financial statements for prior periods to conform with current presentation.
The preparation of the condensed consolidated financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingentcertain assets and liabilities. Actual results could differ from those estimates. Results of operations and cash flows for the interim periods presented are not necessarily indicative of the results that will be realized for the year ending December 31, 2022 or any other interim or annual period.
(3) Recent Accounting Pronouncements and Accounting Changes
Recent Accounting Pronouncements - New Accounting Standards Issued But Not Yet Implemented
In March 2020, the Financial Accounting Standards Board (“FASB”) issued Accounting Standard Update (“ASU”) 2020-04, Reference Rate Reform (Topic 848) - Facilitation of the Effects of Reference Rate Reform on Financial Reporting, which provides optional guidance to ease the potential burden in accounting for (or recognizing the effects of) reference rate reform on financial reporting. This guidance applies to contracts, hedging relationships and other transactions affected by the discontinuation of the London Interbank Offered Rate (“LIBOR”) and other interbank offered rates. The guidance is effective beginning on March 12, 2020 through the sunset date of Topic 848, which is currently expected to occur on December 31, 2022. The Company has not utilized any of the optional expedients or exceptions available under this guidance and will continue to assess whether this guidance is applicable throughout the effective period.
(4) Inventories
Inventories consisted of the following:
| | (in millions) | (in millions) | June 30, 2022 | | December 31, 2021 | (in millions) | September 30, 2022 | | December 31, 2021 |
| Finished goods | Finished goods | $ | 345 | | | $ | 215 | | Finished goods | $ | 281 | | | $ | 215 | |
| Raw materials | Raw materials | 262 | | | 177 | | Raw materials | 244 | | | 177 | |
| In-process inventories | In-process inventories | 31 | | | 20 | | In-process inventories | 25 | | | 20 | |
| Parts, supplies and other | Parts, supplies and other | 84 | | | 72 | | Parts, supplies and other | 82 | | | 72 | |
| Total inventories | Total inventories | $ | 722 | | | $ | 484 | | Total inventories | $ | 632 | | | $ | 484 | |
(5) Property, Plant and Equipment
Property, plant and equipment consisted of the following:
| | (in millions) | (in millions) | June 30, 2022 | | December 31, 2021 | (in millions) | September 30, 2022 | | December 31, 2021 |
| Machinery and equipment | Machinery and equipment | $ | 4,161 | | | $ | 4,033 | | Machinery and equipment | $ | 4,162 | | | $ | 4,033 | |
| Buildings and improvements | Buildings and improvements | 89 | | | 88 | | Buildings and improvements | 87 | | | 88 | |
| ROU finance leases | ROU finance leases | 80 | | | 81 | | ROU finance leases | 79 | | | 81 | |
| Land and improvements | Land and improvements | 72 | | | 71 | | Land and improvements | 72 | | | 71 | |
| Furniture and fixtures | Furniture and fixtures | 37 | | | 37 | | Furniture and fixtures | 35 | | | 37 | |
| Construction in progress | Construction in progress | 104 | | | 142 | | Construction in progress | 131 | | | 142 | |
| Other | Other | 14 | | | 15 | | Other | 14 | | | 15 | |
| | | 4,557 | | | 4,467 | | | 4,580 | | | 4,467 | |
| Less: Accumulated depreciation and amortization | Less: Accumulated depreciation and amortization | (2,305) | | | (2,194) | | Less: Accumulated depreciation and amortization | (2,313) | | | (2,194) | |
| Total property, plant and equipment, net | Total property, plant and equipment, net | $ | 2,252 | | | $ | 2,273 | | Total property, plant and equipment, net | $ | 2,267 | | | $ | 2,273 | |
On February 1, 2021, the Company completed a pipeline acquisition for total consideration of $23 million, which was accounted for as a business combination under Accounting Standards Codification (“ASC”) 805. An intangible asset of $3
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
$3 million was recognized in Other long-term assets related to acquired contracts that is being amortized over less than three years. The accounting for the business combination was finalized during January 2022.
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
During the sixnine months ended JuneSeptember 30, 2022, the Company had not identified the existence of an impairment indicator for our long-lived asset groups as outlined under ASC 360.
(6) Leases
Lease Overview
We lease certain pipelines, storage tanks, railcars, office space, land, and equipment across our refining, fertilizer, and corporate operations. Most of our leases include 1one or more renewal options to extend the lease term, from one to 20 years or more, which can be exercised at our sole discretion. Certain leases also include options to purchase the leased property. The depreciable life of leased assets and leasehold improvements are limited by the expected lease term, unless there is a transfer of title or purchase option reasonably certain of exercise. Certain of our lease agreements include rental payments which are adjusted periodically for factors such as inflation. Our lease agreements do not contain any material residual value guarantees or material restrictive covenants. Additionally, we do not have any material lessor or sub-leasing arrangements.
Balance Sheet Summary as of JuneSeptember 30, 2022 and December 31, 2021
The following tables summarize the right-of-use (“ROU”) asset and lease liability balances for the Company’s operating and finance leases at JuneSeptember 30, 2022 and December 31, 2021:
| | | June 30, 2022 | | December 31, 2021 | | September 30, 2022 | | December 31, 2021 |
| (in millions) | (in millions) | Operating Leases | | Finance Leases | | Operating Leases | | Finance Leases | (in millions) | Operating Leases | | Finance Leases | | Operating Leases | | Finance Leases |
| ROU assets, net | ROU assets, net | | | | | | | | ROU assets, net | | | | | | | |
| Pipeline and storage | Pipeline and storage | $ | 18 | | | $ | 22 | | | $ | 17 | | | $ | 23 | | Pipeline and storage | $ | 17 | | | $ | 21 | | | $ | 17 | | | $ | 23 | |
| Railcars | Railcars | 5 | | | — | | | 6 | | | — | | Railcars | 4 | | | — | | | 6 | | | — | |
| Real estate and other | Real estate and other | 15 | | | 16 | | | 14 | | | 18 | | Real estate and other | 14 | | | 15 | | | 14 | | | 18 | |
| Lease liability | Lease liability | | Lease liability | |
| Pipelines and storage | Pipelines and storage | 18 | | | 34 | | | 17 | | | 35 | | Pipelines and storage | 17 | | | 33 | | | 17 | | | 35 | |
| Railcars | Railcars | 5 | | | — | | | 6 | | | — | | Railcars | 4 | | | — | | | 6 | | | — | |
| Real estate and other | Real estate and other | 15 | | | 17 | | | 14 | | | 19 | | Real estate and other | 14 | | | 17 | | | 14 | | | 19 | |
Lease Expense Summary for the Three and SixNine Months Ended JuneSeptember 30, 2022 and 2021
We recognize lease expense on a straight-line basis over the lease term and short-term lease expense within Direct operating expenses (exclusive of depreciation and amortization). For the three and sixnine months ended JuneSeptember 30, 2022 and 2021, we recognized lease expense comprised of the following components:
| | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | Three Months Ended
September 30, | | Nine Months Ended
September 30, |
| (in millions) | (in millions) | 2022 | | 2021 | | 2022 | | 2021 | (in millions) | 2022 | | 2021 | | 2022 | | 2021 |
| Operating lease expense | Operating lease expense | $ | 4 | | | $ | 4 | | | $ | 8 | | | $ | 8 | | Operating lease expense | $ | 4 | | | $ | 3 | | | $ | 12 | | | $ | 11 | |
| Finance lease expense: | Finance lease expense: | | Finance lease expense: | |
| Amortization of ROU asset | Amortization of ROU asset | 1 | | | 1 | | | 3 | | | 3 | | Amortization of ROU asset | 2 | | | 2 | | | 5 | | | 5 | |
| Interest expense on lease liability | Interest expense on lease liability | 1 | | | 2 | | | 2 | | | 3 | | Interest expense on lease liability | 1 | | | 1 | | | 4 | | | 4 | |
| Short-term lease expense | Short-term lease expense | 2 | | | 2 | | | 5 | | | 4 | | Short-term lease expense | 3 | | | 2 | | | 7 | | | 6 | |
JuneSeptember 30, 2022 | 11
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
Lease Terms and Discount Rates
The following outlines the remaining lease terms and discount rates used in the measurement of the Company’s ROU assets and lease liabilities:
| | | June 30, 2022 | | December 31, 2021 | | September 30, 2022 | | December 31, 2021 |
| | Operating Leases | | Finance Leases | | Operating Leases | | Finance Leases | | Operating Leases | | Finance Leases | | Operating Leases | | Finance Leases |
| Weighted-average remaining lease term | Weighted-average remaining lease term | 4.0 years | | 6.7 years | | 4.1 years | | 7.2 years | Weighted-average remaining lease term | 3.9 years | | 6.5 years | | 4.1 years | | 7.2 years |
| Weighted-average discount rate | Weighted-average discount rate | 5.1 | % | | 9.0 | % | | 5.4 | % | | 9.0 | % | Weighted-average discount rate | 5.1 | % | | 9.0 | % | | 5.4 | % | | 9.0 | % |
Maturities of Lease Liabilities
The following summarizes the remaining minimum lease payments through maturity of the Company’s lease liabilities at JuneSeptember 30, 2022:
| | (in millions) | (in millions) | Operating Leases | | Finance Leases | (in millions) | Operating Leases | | Finance Leases |
| Remainder of 2022 | Remainder of 2022 | $ | 8 | | | $ | 6 | | Remainder of 2022 | $ | 5 | | | $ | 3 | |
| 2023 | 2023 | 14 | | | 9 | | 2023 | 14 | | | 11 | |
| 2024 | 2024 | 9 | | | 10 | | 2024 | 10 | | | 10 | |
| 2025 | 2025 | 4 | | | 10 | | 2025 | 4 | | | 10 | |
| 2026 | 2026 | 3 | | | 10 | | 2026 | 3 | | | 10 | |
| Thereafter | Thereafter | 4 | | | 23 | | Thereafter | 4 | | | 23 | |
| Total lease payments | Total lease payments | 42 | | | 68 | | Total lease payments | 40 | | | 67 | |
| Less: imputed interest | Less: imputed interest | (4) | | | (17) | | Less: imputed interest | (5) | | | (17) | |
| Total lease liability | Total lease liability | $ | 38 | | | $ | 51 | | Total lease liability | $ | 35 | | | $ | 50 | |
On February 21, 2022, Coffeyville Resources Nitrogen Fertilizers, LLC (“CRNF”), a wholly owned subsidiary of CVR Partners, entered into the First Amendment to the On-Site Product Supply Agreement with Messer LLC (“Messer”), which amended the July 31, 2020 On-Site Product Supply Agreement (as amended, the “Messer Agreement”). Under the Messer Agreement, among other obligations, Messer is obligated to supply and make certain capital improvements during the term of the Messer Agreement, and CRNF is obligated to take as available and pay for, oxygen, nitrogen, and compressed dry air from Messer’s facility. This arrangement for CRNF’s purchase of oxygen, nitrogen, and dry air from Messer does not meet the definition of a lease under FASB ASC Topic 842, Leases (“Topic 842”), as CRNF does not expect to receive substantially all of the output of Messer’s on-site production from its air separation unit over the life of the Messer Agreement. The Messer Agreement also obligates Messer to install a new oxygen storage vessel, related equipment and infrastructure (“Oxygen Storage Vessel” or “Vessel”) to be used solely by the Coffeyville Fertilizer Facility. The arrangement for the use of the Oxygen Storage Vessel meets the definition of a lease under Topic 842, as CRNF will receive all output associated with the Vessel. Based on terms outlined in the Messer Agreement, the Company expects the lease of the Oxygen Storage Vessel to be classified as a financing lease with an amount of approximately $25 million being capitalized upon lease commencement when the Vessel is placed in service.service, which is currently expected within the next 12 months.
On July 14, 2022, the Company entered into the Sixth Amendment to the Sugar Land Plaza Office Building Agreement with LCFRE Sugar Land Town Square, LLC (“LCFRE”), which amends the Sugar Land Plaza Office Building Agreement dated 2016 (as amended, the “LCFRE Agreement”). Under the LCFRE Agreement, LCFRE will provide office space to the Company which will continue to serve as the Company’s corporate office in Sugar Land, Texas and will commence on October 1, 2023. Based on the terms outlined in the LCFRE Agreement, the Company expects the lease to be classified as an operating lease under Topic 842, with approximately $12 million capitalized upon lease commencement.
JuneSeptember 30, 2022 | 12
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
(7) Other Current Liabilities
Other current liabilities were as follows:
| | (in millions) | (in millions) | June 30, 2022 | | December 31, 2021 | (in millions) | September 30, 2022 | | December 31, 2021 |
| Accrued Renewable Fuel Standards (“RFS”) obligation | Accrued Renewable Fuel Standards (“RFS”) obligation | $ | 708 | | | $ | 494 | | Accrued Renewable Fuel Standards (“RFS”) obligation | $ | 715 | | | $ | 494 | |
| Accrued taxes other than income taxes | 49 | | | 45 | | |
| Deferred revenue | | Deferred revenue | 65 | | | 87 | |
| Share-based compensation | Share-based compensation | 37 | | | 15 | | Share-based compensation | 45 | | | 15 | |
| Personnel accruals | Personnel accruals | 33 | | | 46 | | Personnel accruals | 45 | | | 46 | |
| Accrued taxes other than income taxes | | Accrued taxes other than income taxes | 43 | | | 45 | |
| Accrued interest | Accrued interest | 24 | | | 24 | | Accrued interest | 18 | | | 24 | |
| Accrued income taxes | 22 | | | — | | |
| Derivatives | 20 | | | 2 | | |
| Operating lease liabilities | Operating lease liabilities | 14 | | | 13 | | Operating lease liabilities | 14 | | | 13 | |
| Current portion of long-term debt and finance lease obligations | Current portion of long-term debt and finance lease obligations | 6 | | | 6 | | Current portion of long-term debt and finance lease obligations | 6 | | | 6 | |
| Deferred revenue | 4 | | | 87 | | |
| | Derivatives | | Derivatives | — | | | 2 | |
| Other accrued expenses and liabilities | Other accrued expenses and liabilities | 112 | | | 15 | | Other accrued expenses and liabilities | 23 | | | 15 | |
| Total other current liabilities | Total other current liabilities | $ | 1,029 | | | $ | 747 | | Total other current liabilities | $ | 974 | | | $ | 747 | |
(8) Long-Term Debt and Finance Lease Obligations
Long-term debt and finance lease obligations consistconsisted of the following:
| | (in millions) | (in millions) | June 30, 2022 | | December 31, 2021 | (in millions) | September 30, 2022 | | December 31, 2021 |
| CVR Partners: | CVR Partners: | | | | CVR Partners: | | | |
9.25% Senior Secured Notes, due June 2023 (1) | 9.25% Senior Secured Notes, due June 2023 (1) | $ | — | | | $ | 65 | | 9.25% Senior Secured Notes, due June 2023 (1) | $ | — | | | $ | 65 | |
| 6.125% Senior Secured Notes, due June 2028 | 6.125% Senior Secured Notes, due June 2028 | 550 | | | 550 | | 6.125% Senior Secured Notes, due June 2028 | 550 | | | 550 | |
| | Unamortized discount and debt issuance costs | Unamortized discount and debt issuance costs | (3) | | | (4) | | Unamortized discount and debt issuance costs | (3) | | | (4) | |
| Total CVR Partners debt, net of current portion | Total CVR Partners debt, net of current portion | $ | 547 | | | $ | 611 | | Total CVR Partners debt, net of current portion | $ | 547 | | | $ | 611 | |
| | CVR Refining: | CVR Refining: | | CVR Refining: | |
| | Finance lease obligations, net of current portion | Finance lease obligations, net of current portion | 45 | | | 48 | | Finance lease obligations, net of current portion | 44 | | | 48 | |
| | Total CVR Refining debt, net of current portion | Total CVR Refining debt, net of current portion | $ | 45 | | | $ | 48 | | Total CVR Refining debt, net of current portion | $ | 44 | | | $ | 48 | |
| | CVR Energy: | CVR Energy: | | CVR Energy: | |
| 5.25% Senior Notes, due February 2025 | 5.25% Senior Notes, due February 2025 | $ | 600 | | | $ | 600 | | 5.25% Senior Notes, due February 2025 | $ | 600 | | | $ | 600 | |
| 5.75% Senior Notes, due February 2028 | 5.75% Senior Notes, due February 2028 | 400 | | | 400 | | 5.75% Senior Notes, due February 2028 | 400 | | | 400 | |
| Unamortized debt issuance costs | Unamortized debt issuance costs | (4) | | | (5) | | Unamortized debt issuance costs | (4) | | | (5) | |
| Total CVR Energy debt | Total CVR Energy debt | $ | 996 | | | $ | 995 | | Total CVR Energy debt | $ | 996 | | | $ | 995 | |
| Total long-term debt and finance lease obligations, net of current portion | Total long-term debt and finance lease obligations, net of current portion | $ | 1,588 | | | $ | 1,654 | | Total long-term debt and finance lease obligations, net of current portion | $ | 1,587 | | | $ | 1,654 | |
| Current portion of finance lease obligations | Current portion of finance lease obligations | 6 | | | 6 | | Current portion of finance lease obligations | 6 | | | 6 | |
| Total long-term debt and finance lease obligations, including current portion | Total long-term debt and finance lease obligations, including current portion | $ | 1,594 | | | $ | 1,660 | | Total long-term debt and finance lease obligations, including current portion | $ | 1,593 | | | $ | 1,660 | |
(1)The $65 million outstanding balance of the 9.25% Senior Secured Notes, due June 2023 (the “2023 UAN Notes”) was paid in full on February 22, 2022 at par, plus accrued and unpaid interest.
JuneSeptember 30, 2022 | 13
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
Credit Agreements
| | (in millions) | (in millions) | Total Available Borrowing Capacity | | Amount Borrowed as of June 30, 2022 | | Outstanding Letters of Credit | | Available Capacity as of June 30, 2022 | | Maturity Date | (in millions) | Total Available Borrowing Capacity | | Amount Borrowed as of September 30, 2022 | | Outstanding Letters of Credit | | Available Capacity as of September 30, 2022 | | Maturity Date |
| CVR Partners: | CVR Partners: | | | | | | | | | | CVR Partners: | | | | | | | | | |
Asset Based (“Nitrogen Fertilizer ABL”) Credit Agreement (1) | Asset Based (“Nitrogen Fertilizer ABL”) Credit Agreement (1) | $ | 35 | | | $ | — | | | $ | — | | | $ | 35 | | | September 30, 2024 | Asset Based (“Nitrogen Fertilizer ABL”) Credit Agreement (1) | $ | 35 | | | $ | — | | | $ | — | | | $ | 35 | | | September 30, 2024 |
| CVR Refining: | CVR Refining: | | CVR Refining: | |
Amended and Restated Asset Based (“Petroleum ABL”) Credit Agreement (2) | Amended and Restated Asset Based (“Petroleum ABL”) Credit Agreement (2) | $ | 275 | | | $ | — | | | $ | 29 | | | $ | 246 | | | June 30, 2027 | Amended and Restated Asset Based (“Petroleum ABL”) Credit Agreement (2) | $ | 275 | | | $ | — | | | $ | 28 | | | $ | 247 | | | June 30, 2027 |
(1)Beginning September 30, 2021, loans under the Nitrogen Fertilizer ABL bear interest at an annual rate equal to, at the option of the borrowers, (i) (a) 1.615% plus the daily simple Secured Overnight Financing Rate (“SOFR”) or (b) 0.615% plus a base rate, if CVR Partners’ quarterly excess availability is greater than or equal to 75%, (ii) (a) 1.865% plus SOFR or (b) 0.865% plus a base rate, if CVR Partners’ quarterly excess availability is greater than or equal to 50% but less than 75%, or (iii) (a) 2.115% plus SOFR or (b) 1.115% plus a base rate, otherwise.
(2)Beginning June 30, 2022, loans under the Petroleum ABL bear interest at an annual rate equal to, at the option of the borrowers, (i) (a) 1.50% plus the Term SOFR (as defined in the Petroleum ABL) or (b) 0.50% plus a base rate, if CVR Refining’s quarterly excess availability is greater than 50%, and (ii) (a) 1.75% plus the Term SOFR or (b) 0.75% plus a base rate, otherwise.
CVR Partners
2023 UAN Notes - On February 22, 2022, CVR Partners redeemed all of the outstanding 2023 UAN Notes at par and settled accrued and unpaid interest of approximately $1 million through, but not including, the date of redemption. As a result of this transaction, CVR Partners recognized a loss on extinguishment of debt of $1 million, which includes the write-off of unamortized deferred financing costs and discount of less than $1 million each.
CVR Refining
Petroleum ABL - On April 12, 2022, in connection with the Petroleum ABL, a new wholly owned subsidiary of CVR Energy, CVR Renewables, LLC (“CVR Renew”), delivered to Wells Fargo Bank, National Association, as administrative agent and collateral agent for the secured parties, a Joinder Agreement pursuant to which CVR Renew became a borrower for all purposes under the Petroleum ABL and other Credit Documents (as defined in the Petroleum ABL).
On June 30, 2022, CVR Refining and certain of its subsidiaries (the “Credit Parties”) entered into Amendment No. 3 to the Amended and Restated ABL Credit Agreement, dated December 20, 2012 (the “Amendment”, and as amended, the “Petroleum ABL”), with a group of lenders and Wells Fargo Bank, National Association, as administrative agent and collateral agent (the “Agent”). The Petroleum ABL is a senior secured asset based revolving credit facility in an aggregate principal amount of up to $275 million with a $125 million incremental facility, which is subject to additional lender commitments and certain other conditions. The proceeds of the loans may be used for capital expenditures, working capital and general corporate purposes of the Credit Parties and their subsidiaries. The Petroleum ABL provides for loans and letters of credit in an amount up to the aggregate availability under the facility, subject to meeting certain borrowing base conditions, with sub-limits of $30 million for swingline loans and $60 million (or $100 million if increased by the Agent) for letters of credit. The Petroleum ABL is scheduled to mature on June 30, 2027.
Loans under the Petroleum ABL bear interest at an annual rate equal to, at the option of the Credit Parties, (i) (a) 1.50% plus the Term SOFR (as defined in the Petroleum ABL) or (b) 0.50% plus a base rate, if CVR Refining’s quarterly excess availability is greater than 50%, and (ii) (a) 1.75% plus the Term SOFR or (b) 0.75% plus a base rate, otherwise. All borrowings under the Petroleum ABL are subject to the satisfaction of customary conditions, including absence of a default and accuracy of representations and warranties. The Credit Parties must also pay a commitment fee on the unutilized commitments and also pay customary letter of credit fees.
The Petroleum ABL contains customary covenants for a financing of this type and requires the Credit Parties in certain circumstances to comply with a minimum fixed charge coverage ratio test, and contains other customary restrictive covenants that limit the Credit Parties’ ability and the ability of their subsidiaries to, among other things, incur liens, engage in a
JuneSeptember 30, 2022 | 14
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
consolidation, merger and purchase or sale of assets, pay dividends, incur indebtedness, make advances, investment and loans, enter into affiliate transactions, issue equity interests, or create subsidiaries and unrestricted subsidiaries.
On July 22, 2022, in connection with the Petroleum ABL, 14 newly created indirect, wholly owned subsidiaries (the “Joining Subsidiaries”) of CVR Energy delivered to the Agent a Joinder Agreement pursuant to which such Joining Subsidiaries became borrowers for all purposes under the Petroleum ABL and other Credit Documents.
CVR Energy
2025 Notes and 2028 Notes - On April 12, 2022, in connection with the 5.25% Senior Notes, due 2025 (the “2025 Notes”) and the 5.75% Senior Notes, due 2028 (the “2028 Notes” and together with the 2025 Notes, the “Notes”), issued pursuant to the Indenture dated January 27, 2020 (the “Indenture”), among CVR Energy, the subsidiary guarantors listed therein (collectively, the “Guarantors”), and Wells Fargo Bank, National Association, as trustee (the “Trustee”), CVR Renew, the Guarantors, and the Trustee executed and delivered a Supplemental Indenture pursuant to which CVR Renew unconditionally guaranteed all of the Company’s obligations under the Notes on the terms and conditions set forth in the Note Guarantee and the Indenture.
On July 1, 2022, in connection with the Amendment, the Joining Subsidiaries that were not previously parties to the Indenture executed and delivered a Supplemental Indenture to the Trustee pursuant to which such Joining Subsidiaries unconditionally guaranteed all of the Company’s obligations under the Notes on the terms and conditions set forth in the Note Guarantee and the Indenture.
Covenant Compliance
The Company and its subsidiaries were in compliance with all covenants under their respective debt instruments as of JuneSeptember 30, 2022.
(9) Revenue
The following tables present the Company’s revenue, disaggregated by major product. The following tables also include a reconciliation of the disaggregated revenue with the Company’s reportable segments.
| | | Three Months Ended June 30, 2022 | | Six Months Ended June 30, 2022 | | Three Months Ended September 30, 2022 | | Nine Months Ended September 30, 2022 |
| (in millions) | (in millions) | Petroleum Segment | | Nitrogen Fertilizer Segment | | Other / Elimination | | Consolidated | | Petroleum Segment | | Nitrogen Fertilizer Segment | | Other / Elimination | | Consolidated | (in millions) | Petroleum Segment | | Nitrogen Fertilizer Segment | | Other / Elimination | | Consolidated | | Petroleum Segment | | Nitrogen Fertilizer Segment | | Other / Elimination | | Consolidated |
| Gasoline | Gasoline | $ | 1,421 | | | $ | — | | | $ | — | | | $ | 1,421 | | | $ | 2,524 | | | $ | — | | | $ | — | | | $ | 2,524 | | Gasoline | $ | 1,207 | | | $ | — | | | $ | — | | | $ | 1,207 | | | $ | 3,732 | | | $ | — | | | $ | — | | | $ | 3,732 | |
Distillates (1) | Distillates (1) | 1,350 | | | — | | | — | | | 1,350 | | | 2,312 | | | — | | | — | | | 2,312 | | Distillates (1) | 1,202 | | | — | | | 50 | | | 1,252 | | | 3,513 | | | — | | | 76 | | | 3,589 | |
| Ammonia | Ammonia | — | | | 61 | | | — | | | 61 | | | — | | | 103 | | | — | | | 103 | | Ammonia | — | | | 22 | | | — | | | 22 | | | — | | | 125 | | | — | | | 125 | |
| UAN | UAN | — | | | 159 | | | — | | | 159 | | | — | | | 319 | | | — | | | 319 | | UAN | — | | | 119 | | | — | | | 119 | | | — | | | 438 | | | — | | | 438 | |
| Other urea products | Other urea products | — | | | 11 | | | — | | | 11 | | | — | | | 20 | | | — | | | 20 | | Other urea products | — | | | 6 | | | — | | | 6 | | | — | | | 26 | | | — | | | 26 | |
| Freight revenue | Freight revenue | 4 | | | 10 | | | — | | | 14 | | | 8 | | | 19 | | | — | | | 27 | | Freight revenue | 4 | | | 7 | | | — | | | 11 | | | 13 | | | 27 | | | — | | | 40 | |
Other (2) | Other (2) | 81 | | | 3 | | | 32 | | | 116 | | | 160 | | | 6 | | | 28 | | | 194 | | Other (2) | 49 | | | 2 | | | 19 | | | 70 | | | 209 | | | 7 | | | 20 | | | 236 | |
| Revenue from product sales | Revenue from product sales | 2,856 | | | 244 | | | 32 | | | 3,132 | | | 5,004 | | | 467 | | | 28 | | | 5,499 | | Revenue from product sales | 2,462 | | | 156 | | | 69 | | | 2,687 | | | 7,467 | | | 623 | | | 96 | | | 8,186 | |
| | Crude oil sales | Crude oil sales | 12 | | | — | | | — | | | 12 | | | 17 | | | — | | | — | | | 17 | | Crude oil sales | 12 | | | — | | | — | | | 12 | | | 29 | | | — | | | — | | | 29 | |
Other revenue (2) | Other revenue (2) | — | | | — | | | — | | | — | | | 1 | | | — | | | — | | | 1 | | Other revenue (2) | — | | | — | | | — | | | — | | | 1 | | | — | | | — | | | 1 | |
| Total revenue | Total revenue | $ | 2,868 | | | $ | 244 | | | $ | 32 | | | $ | 3,144 | | | $ | 5,022 | | | $ | 467 | | | $ | 28 | | | $ | 5,517 | | Total revenue | $ | 2,474 | | | $ | 156 | | | $ | 69 | | | $ | 2,699 | | | $ | 7,497 | | | $ | 623 | | | $ | 96 | | | $ | 8,216 | |
|
JuneSeptember 30, 2022 | 15
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
| | | Three Months Ended June 30, 2021 | | Six Months Ended June 30, 2021 | | Three Months Ended September 30, 2021 | | Nine Months Ended September 30, 2021 |
| (in millions) | (in millions) | Petroleum Segment | | Nitrogen Fertilizer Segment | | Other / Elimination | | Consolidated | | Petroleum Segment | | Nitrogen Fertilizer Segment | | Other / Elimination | | Consolidated | (in millions) | Petroleum Segment | | Nitrogen Fertilizer Segment | | Other / Elimination | | Consolidated | | Petroleum Segment | | Nitrogen Fertilizer Segment | | Other / Elimination | | Consolidated |
| Gasoline | Gasoline | $ | 908 | | | $ | — | | | $ | — | | | $ | 908 | | | $ | 1,657 | | | $ | — | | | $ | — | | | $ | 1,657 | | Gasoline | $ | 962 | | | $ | — | | | $ | — | | | $ | 962 | | | $ | 2,619 | | | $ | — | | | $ | — | | | $ | 2,619 | |
Distillates (1) | Distillates (1) | 685 | | | — | | | — | | | 685 | | | 1,273 | | | — | | | — | | | 1,273 | | Distillates (1) | 723 | | | — | | | — | | | 723 | | | 1,996 | | | — | | | — | | | 1,996 | |
| Ammonia | Ammonia | — | | | 32 | | | — | | | 32 | | | — | | | 42 | | | — | | | 42 | | Ammonia | — | | | 27 | | | — | | | 27 | | | — | | | 68 | | | — | | | 68 | |
| UAN | UAN | — | | | 87 | | | — | | | 87 | | | — | | | 126 | | | — | | | 126 | | UAN | — | | | 99 | | | — | | | 99 | | | — | | | 224 | | | — | | | 224 | |
| Other urea products | Other urea products | — | | | 7 | | | — | | | 7 | | | — | | | 11 | | | — | | | 11 | | Other urea products | — | | | 8 | | | — | | | 8 | | | — | | | 20 | | | — | | | 20 | |
| Freight revenue | Freight revenue | 5 | | | 9 | | | — | | | 14 | | | 11 | | | 15 | | | — | | | 26 | | Freight revenue | 5 | | | 9 | | | — | | | 14 | | | 16 | | | 24 | | | — | | | 40 | |
Other (2) | Other (2) | 41 | | | 3 | | | (3) | | | 41 | | | 73 | | | 5 | | | (5) | | | 73 | | Other (2) | 45 | | | 2 | | | (4) | | | 43 | | | 117 | | | 8 | | | (8) | | | 117 | |
| Revenue from product sales | Revenue from product sales | 1,639 | | | 138 | | | (3) | | | 1,774 | | | 3,014 | | | 199 | | | (5) | | | 3,208 | | Revenue from product sales | 1,735 | | | 145 | | | (4) | | | 1,876 | | | 4,748 | | | 344 | | | (8) | | | 5,084 | |
| | Crude oil sales | Crude oil sales | 8 | | | — | | | — | | | 8 | | | 37 | | | — | | | — | | | 37 | | Crude oil sales | 6 | | | — | | | — | | | 6 | | | 43 | | | — | | | — | | | 43 | |
Other revenue (2) | Other revenue (2) | 1 | | | — | | | — | | | 1 | | | 1 | | | — | | | — | | | 1 | | Other revenue (2) | 1 | | | — | | | — | | | 1 | | | 2 | | | — | | | — | | | 2 | |
| Total revenue | Total revenue | $ | 1,648 | | | $ | 138 | | | $ | (3) | | | $ | 1,783 | | | $ | 3,052 | | | $ | 199 | | | $ | (5) | | | $ | 3,246 | | Total revenue | $ | 1,742 | | | $ | 145 | | | $ | (4) | | | $ | 1,883 | | | $ | 4,793 | | | $ | 344 | | | $ | (8) | | | $ | 5,129 | |
|
(1)Distillates consist primarily of diesel fuel, kerosene, jet fuel, and jet fuel.renewable fuels activity.
(2)Other revenue consists primarily of renewable fuels activity, feedstock, asphalt sales, and pipeline and processing fees.
Transaction Price Allocated to Remaining Performance Obligations
As of JuneSeptember 30, 2022, the Nitrogen Fertilizer Segment had approximately $8$7 million of remaining performance obligations for contracts with an original expected duration of more than one year. The Nitrogen Fertilizer Segment expects to recognize approximately $4$2 million of these performance obligations as revenue by the end of 2022, an additional $4 million in 2023, and a nominal amountthe remaining balance thereafter.
Contract Balances
The Nitrogen Fertilizer Segment’s deferred revenue is a contract liability that primarily relates to nitrogen fertilizer sales contracts requiring customer prepayment prior to product delivery to guarantee a price and supply of nitrogen fertilizer. A summary of the Nitrogen Fertilizer Segment’s deferred revenue activity during the sixnine months ended JuneSeptember 30, 2022 is presented below:
| | | | | |
| (in millions) | |
| Balance at December 31, 2021 | $ | 87 | |
| Add: | |
New prepay contracts entered into during the period (1) | 1680 | |
| Less: | |
| Revenue recognized that was included in the contract liability balance at the beginning of the period | (84)(86) | |
| Revenue recognized related to contracts entered into during the period | (14)(16) | |
Other changes | (1) | |
Balance at JuneSeptember 30, 2022 | $ | 465 | |
(1) Includes $16 million where paymentSubstantially all of the payments associated with prepaid contracts waswere collected as of JuneSeptember 30, 2022.
(10) Derivative Financial Instruments, Investments and Fair Value Measurements
Derivative Financial Instruments
Our segments are subject to fluctuations of commodity prices caused by supply and economic conditions, weather, interest rates, and other factors. To manage the impact of price fluctuations of crude oil and other commodities in our results of operations and certain inventories, and to fix margins on future sales and purchases, the Petroleum Segment uses various
JuneSeptember 30, 2022 | 16
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
operations and certain inventories, and to fix margins on future sales and purchases, the Petroleum Segment uses various commodity derivative instruments, such as futures and swaps. The Company has not designated any of its derivative contracts as hedge accounting and records changes in fair value and cash settlements on the condensed consolidated statements of operations.
On a regular basis, the Company enters into commodity contracts with counterparties for the purchases or sale of crude oil, blendstocks, various finished products, and RINs. These contracts usually qualify for the normal purchase normal sale exception and follow the accrual method of accounting. The Petroleum Segment may enter into forward purchase or sale contracts associated with RINs. As of JuneSeptember 30, 2022, the Petroleum Segment had open fixed-price commitments to purchase a net amount of 1932 million RINs. All other derivative instruments are recorded at fair value using mark-to-market accounting on a periodic basis utilizing third-party pricing.
The following outlines the net notional buy (sell) position of our commodity derivative instruments held as of JuneSeptember 30, 2022 and December 31, 2021:
| | (in thousands of barrels) | (in thousands of barrels) | Commodity | | June 30, 2022 | | December 31, 2021 | (in thousands of barrels) | Commodity | | September 30, 2022 | | December 31, 2021 |
| Forwards | Forwards | Crude | | 519 | | | 67 | | Forwards | Crude | | (1,640) | | | 67 | |
| Swaps | Group 3 Diesel Cracks | | (1,100) | | | — | | |
| | Futures | Futures | Crude | | — | | | (20) | | Futures | Crude | | — | | | (20) | |
| Futures | Futures | ULSD | | (528) | | | (220) | | Futures | ULSD | | (225) | | | (220) | |
| Futures | Soybean | | 109 | | | — | | |
|
The following outlines the realized and unrealized gains (losses) gains incurred from derivative activities, all of which arewere recorded in Cost of materials and other on the condensed consolidated statements of operations:
| | | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | Three Months Ended
September 30, | | Nine Months Ended
September 30, |
| (in millions) | (in millions) | 2022 | | 2021 | | 2022 | | 2021 | (in millions) | 2022 | | 2021 | | 2022 | | 2021 |
| Forwards | Forwards | $ | (4) | | | $ | 4 | | | $ | 6 | | | $ | 22 | | Forwards | $ | 13 | | | $ | 2 | | | $ | 18 | | | $ | 24 | |
| Swaps | Swaps | (49) | | | (5) | | | (48) | | | (55) | | Swaps | (1) | | | (13) | | | (48) | | | (68) | |
| Futures | Futures | (15) | | | (1) | | | (24) | | | (1) | | Futures | 11 | | | (1) | | | (13) | | | (2) | |
| Total loss on derivatives, net | $ | (68) | | | $ | (2) | | | $ | (66) | | | $ | (34) | | |
| Total gain (loss) on derivatives, net | | Total gain (loss) on derivatives, net | $ | 23 | | | $ | (12) | | | $ | (43) | | | $ | (46) | |
Offsetting Assets and Liabilities
The following outlines the condensed consolidated balance sheetssheet line items that include our derivative financial instruments and the effect of the collateral netting. Such amounts are presented on a gross basis, before the effects of collateral netting. The Company elected to offset the derivative assets and liabilities with the same counterparty on a net basis when the legal right of offset exists.
| | | June 30, 2022 | | December 31, 2021 | | September 30, 2022 | | December 31, 2021 |
| | Derivatives | | Collateral Netting | | Net Value | | Derivatives | | Collateral Netting | | Net Value | | Derivatives | | Collateral Netting | | Net Value | | Derivatives | | Collateral Netting | | Net Value |
| (in millions) | (in millions) | Assets | | Liabilities | | Assets | | Liabilities | | (in millions) | Assets | | Liabilities | | Assets | | Liabilities | |
| Prepaid expenses and other current assets | Prepaid expenses and other current assets | $ | 8 | | | $ | (3) | | | $ | — | | | $ | 5 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | Prepaid expenses and other current assets | $ | 7 | | | $ | (2) | | | $ | — | | | $ | 5 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | |
| Other current liabilities | Other current liabilities | — | | | (20) | | | — | | | (20) | | | 5 | | | (7) | | | — | | | (2) | | Other current liabilities | — | | | — | | | — | | | — | | | 5 | | | (7) | | | — | | | (2) | |
At JuneSeptember 30, 2022 and December 31, 2021, the Company had $4$7 million and $4 million of collateral under master netting arrangements not offset against the derivatives within Prepaid expenses and other current assets on the condensed consolidated balance sheets, respectively, primarily related to initial margin requirements. Certain of ourOur derivative instruments may contain credit risk-related contingent provisions associated with our credit ratings. If our credit rating were to be downgraded, it would allow the counterparty to require us to post collateral or to request immediate, full settlement of derivative instruments in liability positions. There are no derivative liabilities with credit risk-related contingent provisions as of September 30, 2022, and no collateral has been posted.
JuneSeptember 30, 2022 | 17
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
liability positions. The aggregate fair value of our derivative liabilities with credit risk-related contingent provisions as of June 30, 2022 was $17 million, for which no collateral has been posted.
Investments
Investments consistconsisted of equity securities, which are reported at fair value in Prepaid expenses and other current assets on our condensed consolidated balance sheets. These investments arewere considered trading securities. Investment (loss) income on marketable securities consistsconsisted of the following:
| | | | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended
June 30, | | Six Months Ended
June 30, |
| (in millions) | 2022 | | 2021 | | 2022 | | 2021 |
| | | | | | | |
| Gain on marketable securities | $ | — | | | $ | 21 | | | $ | — | | | $ | 83 | |
| Investment income on marketable securities | $ | — | | | $ | 21 | | | $ | — | | | $ | 83 | |
| | | | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended
September 30, | | Nine Months Ended
September 30, |
| (in millions) | 2022 | | 2021 | | 2022 | | 2021 |
| | | | | | | |
| Gain (loss) on marketable securities | $ | — | | | $ | (1) | | | $ | — | | | $ | 82 | |
| Investment (loss) income on marketable securities | $ | — | | | $ | (1) | | | $ | — | | | $ | 82 | |
On January 18, 2022, the Company divested its remaining nominal investment in Delek US Holdings, Inc. (“Delek”). As of JuneSeptember 30, 2022, the Company did not hold any investment in Delek.
Fair Value Measurements
In accordance with FASB ASC Topic 820 — Fair Value Measurements and Disclosures (“ASC 820”), the Company utilizes the market approach to measure fair value for its financial assets and liabilities. The market approach uses prices and other relevant information generated by market transactions involving identical or comparable assets, liabilities or a group of assets or liabilities, such as a business.
ASC 820 utilizes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three broad levels. The following is a brief description of those three levels:
•Level 1 — Quoted prices in active markets for identical assets or liabilities
•Level 2 — Other significant observable inputs (including quoted prices in active markets for similar assets or liabilities)
•Level 3 — Significant unobservable inputs (including the Company’s own assumptions in determining the fair value)
The following tables set forth the assets and liabilities measured or disclosed at fair value on a recurring basis, by input level, as of JuneSeptember 30, 2022 and December 31, 2021:
| | | June 30, 2022 | | September 30, 2022 |
| (in millions) | (in millions) | Level 1 | | Level 2 | | Level 3 | | | Total | (in millions) | Level 1 | | Level 2 | | Level 3 | | | Total |
| Location and description | Location and description | | | | | | | | | Location and description | | | | | | | | |
| | Other current assets (derivative financial instruments) | $ | — | | | $ | 5 | | | $ | — | | | $ | 5 | | |
| Prepaid expenses and other current assets (derivative financial instruments) | | Prepaid expenses and other current assets (derivative financial instruments) | $ | — | | | $ | 5 | | | $ | — | | | $ | 5 | |
| | Total assets | Total assets | $ | — | | | $ | 5 | | | $ | — | | | $ | 5 | | Total assets | $ | — | | | $ | 5 | | | $ | — | | | $ | 5 | |
| | Other current liabilities (derivative financial instruments) | $ | — | | | $ | (20) | | | $ | — | | | $ | (20) | | |
| | Other current liabilities (RFS obligations) | Other current liabilities (RFS obligations) | — | | | (708) | | | — | | | (708) | | Other current liabilities (RFS obligations) | $ | — | | | $ | (715) | | | $ | — | | | $ | (715) | |
| Long-term debt and finance lease obligations, net of current portion (long-term debt) | Long-term debt and finance lease obligations, net of current portion (long-term debt) | — | | | (1,392) | | | — | | | (1,392) | | Long-term debt and finance lease obligations, net of current portion (long-term debt) | — | | | (1,361) | | | — | | | (1,361) | |
| Total liabilities | Total liabilities | $ | — | | | $ | (2,120) | | | $ | — | | | $ | (2,120) | | Total liabilities | $ | — | | | $ | (2,076) | | | $ | — | | | $ | (2,076) | |
JuneSeptember 30, 2022 | 18
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
| | | December 31, 2021 | | December 31, 2021 |
| (in millions) | (in millions) | Level 1 | | Level 2 | | Level 3 | | | Total | (in millions) | Level 1 | | Level 2 | | Level 3 | | | Total |
| Location and description | Location and description | | | | | | | | | Location and description | | | | | | | | |
| | Other current assets (derivative financial instruments) | $ | — | | | $ | 1 | | | $ | — | | | | $ | 1 | | |
| Prepaid expenses and other current assets (derivative financial instruments) | | Prepaid expenses and other current assets (derivative financial instruments) | $ | — | | | $ | 1 | | | $ | — | | | | $ | 1 | |
| | Total assets | Total assets | $ | — | | | $ | 1 | | | $ | — | | | | $ | 1 | | Total assets | $ | — | | | $ | 1 | | | $ | — | | | | $ | 1 | |
| | Other current liabilities (derivative financial instruments) | Other current liabilities (derivative financial instruments) | $ | — | | | $ | (2) | | | $ | — | | | | $ | (2) | | Other current liabilities (derivative financial instruments) | $ | — | | | $ | (2) | | | $ | — | | | | $ | (2) | |
| Other current liabilities (RFS obligations) | Other current liabilities (RFS obligations) | — | | | (494) | | | — | | | | (494) | | Other current liabilities (RFS obligations) | — | | | (494) | | | — | | | | (494) | |
| Long-term debt and finance lease obligations, net of current portion (long-term debt) | Long-term debt and finance lease obligations, net of current portion (long-term debt) | — | | | (1,620) | | | — | | | | (1,620) | | Long-term debt and finance lease obligations, net of current portion (long-term debt) | — | | | (1,620) | | | — | | | | (1,620) | |
| Total liabilities | Total liabilities | $ | — | | | $ | (2,116) | | | $ | — | | | | $ | (2,116) | | Total liabilities | $ | — | | | $ | (2,116) | | | $ | — | | | | $ | (2,116) | |
As of JuneSeptember 30, 2022 and December 31, 2021, the only financial assets and liabilities that are measured at fair value on a recurring basis are the Company’s investments, derivative instruments, and the RFS obligations. The estimated fair value of cash equivalents, including amounts invested in short-term money market funds, and restricted cash approximate their carrying amounts. The Petroleum Segment’s commodity derivative contracts and RFS obligations, which use fair value measurements and are valued using broker quoted market prices of similar instruments, are considered Level 2 inputs. The Company had no transfers of assets or liabilities between any of the above levels during the sixnine months ended JuneSeptember 30, 2022.2022 and year ended December 31, 2021.
(11) Share-Based Compensation
A summary of compensation expense during the three and sixnine months ended JuneSeptember 30, 2022 and 2021 is presented below:
| | | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | Three Months Ended
September 30, | | Nine Months Ended
September 30, |
| (in millions) | (in millions) | 2022 | | 2021 | | 2022 | | 2021 | (in millions) | 2022 | | 2021 | | 2022 | | 2021 |
| Performance Unit Awards | Performance Unit Awards | $ | — | | | $ | — | | | $ | — | | | $ | (3) | | Performance Unit Awards | $ | — | | | $ | — | | | $ | — | | | $ | (3) | |
| | CVR Partners - Phantom Unit Awards | CVR Partners - Phantom Unit Awards | (3) | | | 7 | | | 11 | | | 12 | | CVR Partners - Phantom Unit Awards | 9 | | | 6 | | | 20 | | | 18 | |
| Incentive Unit Awards | Incentive Unit Awards | 14 | | | 5 | | | 25 | | | 11 | | Incentive Unit Awards | 4 | | | 5 | | | 29 | | | 16 | |
| Total share-based compensation expense | Total share-based compensation expense | $ | 11 | | | $ | 12 | | | $ | 36 | | | $ | 20 | | Total share-based compensation expense | $ | 13 | | | $ | 11 | | | $ | 49 | | | $ | 31 | |
(12) Commitments and Contingencies
Except as described below, there have been no material changes in the Company’s commitments and contingencies disclosed in the 2021 Form 10-K and first and second quarter 2022 FormForms 10-Q. In the ordinary course of business, the Company may become party to lawsuits, administrative proceedings, and governmental investigations, including environmental, regulatory, and other matters. The outcome of these matters cannot always be predicted accurately, but the Company accrues liabilities for these matters if the Company has determined that it is probable a loss has been incurred and the loss can be reasonably estimated. While it is not possible to predict the outcome of such proceedings, if one or more of them were decided against us, the Company believes there would be no material impact on its consolidated financial statements.
The Company continues to monitor its contractual arrangements and customer, vendor, and supplier relationships to determine whether and to what extent, if any, the impacts of the COVID-19 pandemic, the Russia-Ukraine conflict, the current global and domestic economic environment, including increasing interest rates and inflation or a potential recession, or ongoing crude oil, refined product, or utility price volatility will impair or excuse the performance of the Company or its subsidiaries or their customers, vendors, or suppliers under existing agreements. As of JuneSeptember 30, 2022, the Company had not experienced a material financial impact from any actual or threatened impairment of or excuse in its or others’ performance under such agreements.
Crude Oil Supply Agreement
Effective on August 4, 2021, an indirect, wholly owned subsidiary of CVR Refining entered into the Second Amended and Restated Crude Oil Supply Agreement (the “Crude Oil Supply Agreement”) with Vitol Inc. (“Vitol”), which superseded, in its entirety, the August 31, 2012 Amended and Restated Crude Oil Supply Agreement between the parties. Under the Crude Oil Supply Agreement, Vitol supplies the Petroleum Segment with crude oil and intermediation logistics helping to reduce the
amount of inventory held at certain locations and mitigate crude oil pricing risk. Volumes contracted under the Crude Oil Supply Agreement, as a percentage of the total crude oil purchases (in barrels), were approximately 30% and 42%41% for the three months ended JuneSeptember 30, 2022 and 2021, respectively, and approximately 34%33% and 40%43% for the sixnine months ended JuneSeptember 30, 2022 and 2021, respectively. The Crude Oil Supply Agreement, which currently extends through December 31, 2022, automatically renews for successive one-year terms (each such term, a “Renewal Term”) unless either party provides the other with notice of non-renewal at least 180 days prior to expiration of the term or any Renewal Term.
Renewable Fuel Standards
The Company’s Petroleum Segment is subject to the RFS, implemented by the Environmental Protection Agency (the “EPA”), which requires refiners to either blend renewable fuels into their transportation fuels or purchase renewable fuel credits, known as RINs, in lieu of blending. The Petroleum Segment is not able to blend the substantial majority of its transportation fuels and must either purchase RINs or obtain waiver credits for cellulosic biofuels, or other exemptions from the EPA, in order to comply with the RFS. Additionally, the Petroleum Segment purchases RINs generated from our renewable diesel operations, whose operating results are included in the Other Segment, to partially satisfy its RFS obligations.
The Petroleum SegmentCompany recognized an expense of $153$86 million and $173a benefit of $16 million for the three months ended JuneSeptember 30, 2022 and 2021, respectively, and $259expense of $328 million and $351$335 million for the sixnine months ended JuneSeptember 30, 2022 and 2021, respectively, for its compliance with the RFS (based on the 2020, 2021 and 2022 renewable volume obligation (“RVO”), for the respective periods, excluding the impacts of any exemptions or waivers to which the Petroleum SegmentCompany may be entitled). The recognized amounts are included within Cost of materials and other in the condensed consolidated statements of operations and represent costs to comply with the RFS obligation through purchasing of RINs not otherwise reduced by blending of ethanol, biodiesel, or renewable diesel. At each reporting period, to the extent RINs purchased and generated through blending are less than the RFS obligation (excluding the impact of exemptions or waivers to which the Petroleum SegmentCompany may be entitled), the remaining position is marked-to-marketvalued using RIN market prices at period end. As of JuneSeptember 30, 2022 and December 31, 2021, the Petroleum Segment’sCompany’s RFS position waspositions were approximately $708$715 million and $494 million, respectively, which isand are recorded in Other current liabilities in the condensed consolidated balance sheets.
Litigation
The U.S. Attorney’s office for the Southern District of New York contacted CVR Energy in September 2017 seeking production of information pertaining to CVR Refining’s, CVR Energy’s and Mr. Carl C. Icahn’s activities relating to the RFS and Mr. Icahn’s former role as an advisor to former President Trump. CVR Energy cooperated with the request and provided information in response to the subpoena. The U.S. Attorney’s office has not made any claims or allegations against CVR Energy or Mr. Icahn. CVR Energy believes it maintains a strong compliance program and, while no assurances can be made, CVR Energy does not believe this inquiry will have a material impact on its business, financial condition, results of operations or cash flows.
Call Option Lawsuits – On July 20,August 19, 2022, the Company and certain of its affiliates (the “Call Defendants”) who are parties to the consolidated lawsuits (collectively, the “Call Option Lawsuits”) pending before the Delaware Court of Chancery (the “Chancery Court”), primarily alleging breach of contract, tortious interference and breach of the implied covenant of good faith and fair dealing and seeking monetary damages and attorneys’ fees, among other remedies, filed by purported former unitholders of CVR Refining on behalf of themselves and an alleged class of similarly situated unitholders relating to the Company’s exercise of the call option under the CVR Refining Amended and Restated Agreement of Limited Partnership assigned to it by CVR Refining’s general partner, entered into a confidential, binding term sheet pursuant to which the Company, Call DefendantsStipulation, Compromise and plaintiffs areRelease (the “Settlement”) in connection with its expected to execute a final agreement to settlesettlement of the Call Option Lawsuits for $79 million, subject tomillion. Final approval byof the Settlement is pending before the Chancery Court and other conditions contained therein.Court. If finalized, settlement of the Call Option LawsuitsSettlement is not currently expected to have any further impact on the Company’s financial position or results of operations beyond the $79 million recognized within Other current liabilities and Otherincome (expense) income,, net as of Junefor the nine months ended September 30, 2022 to reflect the estimated probable loss.
The lawsuitsIn October 2022, the Call Defendants filed a First Amended Complaint in Chancery Court alleging Breach of Contract and Breach of the Implied Covenant of Good Faith and Fair Dealing against their primary and excess insurers (the “Insurers”) relating to insurancetheir denial of coverage forof the Call Defendants’ defense expenses and indemnity, as well as other conduct of the Insurers relating to the Call Option Lawsuits, oneLawsuits. Also in October 2022, the Call Defendants filed motions to oppose the Insurers’ Motion for Partial Summary Judgment in the lawsuit filed by the Insurers on January 27, 2021, in the 434th Judicial District Court of Fort Bend County, Texas by the Call Defendants’ primary and excess insurers (the “Insurers”) seeking a declaratory judgment determining that they owe no indemnity coverage for the Call Option Lawsuits in relation to insurance policies that have coverage limits of $50 million, and another filed on January 30, 2022, in the Superior Court of the State of Delaware by the Call Defendants against the Insurers for anticipatory breach of contract and breach of the implied covenant of good faith and fair dealing (the “Delaware Coverage Case”), remain pending, and pre-trial proceedings are in process. The
Company intends to vigorously pursue recovery of the $79 million it expects to pay in settlement of the Call Option Lawsuits and other damages allowed by law from its primary and excess insurers in the event the Chancery Court approves the settlement.million. As both lawsuits are in their early stages, the Company cannot determine at this time the outcome of these lawsuits, including whether the outcome would have a material impact on the Company’s financial position, results of operations, or cash flows.
RFS Disputes – In April 2022,The Company has filed a number of petitions in the EPA (a) denied 36United States Court of Appeals for the Fifth Circuit and the United States Court of Appeals for the District of Colombia Circuit challenging the EPA’s denial of small refinery exemptions (“SREs”) under the RFS, including one the EPA had previously granted tosought by Wynnewood Refining Company, LLC (“WRC”) for the 2018 compliance period, which previous grant was initially made by the EPA months after its required deadline causing harm to WRC; and (b) issued an alternate compliance ruling under which certain small refineries, including WRC for 2018, were not required to purchase or redeem additional RFS credits as a result of the EPA’s denial (the “Alternate Compliance Ruling”). In June 2022, the EPA (c) denied WRC’s 2017 SRE, which had been previously granted by the EPA, and also denied WRC’s SREs for 2019, 2020 and 2021, which had been previously pending before the EPA, and (d) added to its April 2022 Alternate Compliance Ruling WRC’s now-denied 2017 SRE. In June 2022, WRC filed petitions challenging the EPA’s improper denial of WRC’s 2018 SRE and the Alternate Compliance Ruling. In July and August 2022, WRC filed petitions challenging the EPA’s improper denial of WRC’s SREs for the 2017 and 2019 tothrough 2021 compliance periods, the EPA’s April 2022 and June 2022 alternate compliance rulings and the EPA’s Final Rule filed in July 2022 establishing RVO, and also intervened in an action filed by certain biofuels producers against the EPA relating to the Alternate Compliance Ruling.RFS. As each of these proceedings is in its earliestpreliminary stages, the Company cannot determine at this time the outcomes of these matters. However, while we firmly believe the EPA’s actions are unlawful and violate the RFS, and whileWhile we intend to pursue all available legal remedies,prosecute these actions vigorously, if these matters are ultimately concluded in a manner adverse to the Company, they could have a material effect on the Company’s financial position, results of operations, or cash flows.
Environmental, Health, and Safety (“EHS”) Matters
Clean Air Act Matter - In MayAugust 2022, CRRM appealedthe United States Court of Appeals for the Tenth Circuit granted CRRM’s motion to the 10th Circuitstay its appeal of the March 30, 2022 decision of the United States District Court for the District of Kansas (“D. Kan.”) denying CRRM’s petition for judicial review of approximately $6.8 million in stipulated penalties (the “Stipulated Claims”) being sought by the United States (on behalf of the EPA) and the State of Kansas, through the Kansas Department of Health and Environment (“KDHE”) in connection with their allegations that CRRM violated the CAAFederal Clean Air Act (the “CAA”) and a 2012 Consent Decree (the “CD”) between CRRM, the United States (on behalf of the EPA) and KDHE at CRRM’s Coffeyville refinery, primarily relating to flares. CRRM previously deposited funds into a commercial escrow account relating to the Stipulated Claims, and such funds are legally restricted for use and are included within Prepaid expenses and other current assets on the condensed consolidated balance sheets. Briefing relating to the appropriate jurisdiction of the appeal is in process.
On March 21, 2022, CRRM filed a Motion to Dismiss certain claimspractice in the first amended supplemental complaintlawsuit filed by the United States (on behalf of the EPA) and KDHE, which complaint was amended on February 17, 2022 (the “Amended Complaint”), alleging violations of the CAA, the Kansas State Implementation Plan, Kansas law, 40 C.F.R. Part 63 and CRRM’s permits relating to flares, heaters, and related matters and seeking civil penalties, injunctive and related relief (collectively, the “Statutory Claims”)., is ongoing. In October 2022, the D. Kan granted CRRM’s Motionmostion to Dismiss remains pending before D. Kan.dismiss counts 1 through 17 of the Amended Complaint alleging violations of certain provisions of the Kansas Air Quality Act but denied its motion to dismiss all other Statutory Claims. CRRM expects to file an answer to the Amended Complaint in November 2022.
As negotiations and proceedings relating to the Stipulated Claims and the Statutory Claims are ongoing, the Company cannot determine at this time the outcome of these matters, including whether such outcome, or any subsequent enforcement or litigation relating thereto would have a material impact on the Company’s financial position, results of operations, or cash flows.
(13) Business Segments
CVR Energy’s revenues are primarily derived from 2two reportable segments: the Petroleum Segment and the Nitrogen Fertilizer Segment. The Company evaluates the performance of its segments based primarily on segment operating income (loss) and Earnings Before Interest, Taxes, Depreciation, and Amortization (“EBITDA”). For the purposes of the business segments disclosure, the Company presents operating income (loss) as it is the most comparable measure to the amounts presented on the condensed consolidated statements of operations. The other amounts reflect renewable fuels activities, intercompany eliminations, corporate cash and cash equivalents, income tax activities, and other corporate activities that are not allocated or aggregated to the reportable segments.
JuneSeptember 30, 2022 | 19
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
The following table summarizes certain operating results and capital expenditures information by segment:
| | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | Three Months Ended
September 30, | | Nine Months Ended
September 30, |
| (in millions) | (in millions) | 2022 | | 2021 | | 2022 | | 2021 | (in millions) | 2022 | | 2021 | | 2022 | | 2021 |
| Net sales: | Net sales: | | | | | | | | Net sales: | | | | | | | |
| Petroleum | Petroleum | $ | 2,868 | | | $ | 1,648 | | | $ | 5,022 | | | $ | 3,052 | | Petroleum | $ | 2,474 | | | $ | 1,742 | | | $ | 7,497 | | | $ | 4,793 | |
| Nitrogen Fertilizer | Nitrogen Fertilizer | 244 | | | 138 | | | 467 | | | 199 | | Nitrogen Fertilizer | 156 | | | 145 | | | 623 | | | 344 | |
Other, including intersegment eliminations (1) | Other, including intersegment eliminations (1) | 32 | | | (3) | | | 28 | | | (5) | | Other, including intersegment eliminations (1) | 69 | | | (4) | | | 96 | | | (8) | |
| Total net sales | Total net sales | $ | 3,144 | | | $ | 1,783 | | | $ | 5,517 | | | $ | 3,246 | | Total net sales | $ | 2,699 | | | $ | 1,883 | | | $ | 8,216 | | | $ | 5,129 | |
| | Operating income (loss): | Operating income (loss): | | | | | | | | Operating income (loss): | | | | | | | |
| Petroleum | Petroleum | $ | 297 | | | $ | (20) | | | $ | 427 | | | $ | (136) | | Petroleum | $ | 137 | | | $ | 135 | | | $ | 564 | | | $ | (1) | |
| Nitrogen Fertilizer | Nitrogen Fertilizer | 126 | | | 30 | | | 230 | | | 16 | | Nitrogen Fertilizer | (12) | | | 46 | | | 218 | | | 63 | |
Other, including intersegment eliminations (1) | Other, including intersegment eliminations (1) | (21) | | | (4) | | | (34) | | | (9) | | Other, including intersegment eliminations (1) | (22) | | | (6) | | | (56) | | | (16) | |
| Total operating income (loss) | Total operating income (loss) | 402 | | | 6 | | | 623 | | | (129) | | Total operating income (loss) | 103 | | | 175 | | | 726 | | | 46 | |
| Interest expense, net | Interest expense, net | (23) | | | (38) | | | (48) | | | (69) | | Interest expense, net | (19) | | | (23) | | | (67) | | | (92) | |
| Investment income on marketable securities | — | | | 21 | | | — | | | 83 | | |
| Other (expense) income, net | (74) | | | 3 | | | (84) | | | 10 | | |
| Income (loss) before income tax expense | $ | 305 | | | $ | (8) | | | $ | 491 | | | $ | (105) | | |
| Investment (loss) income on marketable securities | | Investment (loss) income on marketable securities | — | | | (1) | | | — | | | 82 | |
| Other income (expense), net | | Other income (expense), net | 3 | | | 2 | | | (81) | | | 12 | |
| Income before income tax expense | | Income before income tax expense | $ | 87 | | | $ | 153 | | | $ | 578 | | | $ | 48 | |
| Depreciation and amortization: | Depreciation and amortization: | | | | | | | | Depreciation and amortization: | | | | | | | |
| Petroleum | Petroleum | $ | 46 | | | $ | 51 | | | $ | 93 | | | $ | 102 | | Petroleum | $ | 47 | | | $ | 50 | | | $ | 140 | | | $ | 152 | |
| Nitrogen Fertilizer | Nitrogen Fertilizer | 21 | | | 21 | | | 42 | | | 35 | | Nitrogen Fertilizer | 22 | | | 18 | | | 64 | | | 52 | |
Other (1) | Other (1) | 6 | | | — | | | 5 | | | 1 | | Other (1) | 6 | | | (1) | | | 11 | | | 1 | |
| Total depreciation and amortization | Total depreciation and amortization | $ | 73 | | | $ | 72 | | | $ | 140 | | | $ | 138 | | Total depreciation and amortization | $ | 75 | | | $ | 67 | | | $ | 215 | | | $ | 205 | |
Capital expenditures: (2) | Capital expenditures: (2) | | | | | | | | Capital expenditures: (2) | | | | | | | |
| Petroleum | Petroleum | $ | 19 | | | $ | 9 | | | $ | 38 | | | $ | 19 | | Petroleum | $ | 23 | | | $ | 12 | | | $ | 61 | | | $ | 31 | |
| Nitrogen Fertilizer | Nitrogen Fertilizer | 9 | | | 4 | | | 14 | | | 7 | | Nitrogen Fertilizer | 25 | | | 7 | | | 39 | | | 14 | |
Other (1) | Other (1) | 13 | | | 70 | | | 39 | | | 125 | | Other (1) | 20 | | | 19 | | | 59 | | | 144 | |
| Total capital expenditures | Total capital expenditures | $ | 41 | | | $ | 83 | | | $ | 91 | | | $ | 151 | | Total capital expenditures | $ | 68 | | | $ | 38 | | | $ | 159 | | | $ | 189 | |
The following table summarizes total assets by segment:
| | (in millions) | (in millions) | June 30, 2022 | | December 31, 2021 | (in millions) | September 30, 2022 | | December 31, 2021 |
| | Petroleum | Petroleum | $ | 4,280 | | | $ | 3,368 | | Petroleum | $ | 4,247 | | | $ | 3,368 | |
| Nitrogen Fertilizer | Nitrogen Fertilizer | 1,119 | | | 1,127 | | Nitrogen Fertilizer | 1,083 | | | 1,127 | |
Other, including intersegment eliminations (1) | Other, including intersegment eliminations (1) | (728) | | | (589) | | Other, including intersegment eliminations (1) | (1,124) | | | (589) | |
| Total assets | Total assets | $ | 4,671 | | | $ | 3,906 | | Total assets | $ | 4,206 | | | $ | 3,906 | |
|
(1)Other includes amounts for the Wynnewood renewable diesel unit project.
(2)Capital expenditures are shown exclusive of capitalized turnaround expenditures and business combinations.
JuneSeptember 30, 2022 | 20
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
(14) Supplemental Cash Flow Information
Cash flows related to income taxes, interest, leases, capital expenditures and deferred financing costs included in accounts payable, and non-cash dividends were as follows:
| | | Six Months Ended
June 30, | | Nine Months Ended
September 30, |
| (in millions) | (in millions) | 2022 | | 2021 | (in millions) | 2022 | | 2021 |
| Supplemental disclosures: | Supplemental disclosures: | | | | Supplemental disclosures: | | | |
| Cash paid for income taxes, net of refunds | Cash paid for income taxes, net of refunds | $ | 60 | | | $ | — | | Cash paid for income taxes, net of refunds | $ | 131 | | | $ | 35 | |
| Cash paid for interest | Cash paid for interest | 49 | | | 65 | | Cash paid for interest | 78 | | | 92 | |
| Cash paid for amounts included in the measurement of lease liabilities: | Cash paid for amounts included in the measurement of lease liabilities: | | Cash paid for amounts included in the measurement of lease liabilities: | |
| Operating cash flows from operating leases | Operating cash flows from operating leases | 9 | | | 8 | | Operating cash flows from operating leases | 13 | | | 11 | |
| Operating cash flows from finance leases | Operating cash flows from finance leases | 2 | | | 3 | | Operating cash flows from finance leases | 4 | | | 4 | |
| Financing cash flows from finance leases | Financing cash flows from finance leases | 3 | | | 3 | | Financing cash flows from finance leases | 4 | | | 4 | |
| Non-cash investing and financing activities: | Non-cash investing and financing activities: | | Non-cash investing and financing activities: | |
| Change in capital expenditures included in accounts payable (1) | Change in capital expenditures included in accounts payable (1) | 3 | | | 25 | | Change in capital expenditures included in accounts payable (1) | 14 | | | 1 | |
| Change in turnaround expenditures included in accounts payable | Change in turnaround expenditures included in accounts payable | — | | | (1) | | Change in turnaround expenditures included in accounts payable | (1) | | | (1) | |
| Change in deferred financing costs included in accounts payable | | Change in deferred financing costs included in accounts payable | — | | | 1 | |
| Non-cash dividends to CVR Energy stockholders | Non-cash dividends to CVR Energy stockholders | — | | | 251 | | Non-cash dividends to CVR Energy stockholders | — | | | 251 | |
(1)Capital expenditures are shown exclusive of capitalized turnaround expenditures.
Cash, cash equivalents and restricted cash consisted of the following:
| | (in millions) | (in millions) | June 30, 2022 | | December 31, 2021 | (in millions) | September 30, 2022 | | December 31, 2021 |
| Cash and cash equivalents | Cash and cash equivalents | $ | 893 | | | $ | 510 | | Cash and cash equivalents | $ | 618 | | | $ | 510 | |
Restricted cash (1) | Restricted cash (1) | 7 | | | 7 | | Restricted cash (1) | 7 | | | 7 | |
| Cash, cash equivalents and restricted cash | Cash, cash equivalents and restricted cash | $ | 900 | | | $ | 517 | | Cash, cash equivalents and restricted cash | $ | 625 | | | $ | 517 | |
(1)The restricted cash balance is included within Prepaid expenses and other current assets on the condensed consolidated balance sheets.
(15) Related Party Transactions
Activity associated with the Company’s related party arrangements for the three and sixnine months ended JuneSeptember 30, 2022 and 2021 is summarized below:
Expenses from Related Parties
| | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | Three Months Ended
September 30, | | Nine Months Ended
September 30, |
| (in millions) | (in millions) | 2022 | | 2021 | | 2022 | | 2021 | (in millions) | 2022 | | 2021 | | 2022 | | 2021 |
| Cost of materials and other: | Cost of materials and other: | | | | | | | | Cost of materials and other: | | | | | | | |
| Enable Joint Venture Transportation Agreement | Enable Joint Venture Transportation Agreement | $ | 2 | | | $ | 3 | | | $ | 5 | | | $ | 6 | | Enable Joint Venture Transportation Agreement | $ | 3 | | | $ | 3 | | | $ | 7 | | | $ | 8 | |
| | | Payments made: | | |
| Payments: | | Payments: | |
| Dividends (1) | Dividends (1) | 28 | | | 348 | | | 28 | | | 348 | | Dividends (1) | 214 | | | — | | | 242 | | | 348 | |
|
(1)See below for a summary of the dividends paid to IEP forduring the sixnine months ended JuneSeptember 30, 2022 and year ended December 31, 2021.
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
Corporate Master Service Agreement
On April 12, 2022, in connection with our Corporate Master Service Agreement effective January 1, 2020, by and among our wholly owned subsidiary, CVR Services, and certain other of our subsidiaries, including but not limited to CVR Partners and its subsidiaries, pursuant to which CVR Services provides the service recipients thereunder with management and other
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
professional services (the “Corporate MSA”), 18 indirect, wholly owned subsidiaries of CVR Energy, including but not limited to CVR Renew and the Joining Subsidiaries, were joined as service recipients under the Corporate MSA.
Dividends to CVR Energy Stockholders
Dividends, if any, including the payment, amount and timing thereof, are determined in the discretion of CVR Energy’s board of directors (the “Board”). IEP, through its ownership of the Company’s common stock, is entitled to receive dividends that are declared and paid by the Company based on the number of shares held at each record date. The following table presents quarterly dividends, excluding any special dividends, paid to the Company’s stockholders, including IEP, during 2022 (amounts presented in table below may not add to totals presented due to rounding).
| | | | Dividends Paid (in millions) | | Quarterly Dividends Paid (in millions) |
| Related Period | Related Period | | Date Paid | | Dividend Per Share | | Stockholders | | IEP | | Total | Related Period | | Date Paid | | Quarterly Dividend
Per Share | | Public Stockholders | | IEP | | Total |
| 2022 - 1st Quarter | 2022 - 1st Quarter | | May 23, 2022 | | $ | 0.40 | | | $ | 12 | | | $ | 28 | | | $ | 40 | | 2022 - 1st Quarter | | May 23, 2022 | | $ | 0.40 | | | $ | 12 | | | $ | 28 | | | $ | 40 | |
| | 2022 - 2nd Quarter | | 2022 - 2nd Quarter | | August 22, 2022 | | 0.40 | | | 12 | | | 28 | | | 40 | |
| Total 2022 quarterly dividends | | Total 2022 quarterly dividends | | $ | 0.80 | | | $ | 23 | | | $ | 57 | | | $ | 80 | |
No quarterly dividends were paid during the first quarter of 2022 related to the fourth quarter of 2021, and there were no quarterly dividends declared or paid during 2021 related to the first, second, and third quarters of 2021 and fourth quarter of 2020.
On August 1, 2022, the Company also declared a special dividend of $2.60 per share, or $261 million, which was paid on August 22, 2022. Of this amount, IEP received $185 million due to its ownership interest in the Company’s shares.
On May 26, 2021, the Company announced a special dividend of approximately $492 million, or equivalent to $4.89 per share of the Company’s common stock, to be paid in a combination of cash (the “Cash Distribution”) and the common stock of Delek held by the Company (the “Stock Distribution”). On June 10, 2021, the Company distributed an aggregate amount of approximately $241 million, or $2.40 per share of the Company’s common stock, pursuant to the Cash Distribution, and approximately 10,539,880 shares of Delek common stock, which represented approximately 14.3% of the outstanding shares of Delek common stock, pursuant to the Stock Distribution. IEP received approximately 7,464,652 shares of common stock of Delek and $171 million in cash. The Stock Distribution was recorded as a reduction to equity through a derecognition of our investment in Delek, and the Company recognized a gain of $112 million from the initial investment in Delek through the date of the Stock Distribution.
For the secondthird quarter of 2022, the Company, upon approval by the Board on August 1,October 31, 2022, declared a cash dividend of $0.40 per share, or $40 million, which is payable August 22,November 21, 2022 to shareholders of record as of August 12,November 14, 2022. Of this amount, IEP will receive $28 million due to its ownership interest in the Company’s shares.
In addition, the Company, upon approval by the Board on August 1,October 31, 2022, declared a special dividend of $2.60$1.00 per share, or $261$101 million, which is payable August 22,November 21, 2022 to shareholders of record as of August 12,November 14, 2022. Of this amount, IEP will receive $185$71 million due to its ownership interest in the Company’s shares.
Distributions to CVR Partners’ Unitholders
Distributions, if any, including the payment, amount and timing thereof, are subject to change at the discretion of the UAN GP Board. The following table presents quarterly distributions paid by CVR Partners to its unitholders, including amounts received by the Company, during 2022 and 2021 (amounts presented in tables below may not add to totals presented due to rounding).
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| | | | | | | | | | |
| | | | | | Distributions Paid (in millions) |
| Related Period | | Date Paid | | Distributions
Per Common Unit | | Public
Unitholders | | CVR Energy | | Total |
| 2021 - 4th Quarter | | March 14, 2022 | | $ | 5.24 | | | $ | 36 | | | $ | 20 | | | $ | 56 | |
| 2022 - 1st Quarter | | May 23, 2022 | | 2.26 | | | 15 | | | 9 | | | 24 | |
| | | | | | | | | | |
| Total 2022 distributions | | $ | 7.50 | | | $ | 51 | | | $ | 29 | | | $ | 80 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | |
| | | | | | Distributions Paid (in millions) |
| Related Period | | Date Paid | | Distributions
Per Common Unit | | Public
Unitholders | | CVR Energy | | Total |
| 2021 - 2nd Quarter | | August 23, 2021 | | $ | 1.72 | | | $ | 11 | | | $ | 7 | | | $ | 18 | |
| 2021 - 3rd Quarter | | November 22, 2021 | | 2.93 | | | 20 | | | 11 | | | 31 | |
| Total 2021 distributions | | $ | 4.65 | | | $ | 31 | | | $ | 18 | | | $ | 50 | |
JuneSeptember 30, 2022 | 22
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
received by the Company, during 2022 and 2021 (amounts presented in tables below may not add to totals presented due to rounding).
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | |
| | | | | | Quarterly Distributions Paid (in millions) |
| Related Period | | Date Paid | | Quarterly Distributions
Per Common Unit | | Public
Unitholders | | CVR Energy | | Total |
| 2021 - 4th Quarter | | March 14, 2022 | | $ | 5.24 | | | $ | 36 | | | $ | 20 | | | $ | 56 | |
| 2022 - 1st Quarter | | May 23, 2022 | | 2.26 | | | 15 | | | 9 | | | 24 | |
| 2022 - 2nd Quarter | | August 22, 2022 | | 10.05 | | | 67 | | | 39 | | | 106 | |
| Total 2022 quarterly distributions | | $ | 17.55 | | | $ | 118 | | | $ | 68 | | | $ | 186 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | |
| | | | | | Quarterly Distributions Paid (in millions) |
| Related Period | | Date Paid | | Quarterly Distributions
Per Common Unit | | Public
Unitholders | | CVR Energy | | Total |
| 2021 - 2nd Quarter | | August 23, 2021 | | $ | 1.72 | | | $ | 11 | | | $ | 7 | | | $ | 18 | |
| 2021 - 3rd Quarter | | November 22, 2021 | | 2.93 | | | 20 | | | 11 | | | 31 | |
| Total 2021 quarterly distributions | | $ | 4.65 | | | $ | 31 | | | $ | 18 | | | $ | 50 | |
There were no quarterly distributions declared or paid by CVR Partners related to the first quarter of 2021 and fourth quarter of 2020.
For the secondthird quarter of 2022, CVR Partners, upon approval by the UAN GP Board on August 1,October 31, 2022, declared a distribution of $10.05$1.77 per common unit, or $106$19 million, which is payable August 22,November 21, 2022 to unitholders of record as of August 12,November 14, 2022. Of this amount, CVR Energy will receive approximately $39$7 million, with the remaining amount payable to public unitholders.
JuneSeptember 30, 2022 | 23
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations
The following discussion and analysis of our financial condition and results of operations should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2021 filed with the U.S. Securities and Exchange Commission (the “SEC”) on February 23, 2022 (the “2021 Form 10-K”), and the unaudited condensed consolidated financial statements and related notes and with the statistical information and financial data appearing in this Report. Results of operations for the three and sixnine months ended JuneSeptember 30, 2022 and cash flows for the sixnine months ended JuneSeptember 30, 2022 are not necessarily indicative of results to be attained for any other period. See “Important Information Regarding Forward-Looking Statements.”
Reflected in this discussion and analysis is how management views the Company’s current financial condition and results of operations, along with key external variables and management’s actions that may impact the Company. Understanding significant external variables, such as market conditions, weather, and seasonal trends, among others, and management actions taken to manage the Company, address external variables, among others, will increase users’ understanding of the Company, its financial condition and results of operations. This discussion may contain forward-looking statements that reflect our plans, estimates and beliefs. Our actual results could differ materially from those discussed in the forward-looking statements. Factors that could cause or contribute to such differences include, but are not limited to, those discussed below and elsewhere in this Report.
Company Overview
CVR Energy, Inc. (“CVR Energy,” “CVR,” “we,” “us,” “our,” or the “Company”) is a diversified holding company primarily engaged in the petroleum refining and nitrogen fertilizer manufacturing industries through our holdings in CVR Refining, LP (“CVR Refining”) and CVR Partners, LP (“CVR Partners”), respectively. CVR Refining is a refiner that does not have crude oil exploration or production operations (an “independent petroleum refiner”) and is a marketer of high value transportation fuels.fuels primarily in the form of gasoline and diesel fuels, as well as renewable diesel. CVR Partners produces and markets nitrogen fertilizers primarily in the form of ammonia and urea ammonium nitrate (“UAN”). Ammonia is a direct application fertilizer and is primarily used as a building block for other nitrogen products for industrial applications and finished fertilizer products. UAN is an aqueous solution of urea and ammonium nitrate. At JuneSeptember 30, 2022, we owned the general partner and approximately 37% of the outstanding common units representing limited partner interests in CVR Partners. As of JuneSeptember 30, 2022, Icahn Enterprises L.P. and its affiliates (“IEP”) owned approximately 71% of our outstanding common stock.
We operate under two reportable business segments: petroleum and nitrogen fertilizer, which are referred to in this document as our “Petroleum Segment” and our “Nitrogen Fertilizer Segment,” respectively.
On February 22, 2022, in connection with our focus on decarbonization, we announced that our board of directors (the “Board”) had approved a plan to restructure our business to segregate our renewables business. As part of this restructuring, in the first quarter of 2022, we formed 16 new indirect, wholly owned subsidiaries (“NewCos”) of CVR Energy. In addition, in April 2022, in connection with our Corporate Master Service Agreement effective January 1, 2020, by and among our wholly owned subsidiary, CVR Services, LLC (“CVR Services”), and certain other of our subsidiaries, including but not limited to CVR Partners and its subsidiaries, pursuant to which CVR Services provides the service recipients thereunder with management and other professional services (the “Corporate MSA”), 18 indirect, wholly owned subsidiaries of CVR Energy, including but not limited to CVR Renewables, LLC (“CVR Renew”), were joined as service recipients under the Corporate MSA. Over the coming year, the Company intends to evaluate the transfer of certain additional assets to these NewCos to, among other purposes, better align our organizational structure with management, financial reporting, and our goal to maximize our renewables focus. Effective July 1, 2022, the Company completed the first of several planned intercompany asset transfers related to the restructuring and entered into certain agreements related thereto. At the present time, we expect the restructuring to be completed during the first quarter of 2023.
Strategy and Goals
The Company has adopted Mission and Values, which articulate the Company’s expectations for how it and its employees do business each and every day.
JuneSeptember 30, 2022 | 24
Mission and Values
Our Mission is to be a top tier North American renewable fuels, petroleum refining, and nitrogen-based fertilizer company as measured by safe and reliable operations, superior performance and profitable growth. The foundation of how we operate is built on five core Values:
•Safety - We always put safety first. The protection of our employees, contractors and communities is paramount. We have an unwavering commitment to safety above all else. If it’s not safe, then we don’t do it.
•Environment - We care for our environment. Complying with all regulations and minimizing any environmental impact from our operations is essential. We understand our obligation to the environment and that it’s our duty to protect it.
•Integrity - We require high business ethics. We comply with the law and practice sound corporate governance. We only conduct business one way—the right way with integrity.
•Corporate Citizenship - We are proud members of the communities where we operate. We are good neighbors and know that it’s a privilege we can’t take for granted. We seek to make a positive economic and social impact through our financial donations and the contributions of time, knowledge and talent of our employees to the places where we live and work.
•Continuous Improvement - We believe in both individual and team success. We foster accountability under a performance-driven culture that supports creative thinking, teamwork, diversity and personal development so that employees can realize their maximum potential. We use defined work practices for consistency, efficiency and to create value across the organization.
Our core values are driven by our people, inform the way we do business each and every day and enhance our ability to accomplish our mission and related strategic objectives.
Strategic Objectives
We have outlined the following strategic objectives to drive the accomplishment of our mission:
Environmental Health & Safety (“EH&S”) - We aim to achieve continuous improvement in all EH&S areas through ensuring our people’s commitment to environmental, health and safety comes first, the refinement of existing policies, continuous training, and enhanced monitoring procedures.
Reliability - Our goal is to achieve industry-leading utilization rates at our facilities through safe and reliable operations. We are focusing on improvements in day-to-day plant operations, identifying alternative sources for plant inputs to reduce lost time due to third-party operational constraints, and optimizing our commercial and marketing functions to maintain plant operations at their highest level.
Market Capture - We continuously evaluate opportunities to improve the facilities’ realized pricing at the gate and reduce variable costs incurred in production to maximize our capture of market opportunities.
Financial Discipline - We strive to be as efficient as possible by maintaining low operating costs and disciplined deployment of capital.
JuneSeptember 30, 2022 | 25
Achievements
DuringFrom the first six monthsbeginning of 2022,the fiscal year through the date of filing, we successfully executed a number of achievements in support of our strategic objectives shown below through the date of this filing:below:
| | | | | | | | | | | | | | | | | | | | | | | |
| Safety | | Reliability | | Market Capture | | Financial Discipline |
Achieved reductions in environmental events, process safety management tier 1 incidents and total recordable incident rate of 13%23%, 70% and 92%67%, respectively, compared to the first sixnine months of 2021 | ü | | | | | | |
Declared a quarterly cash dividend of $0.40 per share and a special dividend of $2.60$1.00 per share for the secondthird quarter of 2022, bringing total dividends declared to date of $3.40$4.80 per share related to the first sixnine months of 2022 | | | | | ü | | ü |
| Progressed plan to restructure our business to segregate our renewables operations, including the creation of new entities and intercompany transfer of certain assets thereto | | | | | ü | | ü |
| Completed the conversion of the Wynnewood hydrocracker to renewable diesel service | | | | | ü | | ü |
| Petroleum Segment: | | | | | | | |
Achieved reductions in environmental events, process safety management tier 1 incidents and total recordable incident rate of 50%36%, 20% and 100%57%, respectively, compared to the first sixnine months of 2021 | ü | | | | | | |
| Operated our refineries safely and reliably and at high utilization rates | ü | | ü | | ü | | |
| Safely completed the planned turnaround at the Wynnewood Refinery on time and on budget | | | ü | | ü | | ü |
| Completed an amendment and extension of the CVR Refining Asset Based Credit Agreement | | | | | | | ü |
| Achieved record truck-gathered crude oil volumes in the third quarter of 2022 | | | | | ü | | |
| Nitrogen Fertilizer Segment: | | | | | | | |
Achieved reductions in environmental events, process safety management tier 1 incidents and total recordable incident rate of 50%, 100% and 77%79%, respectively, compared to the first sixnine months of 2021 | ü | | | | | | |
| Operated both fertilizer facilities safely | ü | | | | | | |
| Safely completed the planned turnarounds at both fertilizer facilities on time and on budget, as well as inspected, repaired and replaced major equipment as necessary during this downtime | ü | | ü | | ü | | ü |
Achieved record UAN production volumes at the Coffeyville Fertilizer Facility in March 2022 through facility upgrades completed in October 2021 | | | ü | | ü | | |
Declared cash distribution of $10.05$1.77 per common unit for the secondthird quarter of 2022, bringing cumulative distributions declared to date of $12.31$14.08 per common unit related to the first sixnine months of 2022 | | | | | ü | | ü |
GeneratedAchieved average reduction in CO2e emissions of over 1 million carbon offset credits related to voluntary Nitrous Oxide abatement at the Coffeyville Fertilizer Facilitymetric tons per year since 2020 for CVR Partners | ü | | | | | | |
| Completed CVR Partners’ targeted $95 million debt reduction plan with the repayment of the remaining $65 million balance of its 9.25% Senior Secured Notes, due 2023 (the “2023 UAN Notes”) in the first quarter of 2022 for a total reduction in annual cash interest expense of approximately $9 million | | | | | | | ü |
| Repurchased over 111,000 CVR Partners common units for $12 million | | | | | | | ü |
Industry Factors and Market Indicators
General Business Environment
COVID-19 - Throughout 2020 and into 2021, the COVID-19 pandemic impacted the worldwide economy, financial markets, and the energy and fertilizer industries. Actions taken by the U.S. government to provide stimulus to individuals and businesses helped mitigate the impacts of the downturn caused by COVID-19, and we continue to see businesses resuming
JuneSeptember 30, 2022 | 26
Industry Factors and Market Indicators
General Business Environment
Russia-Ukraine Conflict and Global Market Conditions - In February 2022, Russia invaded Ukraine, disrupting the global oil, fertilizer, and agriculture markets, and leading to heightened uncertainty in the worldwide economy recovering from the COVID-19 pandemic. In response, many countries have formally or informally adopted sanctions on a number of Russian exports, including Russian oil and natural gas, and individuals affiliated with Russian government leadership. These sanctions, thus far, have resulted in oil price volatility, continued elevation of natural gas prices, and should continue to impact commodity prices in the near-term, which could have a material effect on our financial condition, cash flows, or results of operations. A global recession stemming from market volatility and higher price levels could result in demand destruction. The ultimate outcome of the Russia-Ukraine conflict and any associated market disruptions, as well as the potential for high inflation and/or economic recession, are difficult to predict and may materially affect our business, operations, and the lifting of governmental restrictions. However, despite worldwide advancescash flows in the containment of the virus and economic market recovery in 2021 and 2022, unforeseen ways.
COVID-19 - The COVID-19 pandemic remains a dynamic and continuously evolving situation with unknown short and long-term economic challenges that could reverse any recent improvements. Further, the spread of variants of COVID-19 could cause restrictions to be reinstated, and the extent to which the pandemic may impact our business, financial condition, liquidity, or results of operations cannot be determined at this time.
Russia-Ukraine Conflict - In February 2022, Russia invaded Ukraine, disrupting the global oil, fertilizer, and agriculture markets, and leading to heightened uncertainty in the worldwide economy recovering from the COVID-19 pandemic. In response, many Western countries have formally or informally adopted sanctions on a number of Russian exports, including Russian oil and natural gas, and individuals affiliated with Russian government leadership. These sanctions, thus far, have resulted in higher oil prices, continued elevation of natural gas prices, and should continue to impact commodity prices in the near-term, which could have a material effect on our financial condition, cash flows, or results of operations. A global recession stemming from market volatility could result in demand destruction, thereby lowering commodity prices. The ultimate outcome of the Russia-Ukraine conflict and any associated market disruptions are difficult to predict and may materially affect our business, operations, and cash flows in unforeseen ways.
Petroleum Segment
The earnings and cash flows of the Petroleum Segment are primarily affected by the relationship between refined product prices and the prices for crude oil and other feedstocks that are processed and blended into refined products together with the cost of refinery compliance. The cost to acquire crude oil and other feedstocks and the price for which refined products are ultimately sold depends on factors beyond the Petroleum Segment’s control, including the supply of, and demand for crude oil, as well as gasoline and other refined products which, in turn, depend on, among other factors, changes in domestic and foreign economies, driving habits, weather conditions, domestic and foreign political affairs, production levels, the availability or permissibly of imports and exports, the marketing of competitive fuels, and the extent of government regulation. Because the Petroleum Segment applies first-in first-out accounting to value its inventory, crude oil price movements may impact net income because of changes in the value of its unhedged inventory. The effect of changes in crude oil prices on the Petroleum Segment results of operations is partially influenced by the rate at which the processing of refined products adjusts to reflect these changes.
The prices of crude oil and other feedstocks and refined products are also affected by other factors, such as product pipeline capacity, system inventory, local and regional market conditions, inflation, and the operating levels of other refineries. Crude oil costs and the prices of refined products have historically been subject to wide fluctuations. Widespread expansion or upgrades of third party facilities, price volatility, international political and economic developments, and other factors are likely to continue to play an important role in refining industry economics. These factors can impact, among other things, the level of inventories in the market, resulting in price volatility and a reduction in product margins. Moreover, the refining industry typically experiences seasonal fluctuations in demand for refined products, such as increases in the demand for gasoline during the summer driving season and for volatile seasonal exports of diesel from the United States Gulf Coast.
As a result of government actions taken to curb the spread of COVID-19, and variants thereof, and significant business interruptions, the demand for gasoline and diesel in the regions in which our Petroleum Segment operates declined substantially beginning at the end of the first quarter of 2020. However, building on recovery signs observed in late 2020, the U.S. market for refined products continued to show signs of recovery throughout 2021 and into 2022. Gasoline demand increased due to increased mobility, which is the main driver for highway travel, while the increase in diesel demand is generally a result of the opening of coastal states such as California, New York, New Jersey, and Florida to global shipping and commerce. The combination of improving demand, declining inventories, and loss of domestic and foreign operating refining capacities, and conversion to renewable diesel facilities led to an increase in refined products prices and crack spreads during 2021 and into 2022. Furthermore, contributing to the ultra-low sulfur diesel (“ULSD”) supply constraints is the International Maritime Organization’s new limit on the sulfur content in the fuel oil used on board ships (“bunker fuel”) effective January 1, 2020, which lowered the sulfur limit of bunker fuel from 3.5% to 0.5%, which necessitated blending ULSD into bunker fuel to meet the new specifications. The resulting reduction of supply for traditional ULSD demand was initially muted by the pandemic-induced demand contraction. Additionally, the U.S. demand for jet fuels has recovered, albeit at a slower pace than gasoline and
diesel, with jet fuel demand at approximately 101%83% of pre-2020 demand levels as of JuneSeptember 30, 2022. From a global perspective, the U.S. Energy Information Administration (“EIA”) currently expects oil consumption will increase by more than global oil production, resulting in a decreasean increase of approximately 277204 million barrels in 2022. However, these projections depend on the production decisions of OPEC,OPEC+, U.S. oil production, and the pace of oil demand growth. While the refining market has largely recovered, uncertainty remains as to whether another
wave of COVID-19 cases may spur additional governmental restrictions and lock-downs in the future which could decrease demand once again. Furthermore, the Russia-Ukraine conflict creates additional uncertainty, as sanctions on Russian oil exports, specifically diesel exports, have significantly influenced markets. The resolution of this conflict will continue to affect markets going forward. Based on these factors, current inventory levels have remained low, particularly for distillate, with the days of supply for gasoline, distillate, and jet fuel at approximately 2.4, 5.3, and 4.9 days, respectively, below the seasonally adjusted five-year averages. Furthermore, planned and unplanned outages are continuing to contribute to further inventory tightening and volatility.
In addition to current market conditions discussed above, we continue to be impacted by significant volatility related to compliance requirements under the Renewable Fuel Standard (“RFS”), proposed climate change laws, and regulations. The petroleum business is subject to the RFS, which, each year, requires blending “renewable fuels” with transportation fuels or purchasing renewable identification numbers (“RINs”), in lieu of blending, or otherwise be subject to penalties. Our cost to comply with the RFS is dependent upon a variety of factors, which include the availability of ethanol and biodiesel for blending at our refineries and downstream terminals or RINs for purchase, the price at which RINs can be purchased, transportation fuel and renewable diesel production levels, and the mix of our products, all of which can vary significantly from period to period, as well as certain waivers or exemptions to which we may be entitled. Additionally, our costs to comply with the RFS depend on the consistent and timely application of the program by the Environmental Protection Agency (“EPA”), such as timely establishment of the annual renewable volume obligation (“RVO”). Due to the EPA’s unlawful failure to establish the 2021 and 2022 RVOs by the November 30, 2020 and 2021 statutory deadlines, respectively, the EPA’s delay in issuing decisions on pending small refinery hardship petitions and subsequent denial thereof, and the influence exerted and climate change initiatives announced by the Biden administration, among other factors, the price of RINs has been highly volatile and remains high. The price of RINs has also been impacted by the depletion of the carryover RIN bank, as demand destruction during the COVID-19 pandemic resulted in reduced ethanol blending and RIN generation that did not keep pace with mandated volumes, requiring carryover RINs from the RIN bank to be used to settle blending obligations. As a result, our costs to comply with RFS (excluding the impacts of any exemptions or waivers to which the Petroleum Segment may be entitled) increased significantly throughout 2020, 2021, and remain significant in 2022.
In April 2022, the EPA denied 36 small refinery exemptions (“SRE”) for the 2018 compliance year, many of which had been previously granted by the EPA, and also issued an alternative compliance demonstration approach for certain small refineries (the “Alternate Compliance Ruling”) under which they would not be required to purchase or redeem additional RINs as a result of the EPA’s denial. On June 3, 2022, the EPA revised the 2020 RVO and finalized the 2021 and 2022 RVOs. The EPA also denied 69 petitions from small refineries seeking SREs, including those submitted by Wynnewood Refining Company, LLC for 2019, 2020, and 2021, and applied the Alternate Compliance Ruling to three such petitions. The price of RINs, which continues to remain elevated, did not respond to the EPA announcement, and as a result, we continue to expect significant volatility in the price of RINs during 2022 and into 2023 and such volatility could have material impacts on the Company’s results of operations, financial condition, and cash flows.
In December 2020, the Board approved the renewable diesel project at our Wynnewood Refinery, to convert the Wynnewood Refinery’s hydrocracker to a renewable diesel unit (“RDU”), which is expected to be capable of producing up to 100 million gallons of renewable diesel per year, generating approximately 170 to 180 million RINs annually. The hydrocracker conversion to renewable diesel service was completed in April 2022, and we are continuing to increase production. The production of renewable diesel is expected to significantly reduce our future net exposure to the RFS. Further, the RDU should enable us to capture additional benefits associated with the existing blenders’ tax credit currently setwhich has been extended to expire at the end of 20222024 and growing low carbon fuel standard programs across the country, with programs in place in California and Oregon and new programs anticipated to be implemented over the next fewcoming years. In November 2021, the Board approved the pretreater project at the Wynnewood Refinery, which is expected to be completed in the secondthird quarter of 2023 at an estimated cost of $95 million. The pretreatment unit should enable us to process a wider variety of renewable diesel feedstocks at the Wynnewood Refinery, most of which have a lower carbon intensity than soybean oil and generate additional low carbon fuel standard credits. When completed, these collective renewable diesel efforts could effectively mitigate a substantial majority, if not all, of our future RFS exposure, assuming we receive SREs for our Wynnewood Refinery.Refinery which we believe we are legally entitled to and are pursuing in the courts. However, impacts from recent climate change initiatives under the Biden administration, actions taken by the courts, resulting administration actions under the RFS, and market conditions
could significantly impact the amount by which our renewable diesel business mitigates our costs to comply with the RFS, if at all.
As of JuneSeptember 30, 2022, we have an estimated open position (excluding the impacts of any exemptions or waivers to which we may be entitled) under the RFS for 2020, 2021, and 2022 of approximately 440423 million RINs, excluding approximately 1932 million of net open, fixed-price commitments to purchase RINs, resulting in a potential liability of $708$715 million. The Company’s open RFS position, which does not consider open commitments expected to settle in future periods, is marked-to-market each period and thus significant market volatility, as experienced in late 2021 and 2022 to date, could impact our RFS
expense from period to period. We recognized expense of approximately $153$86 million and $173a benefit of $16 million for the three months ended JuneSeptember 30, 2022 and 2021, respectively, and expense of approximately $259$328 million and $351$335 million for the sixnine months ended JuneSeptember 30, 2022 and 2021, respectively, for the Petroleum Segment’sCompany’s compliance with the RFS. The increase in expense in 2022 compared to 2021 was driven by a decreasean increase in RINs pricing through the secondthird quarter of 2022 and the revised 2020 and finalized 2021 and 2022 RVOs (excluding the impacts of any exemptions or waivers to which we may be entitled).2022. Of the expense recognized during the three and sixnine months ended JuneSeptember 30, 2022, $51$38 million and $70$108 million, respectively, relates to the revaluation of our net RVO position as of JuneSeptember 30, 2022. The revaluation represents the summation of the prior period obligation and current period commercial activities, marked at the period end market price. Based upon recent market prices of RINs in JuneSeptember 2022, current estimates related to other variable factors, including our anticipated blending and purchasing activities, and the impact of the open RFS positions and resolution thereof, our estimated consolidated cost to comply with the RFS (without regard to any SREs we may receive) is $320$390 to $330$400 million for 2022, net of the estimated RINs generation from our renewable diesel operations of $120$100 to $130$110 million.
Market Indicators
NYMEX WTI crude oil is an industry wide benchmark that is utilized in the market pricing of a barrel of crude oil. The pricing differences between other crudes and WTI, known as differentials, show how the market for other crude oils such as WCS, White Cliffs (“Condensate”), Brent Crude (“Brent”), and Midland WTI (“Midland”) are trending. Due to the COVID-19 pandemic, the Russia-Ukraine conflict, and, in each case, actions taken by governments and others in response thereto, refined product prices have experienced extreme volatility. As a result of the current environment, refining margins have been and will continue to be volatile.
As a performance benchmark and a comparison with other industry participants, we utilize NYMEX and Group 3 crack spreads. These crack spreads are a measure of the difference between market prices for crude oil and refined products and are a commonly used proxy within the industry to estimate or identify trends in refining margins. Crack spreads can fluctuate significantly over time as a result of market conditions and supply and demand balances. The NYMEX 2-1-1 crack spread is calculated using two barrels of WTI producing one barrel of NYMEX RBOB Gasoline (“RBOB”) and one barrel of NYMEX NY Harbor ULSD (“HO”). The Group 3 2-1-1 crack spread is calculated using two barrels of WTI crude oil producing one barrel of Group 3 sub-octane gasoline and one barrel of Group 3 ultra-low sulfur diesel.
Both NYMEX 2-1-1 and Group 3 2-1-1 crack spreads increased during the sixnine months ended JuneSeptember 30, 2022 compared to the sixnine months ended JuneSeptember 30, 2021. The NYMEX 2-1-1 crack spread averaged $41.31$42.16 per barrel during the sixnine months ended JuneSeptember 30, 2022 compared to $18.10$19.05 per barrel in the sixnine months ended JuneSeptember 30, 2021. The Group 3 2-1-1 crack spread averaged $35.56$38.38 per barrel during the sixnine months ended JuneSeptember 30, 2022 compared to $17.76$18.58 per barrel during the sixnine months ended JuneSeptember 30, 2021.
Average monthly prices for RINs decreased 7.0%increased 9.7% during the secondthird quarter of 2022 compared to the same period of 2021. On a blended barrel basis (calculated using applicable RVO percentages), RINs approximated $7.58$8.02 per barrel during the secondthird quarter of 2022 compared to $8.15$7.31 per barrel during the secondthird quarter of 2021.
JuneSeptember 30, 2022 | 29
The charts below are presented, on a per barrel basis, by month through JuneSeptember 30, 2022:
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Crude Oil Differentials against WTI (1)(2) |
JuneSeptember 30, 2022 | 30
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PADD II Group 3 Product Crack Spread and RIN Pricing (2)(3) ($/bbl) | | Group 3 Differential against NYMEX WTI (1)(2) ($/bbl) |
(1)The change over time in NYMEX - WTI, as reflected in the charts above, is illustrated below.
| | (in $/bbl) | (in $/bbl) | Average 2020 | | Average December 2020 | | Average 2021 | | Average December 2021 | | Average 2022 | | Average June 2022 | (in $/bbl) | Average 2020 | | Average December 2020 | | Average 2021 | | Average December 2021 | | Average 2022 | | Average September 2022 |
| WTI | WTI | $ | 39.34 | | | $ | 47.07 | | | $ | 68.11 | | | $ | 71.69 | | | $ | 101.86 | | | $ | 114.34 | | WTI | $ | 39.34 | | | $ | 47.07 | | | $ | 68.11 | | | $ | 71.69 | | | $ | 98.35 | | | $ | 83.80 | |
(2)Information used within these charts was obtained from reputable market sources, including the New York Mercantile Exchange (“NYMEX”), Intercontinental Exchange, and Argus Media, among others.
(3)PADD II is the Midwest Petroleum Area for Defense District (“PADD”), which includes Illinois, Indiana, Iowa, Kansas, Kentucky, Michigan, Minnesota, Missouri, Nebraska, North Dakota, Ohio, Oklahoma, South Dakota, Tennessee and Wisconsin.
Nitrogen FertilizerPetroleum Segment
Within the Nitrogen Fertilizer Segment,The earnings and cash flows from operationsof the Petroleum Segment are primarily affected by the relationship between nitrogen fertilizerrefined product prices utilization, and operating coststhe prices for crude oil and expenses, including pet cokeother feedstocks that are processed and natural gas feedstock costs.
blended into refined products together with the cost of refinery compliance. The cost to acquire crude oil and other feedstocks and the price atfor which nitrogen fertilizerrefined products are ultimately sold depends on numerous factors beyond the Petroleum Segment’s control, including the global supply of, and demand for nitrogen fertilizercrude oil, as well as gasoline and other refined products world grain demandwhich, in turn, depend on, among other factors, changes in domestic and foreign economies, driving habits, weather conditions, domestic and foreign political affairs, production levels, inflation, global supply disruptions, changes in world population, the cost and availability of fertilizer transportation infrastructure, local market conditions, operating levels of competing facilities, weather conditions, the availability or permissibly of imports impactsand exports, the marketing of foreign imports and foreign subsidies thereof,competitive fuels, and the extent of government interventionregulation. Because the Petroleum Segment applies first-in first-out accounting to value its inventory, crude oil price movements may impact net income because of changes in agriculture markets.the value of its unhedged inventory. The effect of changes in crude oil prices on the Petroleum Segment results of operations is partially influenced by the rate at which the processing of refined products adjusts to reflect these changes.
The prices of crude oil and other feedstocks and refined products are also affected by other factors, such as product pipeline capacity, system inventory, local and regional market conditions, inflation, and the operating levels of other refineries. Crude oil costs and the prices of refined products have historically been subject to wide fluctuations. Widespread expansion or upgrades of third party facilities, price volatility, international political and economic developments, and other factors are likely to continue to play an important role in refining industry economics. These factors can impact, among other things, the level of inventories in the market, resulting in price volatility and a reduction in product margins. Moreover, the refining industry typically experiences seasonal fluctuations in demand for nitrogen fertilizer products.refined products, such as increases in the demand for gasoline during the summer driving season and for volatile seasonal exports of diesel from the United States Gulf Coast.
As a result of government actions taken to curb the spread of COVID-19, and variants thereof, and significant business interruptions, the demand for gasoline and diesel in the regions in which our Petroleum Segment operates declined substantially beginning at the end of the first quarter of 2020. However, building on recovery signs observed in late 2020, the U.S. market for refined products continued to show signs of recovery throughout 2021 and into 2022. Gasoline demand increased due to increased mobility, which is the main driver for highway travel, while the increase in diesel demand is generally a result of the opening of coastal states such as California, New York, New Jersey, and Florida to global shipping and commerce. The combination of improving demand, declining inventories, loss of domestic and foreign operating refining capacities, and conversion to renewable diesel facilities led to an increase in refined products prices and crack spreads during 2021 and into 2022. Furthermore, contributing to the ultra-low sulfur diesel (“ULSD”) supply constraints is the International Maritime Organization’s new limit on the sulfur content in the fuel oil used on board ships (“bunker fuel”) effective January 1, 2020, which lowered the sulfur limit of bunker fuel from 3.5% to 0.5%, which necessitated blending ULSD into bunker fuel to meet the new specifications. The resulting reduction of supply for traditional ULSD demand was initially muted by the pandemic-induced demand contraction. Additionally, the U.S. demand for jet fuels has recovered, albeit at a slower pace than gasoline and
diesel, with jet fuel demand at approximately 83% of pre-2020 demand levels as of September 30, 2022. From a global perspective, the U.S. Energy Information Administration (“EIA”) currently expects oil consumption will increase by more than global oil production, resulting in an increase of approximately 204 million barrels in 2022. However, these projections depend on the production decisions of OPEC+, U.S. oil production, and the pace of oil demand growth. While the refining market has largely recovered, uncertainty remains as to whether another wave of COVID-19 cases may spur additional governmental restrictions and lock-downs in the future which could decrease demand once again. Furthermore, the Russia-Ukraine conflict creates additional uncertainty, as sanctions on Russian invasionoil exports, specifically diesel exports, have significantly influenced markets. The resolution of Ukraine,this conflict will continue to affect markets going forward. Based on these factors, current inventory levels have remained low, particularly for distillate, with the Black Sea,days of supply for gasoline, distillate, and jet fuel at approximately 2.4, 5.3, and 4.9 days, respectively, below the seasonally adjusted five-year averages. Furthermore, planned and unplanned outages are continuing to contribute to further inventory tightening and volatility.
In addition to current market conditions discussed above, we continue to be impacted by significant volatility related to compliance requirements under the Renewable Fuel Standard (“RFS”), proposed climate change laws, and regulations. The petroleum business is subject to the RFS, which, each year, requires blending “renewable fuels” with transportation fuels or purchasing renewable identification numbers (“RINs”), in lieu of blending, or otherwise be subject to penalties. Our cost to comply with the RFS is dependent upon a major export pointvariety of factors, which include the availability of ethanol and biodiesel for nitrogen fertilizerblending at our refineries and grainsdownstream terminals or RINs for purchase, the price at which RINs can be purchased, transportation fuel and renewable diesel production levels, and the mix of our products, all of which can vary significantly from these countries,period to period, as well as certain waivers or exemptions to which we may be entitled. Additionally, our costs to comply with the RFS depend on the consistent and timely application of the program by the Environmental Protection Agency (“EPA”), such as timely establishment of the annual renewable volume obligation (“RVO”). Due to the EPA’s unlawful failure to establish the 2021 and 2022 RVOs by the November 30, 2020 and 2021 statutory deadlines, respectively, the EPA’s delay in issuing decisions on pending small refinery hardship petitions and subsequent denial thereof, and the influence exerted and climate change initiatives announced by the Biden administration, among other factors, the price of RINs has been closedhighly volatile and remains high. The price of RINs has also been impacted by the depletion of the carryover RIN bank, as demand destruction during the COVID-19 pandemic resulted in reduced ethanol blending and RIN generation that did not keep pace with mandated volumes, requiring carryover RINs from the RIN bank to exports,be used to settle blending obligations. As a result, our costs to comply with RFS (excluding the impacts of any exemptions or waivers to which prompted tightening global supply conditionsthe Petroleum Segment may be entitled) increased significantly throughout 2020, 2021, and remain significant in 2022.
In April 2022, the EPA denied 36 small refinery exemptions (“SRE”) for nitrogen fertilizer in advancethe 2018 compliance year, many of spring plantingwhich had been previously granted by the EPA, and wheat and corn availability, two major exports from this region. Further, while fertilizers havealso issued an alternative compliance demonstration approach for certain small refineries (the “Alternate Compliance Ruling”) under which they would not been formally sanctioned by Western countries, many Western customers are either unwillingbe required to purchase Russian fertilizers or logistics make it too costlyredeem additional RINs as a result of the EPA’s denial. On June 3, 2022, the EPA revised the 2020 RVO and finalized the 2021 and 2022 RVOs. The EPA also denied 69 petitions from small refineries seeking SREs, including those submitted by Wynnewood Refining Company, LLC for 2019, 2020, and 2021, and applied the Alternate Compliance Ruling to import these fertilizers. Additionally, natural gas supplied from Russiathree such petitions. The price of RINs, which continues to Western Europeremain elevated, did not respond to the EPA announcement, and as a result, we continue to expect significant volatility in the price of RINs during 2022 and into 2023 and such volatility could have material impacts on the Company’s results of operations, financial condition, and cash flows.
In December 2020, the Board approved the renewable diesel project at our Wynnewood Refinery, to convert the Wynnewood Refinery’s hydrocracker to a renewable diesel unit (“RDU”), which is expected to be capable of producing up to 100 million gallons of renewable diesel per year, generating approximately 170 to 180 million RINs annually. The hydrocracker conversion to renewable diesel service was completed in April 2022, and we are continuing to increase production. The production of renewable diesel is expected to significantly reduce our future net exposure to the RFS. Further, the RDU should enable us to capture additional benefits associated with the existing blenders’ tax credit which has been constrainedextended to the end of 2024 and natural gasgrowing low carbon fuel standard programs across the country, with programs in place in California and Oregon and new programs anticipated to be implemented over the coming years. In November 2021, the Board approved the pretreater project at the Wynnewood Refinery, which is expected to be completed in the third quarter of 2023 at an estimated cost of $95 million. The pretreatment unit should enable us to process a wider variety of renewable diesel feedstocks at the Wynnewood Refinery, most of which have a lower carbon intensity than soybean oil and generate additional low carbon fuel standard credits. When completed, these collective renewable diesel efforts could effectively mitigate a substantial majority, if not all, of our future RFS exposure, assuming we receive SREs for our Wynnewood Refinery which we believe we are legally entitled to and are pursuing in the courts. However, impacts from recent climate change initiatives under the Biden administration, actions taken by the courts, resulting administration actions under the RFS, and market conditions
could significantly impact the amount by which our renewable diesel business mitigates our costs to comply with the RFS, if at all.
As of September 30, 2022, we have an estimated open position (excluding the impacts of any exemptions or waivers to which we may be entitled) under the RFS for 2020, 2021, and 2022 of approximately 423 million RINs, excluding approximately 32 million of net open, fixed-price commitments to purchase RINs, resulting in a potential liability of $715 million. The Company’s open RFS position, which does not consider open commitments expected to settle in future periods, is marked-to-market each period and thus significant market volatility, as experienced in late 2021 and 2022 to date, could impact our RFS expense from period to period. We recognized expense of approximately $86 million and a benefit of $16 million for the three months ended September 30, 2022 and 2021, respectively, and expense of approximately $328 million and $335 million for the nine months ended September 30, 2022 and 2021, respectively, for the Company’s compliance with the RFS. The increase in expense in 2022 compared to 2021 was driven by an increase in RINs pricing through the third quarter of 2022. Of the expense recognized during the three and nine months ended September 30, 2022, $38 million and $108 million, respectively, relates to the revaluation of our net RVO position as of September 30, 2022. The revaluation represents the summation of the prior period obligation and current period commercial activities, marked at the period end market price. Based upon recent market prices of RINs in September 2022, current estimates related to other variable factors, including our anticipated blending and purchasing activities, and the impact of the open RFS positions and resolution thereof, our estimated consolidated cost to comply with the RFS (without regard to any SREs we may receive) is $390 to $400 million for 2022, net of the estimated RINs generation from our renewable diesel operations of $100 to $110 million.
Market Indicators
NYMEX WTI crude oil is an industry wide benchmark that is utilized in the market pricing of a barrel of crude oil. The pricing differences between other crudes and WTI, known as differentials, show how the market for other crude oils such as WCS, White Cliffs (“Condensate”), Brent Crude (“Brent”), and Midland WTI (“Midland”) are trending. Due to the COVID-19 pandemic, the Russia-Ukraine conflict, and, in each case, actions taken by governments and others in response thereto, refined product prices have remained elevated since September 2021, causingexperienced extreme volatility. As a significant portionresult of European nitrogen fertilizer production capacitythe current environment, refining margins have been and will continue to be curtailedvolatile.
As a performance benchmark and a comparison with other industry participants, we utilize NYMEX and Group 3 crack spreads. These crack spreads are a measure of the difference between market prices for crude oil and refined products and are a commonly used proxy within the industry to estimate or costs to be elevatedidentify trends in refining margins. Crack spreads can fluctuate significantly over time as a result of market conditions and supply and demand balances. The NYMEX 2-1-1 crack spread is calculated using two barrels of WTI producing one barrel of NYMEX RBOB Gasoline (“RBOB”) and one barrel of NYMEX NY Harbor ULSD (“HO”). The Group 3 2-1-1 crack spread is calculated using two barrels of WTI crude oil producing one barrel of Group 3 sub-octane gasoline and one barrel of Group 3 ultra-low sulfur diesel.
Both NYMEX 2-1-1 and Group 3 2-1-1 crack spreads increased during the nine months ended September 30, 2022 compared to competitorsthe nine months ended September 30, 2021. The NYMEX 2-1-1 crack spread averaged $42.16 per barrel during the nine months ended September 30, 2022 compared to $19.05 per barrel in other regionsthe nine months ended September 30, 2021. The Group 3 2-1-1 crack spread averaged $38.38 per barrel during the nine months ended September 30, 2022 compared to $18.58 per barrel during the nine months ended September 30, 2021.
Average monthly prices for RINs increased 9.7% during the third quarter of 2022 compared to the world. Overall, these events have caused grain and fertilizer pricessame period of 2021. On a blended barrel basis (calculated using applicable RVO percentages), RINs approximated $8.02 per barrel during the third quarter of 2022 compared to rise, and we currently expect these conditions to persist for$7.31 per barrel during the remainderthird quarter of 2022.2021.
JuneSeptember 30, 2022 | 3129
Market Indicators
While there is risk of shorter-term volatility given the inherent nature of the commodity cycle, the Company believes the long-term fundamentals for the U.S. nitrogen fertilizer industry remain intact. The Nitrogen Fertilizer Segment views the anticipated combination of (i) increasing global population, (ii) decreasing arable land per capita, (iii) continued evolution to more protein-based diets in developing countries, (iv) sustained use of corn and soybeans as feedstock for the domestic production of ethanol and other renewable fuels, and (v) positioning at the lower end of the global cost curve should provide a solid foundation for nitrogen fertilizer producers in the U.S. over the longer term.
Corn and soybeans are two major crops planted by farmers in North America. Corn crops result in the depletion of the amount of nitrogen within the soil in which it is grown, which in turn, results in the need for this nutrient to be replenished after each growing cycle. Unlike corn, soybeans are able to obtain most of their own nitrogen through a process known as “N fixation.” As such, upon harvesting of soybeans, the soil retains a certain amount of nitrogen which results in lower demand for nitrogen fertilizer for the following corn planting cycle. Due to these factors, nitrogen fertilizer consumers generally operate a balanced corn-soybean rotational planting cycle as evident by the chart presented below as of June 30, 2022.
The relationship between the total acres planted for both corn and soybean has a direct impact on the overall demand for nitrogen products, as the market and demand for nitrogen increases with increased corn acres and decreases with increased soybean acres. Additionally, an estimated 12 billion pounds of soybean oil is expected to be used in producing cleaner renewables in marketing year 2022/2023. Multiple refiners have announced renewable diesel expansion projects for 2021 and beyond, which will only increase the demand for soybeans and potentially for corn and canola.
The United States Department of Agriculture (“USDA”) estimates that in spring 2022 farmers planted 89.9 million corn acres, representing a decrease of 3.7% as compared to 93.4 million corn acres in 2021. Planted soybean acres are estimated to be 88.3 million, representing a 1.3% increase as compared to 87.2 million soybean acres in 2021. The combined corn and soybean planted acres of 178.2 million is in line with the acreage planted in 2021, which was the highest in history. Due to higher input costs for corn planting and increased demand for soybeans, particularly for renewable diesel production, it was more favorable for farmers to plant soybeans compared to corn. The lower planted corn acres in 2022 is expected to be supportive of corn prices for 2022 and 2023.
Ethanol is blended with gasoline to meet renewable fuel standard requirements and for its octane value. Ethanol production has historically consumed approximately 35% of the U.S. corn crop, so demand for corn generally rises and falls with ethanol demand, as evidenced by the charts below are presented, on a per barrel basis, by month through JuneSeptember 30, 2022.
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U.S. Plant Production of Fuel Ethanol (1)
| | Corn and Soybean Planted Acres (2)
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Crude Oil Differentials against WTI (1)(2) |
(1)Information used within this chart was obtained from the EIA through June 30, 2022.
(2)Information used within this chart was obtained from the USDA, National Agricultural Statistics Services as of June 30, 2022.
Weather continues to be a critical variable for crop production. Even with high planted acres and trendline yields per acre in the U.S., inventory levels for corn and soybeans remain below historical levels and prices have remained elevated. With tight
JuneSeptember 30, 2022 | 3230
grain and fertilizer inventory levels driven by the war in Ukraine, prices for grains and fertilizers are expected to remain elevated throughout 2022. While the weather conditions were difficult early in spring 2022, farmers were able to complete the crop planting later than normal. Demand for nitrogen fertilizer, as well as other crop inputs, was strong for the spring 2022 planting season.
On June 30, 2021, CF Industries Nitrogen, L.L.C., Terra Nitrogen, Limited Partnership, and Terra International (Oklahoma) LLC filed petitions with the U.S. Department of Commerce (“USDOC”) and the U.S. International Trade Commission (the “ITC”) requesting the initiation of antidumping and countervailing duty investigations on imports of UAN from Russia and Trinidad and Tobago (“Trinidad”). Following investigations by both USDOC and the ITC, on November 30, 2021, USDOC determined that UAN imports from Russia are unfairly subsidized at rates ranging from 9.66% to 9.84% and UAN imports from Trinidad are unfairly subsidized at a rate of 1.83%. On January 27, 2022, USDOC found that Russian UAN imports are sold at less than fair value into the U.S. market at rates ranging from 9.15% to 127.19% and that Trinidadian UAN imports at a rate of 63.08%. On June 21, 2022, USDOC issued its final affirmative determinations in anti-dumping and countervailing duty investigations where it found that imports from Russia are dumped at rates ranging from 8.16% to 122.93% and unfairly subsidized at rates ranging from 6.27% to 9.66%. Additionally, USDOC found that imports from Trinidad are dumped at a rate of 111.71% and unfairly subsidized at a rate of 1.83%. On July 18, 2022, the ITC made a negative final injury determination concerning its investigation of imports from Russia and Trinidad despite USDOC’s final determination in June that UAN is subsidized and dumped in the U.S. market by producers in both countries. As the result of this decision, we expect world trade flows of UAN to return to pre-investigation patterns.
The charts below show relevant market indicators for the Nitrogen Fertilizer Segment by month through June 30, 2022:
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PADD II Group 3 Product Crack Spread Ammonia and UAN MarketRIN Pricing (1)(2)(3)($/bbl)
| | Group 3 Differential against NYMEX Natural Gas and Pet Coke Market PricingWTI (1)(2)($/bbl)
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(1)The change over time in NYMEX - WTI, as reflected in the charts above, is illustrated below.
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| (in $/bbl) | Average 2020 | | Average December 2020 | | Average 2021 | | Average December 2021 | | Average 2022 | | Average September 2022 |
| WTI | $ | 39.34 | | | $ | 47.07 | | | $ | 68.11 | | | $ | 71.69 | | | $ | 98.35 | | | $ | 83.80 | |
(2)Information used within these charts was obtained from various third-partyreputable market sources, including Green Markets (a Bloomberg Company)the New York Mercantile Exchange (“NYMEX”), PaceIntercontinental Exchange, and Argus Media, among others.
(3)PADD II is the Midwest Petroleum Coke Quarterly,Area for Defense District (“PADD”), which includes Illinois, Indiana, Iowa, Kansas, Kentucky, Michigan, Minnesota, Missouri, Nebraska, North Dakota, Ohio, Oklahoma, South Dakota, Tennessee and the EIA, amongst others.Wisconsin.
Results of Operations
Consolidated
Our consolidated results of operations include certain other unallocated corporate activities and the elimination of intercompany transactions and, therefore, do not equal the sum of the operating results of the Petroleum Segment and Nitrogen Fertilizer Segment.
Consolidated Financial Highlights (Three and Six Months Ended June 30, 2022 versus June 30, 2021)
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Operating Income (Loss) | | Net Income (Loss) Attributable to CVR
Energy Stockholders
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Earnings (Loss) per Share | | EBITDA (1)
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(1)See “Non-GAAP Reconciliations” section below for reconciliations of the non-GAAP measures shown above.
Three and Six Months Ended June 30, 2022 versus June 30, 2021 (Consolidated)
Overview - For the three months ended June 30, 2022, the Company’s operating income and net income were $402 million and $239 million, respectively, an increase of $396 million and $241 million, respectively, compared to operating income and net loss of $6 million and $2 million, respectively, during the three months ended June 30, 2021. For the six months ended June 30, 2022, the Company’s operating income and net income were $623 million and $392 million, respectively, an increase of $752 million and $449 million, respectively, compared to operating loss and net loss of $129 million and $57 million, respectively, during the six months ended June 30, 2021. Refer to our discussion of each segment’s results of operations below for further information.
Investment Income on Marketable Securities - On June 10, 2021, the Company distributed substantially all of its holdings in Delek US Holdings, Inc. (“Delek”), of which the Company was the largest stockholder holding approximately 14.3% of Delek’s outstanding common stock, as part of a special dividend. On January 18, 2022, the Company divested its remaining nominal holdings in Delek, and as of June 30, 2022, the Company does not hold an investment in other marketable securities of Delek. There was no dividend income received during the three and six months ended June 30, 2022 and 2021. The Company
did not recognize a gain or loss on the investment during the three and six months ended June 30, 2022, and for the three and six months ended June 30, 2021, the Company recognized a gain of $21 million and $83 million, respectively.
Other (Expense) Income, Net - For the three and six months ended June 30, 2022, the Company’s other expense, net was $74 million and $84 million, respectively, compared to other income, net of $3 million and $10 million for the three and six months ended June 30, 2021, respectively. This change was primarily attributable to the expected settlement of litigation. Refer to Part I, Item 1, Note 12 (“Commitments and Contingencies”) of this Report for further discussion.
Income Tax Expense (Benefit) - Income tax expense for the three and six months ended June 30, 2022 was $66 million and $99 million, or 21.5% and 20.2% of income before income tax, respectively, as compared to an income tax benefit for the three and six months ended June 30, 2021 of $6 million and $48 million, or 78.4% and 46.0% of loss before income tax, respectively. The fluctuation in income tax was due primarily to changes in pretax earnings and earnings attributable to noncontrolling interest from the three and six months ended June 30, 2021 to the three and six months ended June 30, 2022. The fluctuation in effective income tax rate was due primarily to changes in pretax earnings, earnings attributable to noncontrolling interest and a discrete tax benefit recorded in June 2021 for decreases in state income tax rates.
Petroleum Segment
The earnings and cash flows of the Petroleum Segment are primarily affected by the relationship between refined product prices and the prices for crude oil and other feedstocks that are processed and blended into refined products together with the cost of refinery compliance. The cost to acquire crude oil and other feedstocks and the price for which refined products are ultimately sold depends on factors beyond the Petroleum Segment’s control, including the supply of, and demand for crude oil, as well as gasoline and other refined products which, in turn, depend on, among other factors, changes in domestic and foreign economies, driving habits, weather conditions, domestic and foreign political affairs, production levels, the availability or permissibly of imports and exports, the marketing of competitive fuels, and the extent of government regulation. Because the Petroleum Segment applies first-in first-out accounting to value its inventory, crude oil price movements may impact net income because of changes in the value of its unhedged inventory. The effect of changes in crude oil prices on the Petroleum Segment results of operations is partially influenced by the rate at which the processing of refined products adjusts to reflect these changes.
The prices of crude oil and other feedstocks and refined products are also affected by other factors, such as product pipeline capacity, system inventory, local and regional market conditions, inflation, and the operating levels of other refineries. Crude oil costs and the prices of refined products have historically been subject to wide fluctuations. Widespread expansion or upgrades of third party facilities, price volatility, international political and economic developments, and other factors are likely to continue to play an important role in refining industry economics. These factors can impact, among other things, the level of inventories in the market, resulting in price volatility and a reduction in product margins. Moreover, the refining industry typically experiences seasonal fluctuations in demand for refined products, such as increases in the demand for gasoline during the summer driving season and for volatile seasonal exports of diesel from the United States Gulf Coast.
As a result of government actions taken to curb the spread of COVID-19, and variants thereof, and significant business interruptions, the demand for gasoline and diesel in the regions in which our Petroleum Segment operates declined substantially beginning at the end of the first quarter of 2020. However, building on recovery signs observed in late 2020, the U.S. market for refined products continued to show signs of recovery throughout 2021 and into 2022. Gasoline demand increased due to increased mobility, which is the main driver for highway travel, while the increase in diesel demand is generally a result of the opening of coastal states such as California, New York, New Jersey, and Florida to global shipping and commerce. The combination of improving demand, declining inventories, loss of domestic and foreign operating refining capacities, and conversion to renewable diesel facilities led to an increase in refined products prices and crack spreads during 2021 and into 2022. Furthermore, contributing to the ultra-low sulfur diesel (“ULSD”) supply constraints is the International Maritime Organization’s new limit on the sulfur content in the fuel oil used on board ships (“bunker fuel”) effective January 1, 2020, which lowered the sulfur limit of bunker fuel from 3.5% to 0.5%, which necessitated blending ULSD into bunker fuel to meet the new specifications. The resulting reduction of supply for traditional ULSD demand was initially muted by the pandemic-induced demand contraction. Additionally, the U.S. demand for jet fuels has recovered, albeit at a slower pace than gasoline and
diesel, with jet fuel demand at approximately 83% of pre-2020 demand levels as of September 30, 2022. From a global perspective, the U.S. Energy Information Administration (“EIA”) currently expects oil consumption will increase by more than global oil production, resulting in an increase of approximately 204 million barrels in 2022. However, these projections depend on the production decisions of OPEC+, U.S. oil production, and the pace of oil demand growth. While the refining market has largely recovered, uncertainty remains as to whether another wave of COVID-19 cases may spur additional governmental restrictions and lock-downs in the future which could decrease demand once again. Furthermore, the Russia-Ukraine conflict creates additional uncertainty, as sanctions on Russian oil exports, specifically diesel exports, have significantly influenced markets. The resolution of this conflict will continue to affect markets going forward. Based on these factors, current inventory levels have remained low, particularly for distillate, with the days of supply for gasoline, distillate, and jet fuel at approximately 2.4, 5.3, and 4.9 days, respectively, below the seasonally adjusted five-year averages. Furthermore, planned and unplanned outages are continuing to contribute to further inventory tightening and volatility.
In addition to current market conditions discussed above, we continue to be impacted by significant volatility related to compliance requirements under the Renewable Fuel Standard (“RFS”), proposed climate change laws, and regulations. The petroleum business is subject to the RFS, which, each year, requires blending “renewable fuels” with transportation fuels or purchasing renewable identification numbers (“RINs”), in lieu of blending, or otherwise be subject to penalties. Our cost to comply with the RFS is dependent upon a variety of factors, which include the availability of ethanol and biodiesel for blending at our refineries and downstream terminals or RINs for purchase, the price at which RINs can be purchased, transportation fuel and renewable diesel production levels, and the mix of our products, all of which can vary significantly from period to period, as well as certain waivers or exemptions to which we may be entitled. Additionally, our costs to comply with the RFS depend on the consistent and timely application of the program by the Environmental Protection Agency (“EPA”), such as timely establishment of the annual renewable volume obligation (“RVO”). Due to the EPA’s unlawful failure to establish the 2021 and 2022 RVOs by the November 30, 2020 and 2021 statutory deadlines, respectively, the EPA’s delay in issuing decisions on pending small refinery hardship petitions and subsequent denial thereof, and the influence exerted and climate change initiatives announced by the Biden administration, among other factors, the price of RINs has been highly volatile and remains high. The price of RINs has also been impacted by the depletion of the carryover RIN bank, as demand destruction during the COVID-19 pandemic resulted in reduced ethanol blending and RIN generation that did not keep pace with mandated volumes, requiring carryover RINs from the RIN bank to be used to settle blending obligations. As a result, our costs to comply with RFS (excluding the impacts of any exemptions or waivers to which the Petroleum Segment may be entitled) increased significantly throughout 2020, 2021, and remain significant in 2022.
In April 2022, the EPA denied 36 small refinery exemptions (“SRE”) for the 2018 compliance year, many of which had been previously granted by the EPA, and also issued an alternative compliance demonstration approach for certain small refineries (the “Alternate Compliance Ruling”) under which they would not be required to purchase or redeem additional RINs as a result of the EPA’s denial. On June 3, 2022, the EPA revised the 2020 RVO and finalized the 2021 and 2022 RVOs. The EPA also denied 69 petitions from small refineries seeking SREs, including those submitted by Wynnewood Refining Company, LLC for 2019, 2020, and 2021, and applied the Alternate Compliance Ruling to three such petitions. The price of RINs, which continues to remain elevated, did not respond to the EPA announcement, and as a result, we continue to expect significant volatility in the price of RINs during 2022 and into 2023 and such volatility could have material impacts on the Company’s results of operations, financial condition, and cash flows.
In December 2020, the Board approved the renewable diesel project at our Wynnewood Refinery, to convert the Wynnewood Refinery’s hydrocracker to a renewable diesel unit (“RDU”), which is expected to be capable of producing up to 100 million gallons of renewable diesel per year, generating approximately 170 to 180 million RINs annually. The hydrocracker conversion to renewable diesel service was completed in April 2022, and we are continuing to increase production. The production of renewable diesel is expected to significantly reduce our future net exposure to the RFS. Further, the RDU should enable us to capture additional benefits associated with the existing blenders’ tax credit which has been extended to the end of 2024 and growing low carbon fuel standard programs across the country, with programs in place in California and Oregon and new programs anticipated to be implemented over the coming years. In November 2021, the Board approved the pretreater project at the Wynnewood Refinery, which is expected to be completed in the third quarter of 2023 at an estimated cost of $95 million. The pretreatment unit should enable us to process a wider variety of renewable diesel feedstocks at the Wynnewood Refinery, most of which have a lower carbon intensity than soybean oil and generate additional low carbon fuel standard credits. When completed, these collective renewable diesel efforts could effectively mitigate a substantial majority, if not all, of our future RFS exposure, assuming we receive SREs for our Wynnewood Refinery which we believe we are legally entitled to and are pursuing in the courts. However, impacts from recent climate change initiatives under the Biden administration, actions taken by the courts, resulting administration actions under the RFS, and market conditions
could significantly impact the amount by which our renewable diesel business mitigates our costs to comply with the RFS, if at all.
As of September 30, 2022, we have an estimated open position (excluding the impacts of any exemptions or waivers to which we may be entitled) under the RFS for 2020, 2021, and 2022 of approximately 423 million RINs, excluding approximately 32 million of net open, fixed-price commitments to purchase RINs, resulting in a potential liability of $715 million. The Company’s open RFS position, which does not consider open commitments expected to settle in future periods, is marked-to-market each period and thus significant market volatility, as experienced in late 2021 and 2022 to date, could impact our RFS expense from period to period. We recognized expense of approximately $86 million and a benefit of $16 million for the three months ended September 30, 2022 and 2021, respectively, and expense of approximately $328 million and $335 million for the nine months ended September 30, 2022 and 2021, respectively, for the Company’s compliance with the RFS. The increase in expense in 2022 compared to 2021 was driven by an increase in RINs pricing through the third quarter of 2022. Of the expense recognized during the three and nine months ended September 30, 2022, $38 million and $108 million, respectively, relates to the revaluation of our net RVO position as of September 30, 2022. The revaluation represents the summation of the prior period obligation and current period commercial activities, marked at the period end market price. Based upon recent market prices of RINs in September 2022, current estimates related to other variable factors, including our anticipated blending and purchasing activities, and the impact of the open RFS positions and resolution thereof, our estimated consolidated cost to comply with the RFS (without regard to any SREs we may receive) is $390 to $400 million for 2022, net of the estimated RINs generation from our renewable diesel operations of $100 to $110 million.
Market Indicators
NYMEX WTI crude oil is an industry wide benchmark that is utilized in the market pricing of a barrel of crude oil. The pricing differences between other crudes and WTI, known as differentials, show how the market for other crude oils such as WCS, White Cliffs (“Condensate”), Brent Crude (“Brent”), and Midland WTI (“Midland”) are trending. Due to the COVID-19 pandemic, the Russia-Ukraine conflict, and, in each case, actions taken by governments and others in response thereto, refined product prices have experienced extreme volatility. As a result of the current environment, refining margins have been and will continue to be volatile.
As a performance benchmark and a comparison with other industry participants, we utilize NYMEX and Group 3 crack spreads. These crack spreads are a measure of the difference between market prices for crude oil and refined products and are a commonly used proxy within the industry to estimate or identify trends in refining margins. Crack spreads can fluctuate significantly over time as a result of market conditions and supply and demand balances. The NYMEX 2-1-1 crack spread is calculated using two barrels of WTI producing one barrel of NYMEX RBOB Gasoline (“RBOB”) and one barrel of NYMEX NY Harbor ULSD (“HO”). The Group 3 2-1-1 crack spread is calculated using two barrels of WTI crude oil producing one barrel of Group 3 sub-octane gasoline and one barrel of Group 3 ultra-low sulfur diesel.
Both NYMEX 2-1-1 and Group 3 2-1-1 crack spreads increased during the nine months ended September 30, 2022 compared to the nine months ended September 30, 2021. The NYMEX 2-1-1 crack spread averaged $42.16 per barrel during the nine months ended September 30, 2022 compared to $19.05 per barrel in the nine months ended September 30, 2021. The Group 3 2-1-1 crack spread averaged $38.38 per barrel during the nine months ended September 30, 2022 compared to $18.58 per barrel during the nine months ended September 30, 2021.
Average monthly prices for RINs increased 9.7% during the third quarter of 2022 compared to the same period of 2021. On a blended barrel basis (calculated using applicable RVO percentages), RINs approximated $8.02 per barrel during the third quarter of 2022 compared to $7.31 per barrel during the third quarter of 2021.
The charts below are presented, on a per barrel basis, by month through September 30, 2022:
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Crude Oil Differentials against WTI (1)(2) |
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PADD II Group 3 Product Crack Spread and RIN Pricing (2)(3)($/bbl) | | Group 3 Differential against NYMEX WTI (1)(2)($/bbl) |
(1)The change over time in NYMEX - WTI, as reflected in the charts above, is illustrated below.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| (in $/bbl) | Average 2020 | | Average December 2020 | | Average 2021 | | Average December 2021 | | Average 2022 | | Average September 2022 |
| WTI | $ | 39.34 | | | $ | 47.07 | | | $ | 68.11 | | | $ | 71.69 | | | $ | 98.35 | | | $ | 83.80 | |
(2)Information used within these charts was obtained from reputable market sources, including the New York Mercantile Exchange (“NYMEX”), Intercontinental Exchange, and Argus Media, among others.
(3)PADD II is the Midwest Petroleum Area for Defense District (“PADD”), which includes Illinois, Indiana, Iowa, Kansas, Kentucky, Michigan, Minnesota, Missouri, Nebraska, North Dakota, Ohio, Oklahoma, South Dakota, Tennessee and Wisconsin.
Nitrogen Fertilizer Segment
Within the Nitrogen Fertilizer Segment, earnings and cash flows from operations are primarily affected by the relationship between nitrogen fertilizer product prices, utilization, and operating costs and expenses, including pet coke and natural gas feedstock costs.
The price at which nitrogen fertilizer products are ultimately sold depends on numerous factors, including the global supply and demand for nitrogen fertilizer products, world grain demand and production levels, inflation, global supply disruptions, changes in world population, the cost and availability of fertilizer transportation infrastructure, local market conditions, operating levels of competing facilities, weather conditions, the availability of imports, impacts of foreign imports and foreign subsidies thereof, and the extent of government intervention in agriculture markets. These factors can impact, among other things, the level of inventories in the market, resulting in price volatility and a reduction in product margins. Moreover, the industry typically experiences seasonal fluctuations in demand for nitrogen fertilizer products.
As a result of the Russian invasion of Ukraine, the Black Sea, a major export point for nitrogen fertilizer and grains from these countries, has been closed to exports, which prompted tightening global supply conditions for nitrogen fertilizer in advance of spring planting and wheat and corn availability, two major exports from this region. Further, while fertilizers have not been formally sanctioned by countries, many customers are either unwilling to purchase Russian fertilizers or logistics make it too costly to import these fertilizers. Additionally, natural gas supplied from Russia to Western Europe has been constrained, and natural gas prices have remained elevated since September 2021, causing a significant portion of European nitrogen fertilizer production capacity to be curtailed or costs to be elevated compared to competitors in other regions of the world. Overall, these events have caused grain and fertilizer prices to rise, and we currently expect these conditions to persist through the spring of 2023.
Market Indicators
While there is risk of shorter-term volatility given the inherent nature of the commodity cycle, the Company believes the long-term fundamentals for the U.S. nitrogen fertilizer industry remain intact. The Nitrogen Fertilizer Segment views the anticipated combination of (i) increasing global population, (ii) decreasing arable land per capita, (iii) continued evolution to more protein-based diets in developing countries, (iv) sustained use of corn and soybeans as feedstock for the domestic production of ethanol and other renewable fuels, and (v) positioning at the lower end of the global cost curve should provide a solid foundation for nitrogen fertilizer producers in the U.S. over the longer term.
Corn and soybeans are two major crops planted by farmers in North America. Corn crops result in the depletion of the amount of nitrogen within the soil in which it is grown, which in turn, results in the need for this nutrient to be replenished after each growing cycle. Unlike corn, soybeans are able to obtain most of their own nitrogen through a process known as “N fixation.” As such, upon harvesting of soybeans, the soil retains a certain amount of nitrogen which results in lower demand for nitrogen fertilizer for the following corn planting cycle. Due to these factors, nitrogen fertilizer consumers generally operate a balanced corn-soybean rotational planting cycle as evident by the chart presented below as of September 30, 2022.
The relationship between the total acres planted for both corn and soybeans has a direct impact on the overall demand for nitrogen products, as the market and demand for nitrogen increases with increased corn acres and decreases with increased soybean acres. Additionally, an estimated 11.8 billion pounds of soybean oil is expected to be used in producing cleaner renewables in marketing year 2022/2023. Multiple refiners have announced renewable diesel expansion projects for 2022 and beyond, which will only increase the demand for soybeans and potentially for corn and canola.
The United States Department of Agriculture (“USDA”) estimates that in spring 2022 farmers planted 88.6 million corn acres, representing a decrease of 5.0% as compared to 93.3 million corn acres in 2021. Planted soybean acres are estimated to be 87.5 million, representing a 0.3% increase as compared to 87.2 million soybean acres in 2021. The combined corn and soybean planted acres of 176.1 million is in line with the acreage planted in 2021, which was the highest in history. Due to higher input costs for corn planting and increased demand for soybeans, particularly for renewable diesel production, it was more favorable for farmers to plant soybeans compared to corn. The lower planted corn acres in 2022 is expected to be supportive of corn prices for the remainder of 2022 and 2023.
Ethanol is blended with gasoline to meet renewable fuel standard requirements and for its octane value. Ethanol production has historically consumed approximately 35% of the U.S. corn crop, so demand for corn generally rises and falls with ethanol demand, as evidenced by the charts below through September 30, 2022.
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U.S. Plant Production of Fuel Ethanol (1) | | Corn and Soybean Planted Acres (2) |
(1)Information used within this chart was obtained from the EIA through September 30, 2022.
(2)Information used within this chart was obtained from the USDA, National Agricultural Statistics Services as of September 30, 2022.
Weather continues to be a critical variable for crop production. Even with high planted acres and trendline yields per acre in the U.S., inventory levels for corn and soybeans remain below historical levels and prices have remained elevated. With tight
grain and fertilizer inventory levels driven by the war in Ukraine, prices for grains and fertilizers are expected to remain elevated through the spring of 2023. While the weather conditions were difficult early in spring 2022, farmers were able to complete the crop planting later than normal. Demand for nitrogen fertilizer, as well as other crop inputs, was strong for the spring 2022 planting season. During the summer 2022 growing season, severe drought conditions were experienced in Asia, Europe, and parts of the U.S. As a result, crop yields are projected to be below expectations and grain inventories are projected to be at the low end of historical levels, causing grain prices to rise during the three months ended September 30, 2022. We expect tight grain inventories to positively impact planted acreage for the spring of 2023 and boost the demand for nitrogen fertilizer.
On June 30, 2021, CF Industries Nitrogen, L.L.C., Terra Nitrogen, Limited Partnership, and Terra International (Oklahoma) LLC filed petitions with the U.S. Department of Commerce (“USDOC”) and the U.S. International Trade Commission (the “ITC”) requesting the initiation of antidumping and countervailing duty investigations on imports of UAN from Russia and Trinidad and Tobago (“Trinidad”). On July 18, 2022, the ITC made a negative final injury determination concerning its investigation of imports from Russia and Trinidad despite USDOC’s final determination in June that UAN is subsidized and dumped in the U.S. market by producers in both countries. Since the decision in July 2022, we have observed minimal impact on the supply or demand for nitrogen fertilizer.
The charts below show relevant market indicators for the Nitrogen Fertilizer Segment by month through September 30, 2022:
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Ammonia and UAN Market Pricing (1) | | Natural Gas and Pet Coke Market Pricing (1) |
(1)Information used within these charts was obtained from various third-party sources, including Green Markets (a Bloomberg Company), Pace Petroleum Coke Quarterly, and the EIA, amongst others.
Results of Operations
Consolidated
Our consolidated results of operations include certain other unallocated corporate activities and the elimination of intercompany transactions and, therefore, do not equal the sum of the operating results of the Petroleum Segment and Nitrogen Fertilizer Segment.
Consolidated Financial Highlights (Three and Nine Months Ended September 30, 2022 versus September 30, 2021)
| | | | | | | | |
| Operating Income | | Net Income Attributable to CVR Energy Stockholders |
| | | | | | | | |
| Earnings per Share | | EBITDA (1) |
(1)See “Non-GAAP Reconciliations” section below for reconciliations of the non-GAAP measures shown above.
Three and Nine Months Ended September 30, 2022 versus September 30, 2021 (Consolidated)
Overview - For the three months ended September 30, 2022, the Company’s operating income and net income were $103 million and $80 million, respectively, a decrease of $72 million and $26 million, respectively, compared to operating income and net income of $175 million and $106 million, respectively, during the three months ended September 30, 2021. For the nine months ended September 30, 2022, the Company’s operating income and net income were $726 million and $472 million, respectively, an increase of $680 million and $423 million, respectively, compared to operating income and net income of $46 million and $49 million, respectively, during the nine months ended September 30, 2021. Refer to our discussion of each segment’s results of operations below for further information.
Investment Income (Loss) on Marketable Securities - On June 10, 2021, the Company distributed substantially all of its holdings in Delek US Holdings, Inc. (“Delek”), of which the Company was the largest stockholder holding approximately 14.3% of Delek’s outstanding common stock, as part of a special dividend. On January 18, 2022, the Company divested its remaining nominal holdings in Delek, and as of September 30, 2022, the Company does not hold an investment in other marketable securities of Delek. There was no dividend income received during the three and nine months ended September 30,
2022 and 2021. The Company did not recognize a gain or loss on the investment during the three and nine months ended September 30, 2022, and for the three and nine months ended September 30, 2021, the Company recognized an unrealized loss of $1 million and a gain of $82 million, respectively.
Other Income (Expense), Net - For the three and nine months ended September 30, 2022, the Company’s Other income (expense), net was $3 million and $(81) million, respectively, compared to other income, net of $2 million and $12 million for the three and nine months ended September 30, 2021, respectively. The change related to the nine months ended September 30, 2022 was primarily attributable to the expected settlement of litigation. Refer to Part I, Item 1, Note 12 (“Commitments and Contingencies”) of this Report for further discussion.
Income Tax Expense (Benefit) - Income tax expense for the three and nine months ended September 30, 2022 was $7 million and $106 million, or 8.3% and 18.4% of income before income tax, respectively, as compared to income tax expense (benefit) for the three and nine months ended September 30, 2021 of $47 million and $(1) million, or 30.8% and (2.1)% of income before income tax, respectively. The fluctuations in income tax expense and effective income tax rate were due primarily to changes in pretax earnings and earnings attributable to noncontrolling interest from the three and nine months ended September 30, 2021 to the three and nine months ended September 30, 2022.
Petroleum Segment
The Petroleum Segment utilizes certain inputs within its refining operations. These inputs include crude oil, butanes, natural gasoline, ethanol, and bio-diesel (these are also known as “throughputs”).
Refining Throughput and Production Data by Refinery
| | Throughput Data | Throughput Data | Three Months Ended
June 30, | | Six Months Ended
June 30, | Throughput Data | Three Months Ended
September 30, | | Nine Months Ended
September 30, |
| (in bpd) | 2022 | | 2021 | | 2022 | | 2021 | |
| (in barrels per day (“bpd”)) | | (in barrels per day (“bpd”)) | 2022 | | 2021 | | 2022 | | 2021 |
| Coffeyville | Coffeyville | | | | | | | | Coffeyville | | | | | | | |
| Regional crude | Regional crude | 66,266 | | | 27,126 | | | 53,089 | | | 28,173 | | Regional crude | 60,762 | | | 28,492 | | | 55,675 | | | 28,281 | |
| WTI | WTI | 34,513 | | | 70,329 | | | 41,127 | | | 61,681 | | WTI | 30,261 | | | 63,779 | | | 37,465 | | | 62,388 | |
| WTL | WTL | 1,317 | | | — | | | 662 | | | — | | WTL | 312 | | | 1,547 | | | 544 | | | 522 | |
| WTS | | WTS | 1,222 | | | — | | | 412 | | | — | |
| | Midland WTI | Midland WTI | — | | | — | | | 1,294 | | | — | | Midland WTI | — | | | 1,633 | | | 858 | | | 550 | |
| Condensate | Condensate | 10,596 | | | 13,412 | | | 10,972 | | | 10,249 | | Condensate | 10,674 | | | 5,532 | | | 10,871 | | | 8,659 | |
| Heavy Canadian | Heavy Canadian | 6,468 | | | 3,703 | | | 6,614 | | | 1,862 | | Heavy Canadian | 7,372 | | | 4,851 | | | 6,869 | | | 2,869 | |
| DJ Basin | DJ Basin | 10,763 | | | 13,522 | | | 14,379 | | | 15,119 | | DJ Basin | 13,526 | | | 17,274 | | | 14,092 | | | 15,845 | |
| | Other feedstocks and blendstocks | Other feedstocks and blendstocks | 9,270 | | | 9,987 | | | 10,301 | | | 9,359 | | Other feedstocks and blendstocks | 8,846 | | | 10,656 | | | 9,811 | | | 9,796 | |
| Wynnewood | Wynnewood | | Wynnewood | |
| Regional crude | Regional crude | 47,392 | | | 60,636 | | | 45,407 | | | 57,913 | | Regional crude | 45,840 | | | 62,091 | | | 45,553 | | | 59,321 | |
| | WTL | WTL | 1,660 | | | 7,422 | | | 1,006 | | | 5,489 | | WTL | 4,915 | | | 2,809 | | | 2,323 | | | 4,586 | |
| Midland WTI | Midland WTI | — | | | — | | | 813 | | | — | | Midland WTI | — | | | 4,312 | | | 539 | | | 1,453 | |
| WTS | WTS | — | | | — | | | 288 | | | — | | WTS | — | | | — | | | 191 | | | — | |
| Condensate | Condensate | 10,710 | | | 7,559 | | | 10,499 | | | 8,544 | | Condensate | 15,313 | | | 4,736 | | | 12,121 | | | 7,260 | |
| | Other feedstocks and blendstocks | Other feedstocks and blendstocks | 2,291 | | | 2,930 | | | 2,855 | | | 3,055 | | Other feedstocks and blendstocks | 2,614 | | | 3,231 | | | 2,774 | | | 3,115 | |
| Total throughput | Total throughput | 201,246 | | | 216,626 | | | 199,306 | | | 201,444 | | Total throughput | 201,657 | | | 210,943 | | | 200,098 | | | 204,645 | |
JuneSeptember 30, 2022 | 35
| | Production Data | Production Data | Three Months Ended
June 30, | | Six Months Ended
June 30, | Production Data | Three Months Ended
September 30, | | Nine Months Ended
September 30, |
| (in bpd) | (in bpd) | 2022 | | 2021 | | 2022 | | 2021 | (in bpd) | 2022 | | 2021 | | 2022 | | 2021 |
| Coffeyville | Coffeyville | | | | | | | | Coffeyville | | | | | | | |
| Gasoline | Gasoline | 71,003 | | 72,440 | | 73,015 | | 67,081 | Gasoline | 67,048 | | 70,729 | | 71,005 | | 68,310 |
| Distillate | Distillate | 58,769 | | 56,123 | | 56,728 | | 51,359 | Distillate | 56,848 | | 53,946 | | 56,768 | | 52,231 |
| Other liquid products | Other liquid products | 5,730 | | 5,752 | | 5,361 | | 4,934 | Other liquid products | 4,832 | | 4,971 | | 5,183 | | 4,947 |
| Solids | Solids | 4,342 | | 4,650 | | 4,351 | | 4,027 | Solids | 4,741 | | 4,355 | | 4,482 | | 4,138 |
| Wynnewood | Wynnewood | | Wynnewood | |
| Gasoline | Gasoline | 33,255 | | 40,830 | | 31,322 | | 39,152 | Gasoline | 36,423 | | 39,647 | | 33,040 | | 39,319 |
| Distillate | Distillate | 22,316 | | 31,471 | | 22,416 | | 30,324 | Distillate | 24,605 | | 32,410 | | 23,154 | | 31,026 |
| Other liquid products | Other liquid products | 4,897 | | 3,010 | | 5,015 | | 2,979 | Other liquid products | 6,264 | | 2,524 | | 5,436 | | 2,826 |
| Solids | Solids | 7 | | 20 | | 13 | | 21 | Solids | 8 | | 16 | | 12 | | 19 |
| Total production | Total production | 200,319 | | 214,296 | | 198,221 | | 199,877 | Total production | 200,769 | | 208,598 | | 199,080 | | 202,816 |
| Light product yield (as % of crude throughput) (1) | Light product yield (as % of crude throughput) (1) | 97.7 | % | | 98.6 | % | | 98.6 | % | | 99.4 | % | Light product yield (as % of crude throughput) (1) | 97.2 | % | | 99.8 | % | | 98.1 | % | | 99.6 | % |
Liquid volume yield (as % of total throughput) (2) | Liquid volume yield (as % of total throughput) (2) | 97.4 | % | | 96.8 | % | | 97.3 | % | | 97.2 | % | Liquid volume yield (as % of total throughput) (2) | 97.2 | % | | 96.8 | % | | 97.2 | % | | 97.1 | % |
Distillate yield (as % of crude throughput) (3) | Distillate yield (as % of crude throughput) (3) | 42.7 | % | | 43.0 | % | | 42.5 | % | | 43.2 | % | Distillate yield (as % of crude throughput) (3) | 42.8 | % | | 43.8 | % | | 42.6 | % | | 43.4 | % |
(1)Total Gasoline and Distillate divided by total Regional crude, WTI, WTL, Midland WTI, WTS, Condensate, Heavy Canadian, and DJ Basin throughput.
(2)Total Gasoline, Distillate, and Other liquid products divided by total throughput.
(3)Total Distillate divided by total Regional crude, WTI, WTL, Midland WTI, WTS, Condensate, Heavy Canadian, and DJ Basin throughput.
Petroleum Segment Financial Highlights (Three and SixNine Months Ended JuneSeptember 30, 2022 versus JuneSeptember 30, 2021)
Overview - For the three months ended JuneSeptember 30, 2022, the Petroleum Segment’s operating income and net income were $297$137 million and $306$152 million, respectively, improvements of $317$2 million and $319$6 million, respectively, compared to operating income and net income of $135 million and $146 million, respectively, for the three months ended September 30, 2021. For the nine months ended September 30, 2022, the Petroleum Segment’s operating income and net income were $564 million and $584 million, respectively, improvements of $565 million and $561 million, respectively, compared to operating loss and net lossincome of $20$1 million and $13$23 million, respectively, for the threenine months ended JuneSeptember 30, 2021. These improvements were primarily due to improved crack spreads, partially offset by increased RINs, utilities, and labor and utility costs and derivative losses. Forcosts. The increases during the sixnine months ended JuneSeptember 30, 2022 the Petroleum Segment’s operating income and net income were $427 million and $432 million, respectively, improvements of $563 million and $555 million, respectively, compared to operating loss and net loss of $136 million and $123 million, respectively, for the six months ended June 30, 2021. These improvements were primarilyalso due to improved crack spreads and lower RINs cost, partially offset by increased labor and utility costs.an increase in crude oil prices.
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| Net Sales | | Operating Income (Loss) |
JuneSeptember 30, 2022 | 36
| | | | | | | | |
Net Income (Loss) | | EBITDA (1) |
(1)See “Non-GAAP Reconciliations” section below for reconciliations of the non-GAAP measures shown above.
Net Sales - For the three and sixnine months ended JuneSeptember 30, 2022, net sales for the Petroleum Segment increased $1.2 billion$732 million and $2.0$2.7 billion, respectively, when compared to the three and sixnine months ended JuneSeptember 30, 2021. The increases in net sales were due to increased prices resulting from tight inventory levels and the ongoing conflict in Ukraine during the three and sixnine months ended JuneSeptember 30, 2022, compared to the three and sixnine months ended JuneSeptember 30, 2021. Further, net sales for the sixnine months ended JuneSeptember 30, 2021 were impacted by Winter Storm Uri, resulting in reduced production rates at both refineries.
| | | | | | | | |
Refining Margin (1) | | Refining Margin (excluding Inventory Valuation Impacts) (1) |
JuneSeptember 30, 2022 | 37
| | | | | | | | |
Refining Margin (1) | | Refining Margin (excluding Inventory Valuation Impacts) (1) |
(1)See “Non-GAAP Reconciliations” section below for reconciliations of the non-GAAP measures shown above.
Refining Margin - For the three months ended JuneSeptember 30, 2022, refining margin was $478$307 million, or $26.10$16.56 per throughput barrel, as compared to $133$292 million, or $6.72$15.03 per throughput barrel, for the three months ended JuneSeptember 30, 2021. The increase in refining margin of $345$15 million was primarily due to an increase in product crack spreads. The Group 3 2-1-1 crack spread increased by $29.35$23.79 per barrel relative to the secondthird quarter of 2021, driven by tight inventory levels and supply concerns due to the ongoing Russia-Ukraine conflict. The Petroleum Segment recognized costs to comply with RFS of $102$98 million, or $5.55$5.28 per throughput barrel, which excludes the RINs revaluation expense impact of $51$38 million, or $2.79$2.06 per total throughput barrel, for the three months ended JuneSeptember 30, 2022. This is compared to RFS compliance costs of $115$100 million, or $5.85$5.14 per throughput barrel, which excludes the RINs revaluation benefit impact of $58$115 million, or $2.92$5.94 per total throughput barrel, for the three months ended JuneSeptember 30, 2021. For the three months ended September 30, 2022, the Petroleum Segment’s RFS compliance costs included $50 million of RINs purchased from our renewable diesel operations. The decrease in RFS compliance costs in 2022 was primarily related to a lower renewable volume obligation for the three months ended JuneSeptember 30, 2022 compared to the prior period. The decreaseincrease in RINs revaluation in 2022 was a result of decreasedincreased RINs prices for the current period and the EPA revising the 2020 RVO and finalizing the 2021 and 2022 RVOs. Offsetting these impacts for the three months ended June 30, 2022, throughput volumes declined by 15,380 bpd due to the completion of the planned turnaround at the Wynnewood refinery in early April 2022 and the conversion of the Wynnewood hydrokracker to renewable diesel service in the current period.increased commercial activity. The Petroleum Segment also recognized a net lossgain on derivatives of $61$13 million during the three months ended JuneSeptember 30, 2022 compared to a derivativenet loss on derivatives of $2$12 million during the three months ended JuneSeptember 30, 2021. Our derivative activity was primarily a result of inventory hedging activity, Canadian crude oil purchases and sales, and crack spread swaps. Offsetting these impacts, crude oil prices decreased for the three months ended September 30, 2022, which led to an unfavorable inventory valuation impact of $107 million, or $5.78 per total throughput barrel, compared to a favorable inventory valuation impact of $8 million, or $0.41 per total throughput barrel for the three months ended September 30, 2021. Further, for the three months ended September 30, 2022, throughput volumes declined by 9,286 bpd due to minor plant outages during the period.
For the sixnine months ended JuneSeptember 30, 2022, refining margin was $775 million,$1.1 billion, or $21.50$19.82 per throughput barrel, as compared to $184$475 million, or $5.04$8.51 per throughput barrel, for the sixnine months ended JuneSeptember 30, 2021. The increase in refining margin of $591$608 million was primarily due to an increase in product crack spreads.spreads and crude oil prices. The Group 3 2-1-1 crack spread increased by $17.80$19.80 per barrel relative to the sixnine months ended JuneSeptember 30, 2021, driven by increasing refined product demand, tight inventory levels, and supply concerns due to the ongoing Russia-Ukraine conflict. Offsetting these impacts for the six months ended June 30, 2022, throughput volumes declined by 2,138 bpd due to the Wynnewood turnaround in the first quarter of 2022, startup of the RDU, and minor plant outages in the current period. The Petroleum Segment recognized costs to comply with RFS of $189 million, or $5.24 per throughput barrel, which excludes the RINs revaluation impact of $70 million, or $1.95 per total throughput barrel, for the six months ended June 30, 2022. This is compared to RFS compliance costs of $182 million, or $4.99 per throughput barrel, which excludes the RINs revaluation impact of $169 million, or $4.63 per total throughput barrel, for the six months ended June 30, 2021. The decrease in RFS compliance costs in 2022 was primarily related to lower RINs prices and throughput for the six months ended June 30, 2022 compared to the prior period. The decrease in RINs revaluation in 2022 was a result of decreased volatility in RINs prices for the current period and the EPA revising the 2020 RVO and finalizing the 2021 and 2022 RVOs. The Petroleum Segment also recognized a net loss on derivatives of $53$40 million during the sixnine months ended JuneSeptember 30,
2022 compared to a derivativenet loss on derivatives of $34$46 million during the sixnine months ended JuneSeptember 30, 2021. Our derivative activity was primarily a result of inventory hedging activity, Canadian crude oil purchases and sales, and crack spread swaps. Offsetting these impacts for the nine months ended September 30, 2022, throughput volumes declined by 4,547 bpd due to the Wynnewood turnaround in the first quarter of 2022, startup of the RDU limiting crude unit capacity, and minor plant outages in the current period. The Petroleum Segment recognized costs to comply with RFS of $287 million, or $5.26 per throughput barrel, which excludes the RINs revaluation expense impact of $108 million, or $1.98 per total throughput barrel, for the nine
months ended September 30, 2022. This is compared to RFS compliance costs of $282 million, or $5.04 per throughput barrel, which excludes the RINs revaluation expense impact of $54 million, or $0.96 per total throughput barrel, for the nine months ended September 30, 2021. For the nine months ended September 30, 2022, the Petroleum Segment’s RFS compliance costs included $68 million of RINs purchased from our renewable diesel operations. The increase in RFS compliance costs in 2022 was primarily related to increased RINs prices for the nine months ended September 30, 2022 compared to the prior period. The increase in RINs revaluation in 2022 was a result of increased RINs prices for the current period. Crude oil prices increased for the nine months ended September 30, 2022, which led to a continued favorable inventory valuation impact of $63 million, or $1.16 per total throughput barrel, compared to a favorable inventory valuation impact of $109 million, or $1.96 per total throughput barrel, during the third quarter of 2021.
| | | | | | | | |
Direct Operating Expenses (1) | | Direct Operating Expenses (1) |
(1)Exclusive of depreciation and amortization expense.
Direct Operating Expenses (Exclusive of Depreciation and Amortization) - For the three and sixnine months ended JuneSeptember 30, 2022, direct operating expenses (exclusive of depreciation and amortization) were $112$103 million and $211$314 million, respectively, as compared to $83$88 million and $182$270 million for the three and sixnine months ended JuneSeptember 30, 2021, respectively. The increases in the current periods were primarily due to increased natural gas costs, electricity costs, repairs and maintenance expense, and personnel costs. On a total throughput barrel basis, direct operating expenses increased to $6.12$5.53 and $5.85 per barrel, for three and six months ended June 30, 2022, respectively, from $4.23 and $4.99$5.74 per barrel, for the three and sixnine months ended JuneSeptember 30, 2022, respectively, from $4.52 and $4.83 per barrel, for the three and nine months ended September 30, 2021, respectively, which was due to increased costs mentioned above and decreased throughput volume compared to the prior periods caused by the Wynnewood turnaround in the first quarter of 2022, startup of the RDU in the second quarter of 2022, and minor plant outages in the current period.periods.
| | | | | | | | |
| Depreciation and Amortization | | Selling, General and Administrative
Expenses, and Other |
Depreciation and Amortization Expense - For the three and sixnine months ended JuneSeptember 30, 2022, depreciation and amortization expense decreased $5$3 million and $9$12 million, respectively, compared to the three and sixnine months ended JuneSeptember 30, 2021, primarily due to assets being fully depreciated in 2021 and early 2022.
Selling, General, and Administrative Expenses, and Other - For the three and sixnine months ended JuneSeptember 30, 2022, selling, general and administrative expenses and other were $23$20 million and $44$65 million, respectively, as compared to $19 million and $36$54 million, for the three and sixnine months ended JuneSeptember 30, 2021, respectively. The increases were primarily a result of increased personnel costs, driven by higherpartially attributable to share-based compensation.compensation as a result of an increase in market prices for CVR Energy’s common shares during the nine months ended September 30, 2022.
Nitrogen Fertilizer Segment
Utilization and Production Volumes - The following tables summarize the consolidated ammonia utilization from the Nitrogen Fertilizer Segment’s facilities in Coffeyville, Kansas (the “Coffeyville Fertilizer Facility”) and East Dubuque, Illinois (the “East Dubuque Fertilizer Facility”). Utilization is an important measure used by management to assess operational output at each of the Nitrogen Fertilizer Segment’s facilities. Utilization is calculated as actual tons of ammonia produced divided by capacity adjusted for planned maintenance and turnarounds.
Utilization is presented solely on ammonia production rather than each nitrogen product as it provides a comparative baseline against industry peers and eliminates the disparity of facility configurations for upgrade of ammonia into other nitrogen products. With effortsproduction primarily focused on ammonia upgrade capabilities, we believe this measure provides a meaningful view of how well we operate.
Gross tons produced for ammonia represent the total ammonia produced, including ammonia produced that was upgraded into other fertilizer products. Net tons available for sale represent the ammonia available for sale that was not upgraded into
other fertilizer products. The table below presents all of these Nitrogen Fertilizer Segment metrics for the three and sixnine months ended JuneSeptember 30, 2022 and 2021:
| | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | Three Months Ended
September 30, | | Nine Months Ended
September 30, |
| | 2022 | | 2021 | | 2022 | | 2021 | | 2022 | | 2021 | | 2022 | | 2021 |
| Consolidated Ammonia Utilization | Consolidated Ammonia Utilization | 89 | % | | 98 | % | | 88 | % | | 93 | % | Consolidated Ammonia Utilization | 52 | % | | 94 | % | | 76 | % | | 93 | % |
| Production Volumes (in thousands of tons) | Production Volumes (in thousands of tons) | | Production Volumes (in thousands of tons) | |
| Ammonia (gross produced) | Ammonia (gross produced) | 193 | | | 217 | | | 380 | | 404 | Ammonia (gross produced) | 114 | | | 205 | | | 494 | | 610 |
| Ammonia (net available for sale) | Ammonia (net available for sale) | 50 | | | 70 | | | 102 | | 140 | Ammonia (net available for sale) | 36 | | | 65 | | | 137 | | 205 |
| UAN | UAN | 331 | | | 334 | | | 648 | | 606 | UAN | 184 | | | 314 | | | 832 | | 920 |
|
On a consolidated basis for the three and sixnine months ended JuneSeptember 30, 2022, the Nitrogen Fertilizer Segment’s utilization decreased to 89%52% and 88%76%, respectively. The decreases during the current periods were primarily due to the completion of planned turnarounds at both fertilizer facilities in the third quarter of 2022, along with unplanned downtime in 2022 associated with the Messer air separation plant (“Messer”(the “Messer Outages”) at the Coffeyville Fertilizer Facility and various pieces of equipment at the East Dubuque Fertilizer Facility.
Sales and Pricing per Ton - Two of the Nitrogen Fertilizer Segment’s key operating metrics are total sales volumes for ammonia and UAN, along with the product pricing per ton realized at the gate. Total product sales volumes were unfavorable driven by lower production at both fertilizer facilities due to the planned turnarounds in the third quarter of 2022, as well as increased downtime from the Messer Outages at the Coffeyville Fertilizer Facility due to reduced downtime from Messer outages and various pieces of equipment at the East Dubuque Fertilizer Facility in 2022, as compared to 2021. For the three and sixnine months ended JuneSeptember 30, 2022, total product sales were favorable, driven by sales price increases of 193%65% and 202%155%, respectively, for ammonia and 134%42% and 154%107%, respectively, for UAN. Ammonia and UAN sales prices were favorable primarily due to lower fertilizer supply driven by production outages from Hurricane Ida in August and September 2021, increased industry turnaround activity, energy shortages in Europe and Asia, and theongoing impacts from the Russia-Ukraine conflict, coupled withincluding reduced production from Europe as a result of the high energy price environment, and higher crop pricing. Product pricing at the gate represents net sales less freight revenue divided by product sales volume in tons and is shown in order to provide a pricing measure comparable across the fertilizer industry.
| | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | Three Months Ended
September 30, | | Nine Months Ended
September 30, |
| | 2022 | | 2021 | | 2022 | | 2021 | | 2022 | | 2021 | | 2022 | | 2021 |
| Consolidated sales (thousand tons) | Consolidated sales (thousand tons) | | | | | | | | Consolidated sales (thousand tons) | | | | | | | |
| Ammonia | Ammonia | 52 | | | 80 | | | 91 | | | 112 | | Ammonia | 27 | | | 52 | | | 118 | | | 164 | |
| UAN | UAN | 287 | | | 370 | | | 609 | | | 609 | | UAN | 275 | | | 322 | | | 884 | | | 931 | |
| | Consolidated product pricing at gate (dollars per ton) | Consolidated product pricing at gate (dollars per ton) | | Consolidated product pricing at gate (dollars per ton) | |
| Ammonia | Ammonia | $ | 1,182 | | | $ | 403 | | | $ | 1,127 | | | $ | 373 | | Ammonia | $ | 837 | | | $ | 507 | | | $ | 1,062 | | | $ | 416 | |
| UAN | UAN | 555 | | | 237 | | | 524 | | | 206 | | UAN | 433 | | | 305 | | | 496 | | | 240 | |
Feedstock - The Coffeyville Fertilizer Facility utilizes a pet coke gasification process to produce nitrogen fertilizer. The East Dubuque Fertilizer Facility uses natural gas in its production of ammonia. The table below presents these feedstocks for
both fertilizer facilities within the Nitrogen Fertilizer Segment for the three and sixnine months ended JuneSeptember 30, 2022 and 2021:
| | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | Three Months Ended
September 30, | | Nine Months Ended
September 30, |
| | 2022 | | 2021 | | 2022 | | 2021 | | 2022 | | 2021 | | 2022 | | 2021 |
| Petroleum coke used in production (thousand tons) | Petroleum coke used in production (thousand tons) | 116 | | | 134 | | | 224 | | | 262 | | Petroleum coke used in production (thousand tons) | 74 | | | 129 | | | 298 | | | 390 | |
Petroleum coke (dollars per ton) | Petroleum coke (dollars per ton) | $ | 49.91 | | | $ | 36.69 | | | $ | 53.06 | | | $ | 39.73 | | Petroleum coke (dollars per ton) | $ | 51.54 | | | $ | 50.35 | | | $ | 52.68 | | | $ | 43.23 | |
Natural gas used in production (thousands of MMBtu) (1) | Natural gas used in production (thousands of MMBtu) (1) | 1,936 | | | 2,154 | | | 3,697 | | | 4,036 | | Natural gas used in production (thousands of MMBtu) (1) | 1,120 | | | 2,043 | | | 4,817 | | | 6,079 | |
Natural gas used in production (dollars per MMBtu) (1) | Natural gas used in production (dollars per MMBtu) (1) | $ | 7.34 | | | $ | 3.04 | | | $ | 6.48 | | | $ | 3.07 | | Natural gas used in production (dollars per MMBtu) (1) | $ | 7.19 | | | $ | 4.29 | | | $ | 6.65 | | | $ | 3.48 | |
Natural gas in cost of materials and other (thousands of MMBtu) (1) | Natural gas in cost of materials and other (thousands of MMBtu) (1) | 1,707 | | | 2,711 | | | 3,235 | | | 3,650 | | Natural gas in cost of materials and other (thousands of MMBtu) (1) | 1,330 | | | 1,786 | | | 4,566 | | | 5,436 | |
Natural gas in cost of materials and other (dollars per MMBtu) (1) | Natural gas in cost of materials and other (dollars per MMBtu) (1) | $ | 5.98 | | | $ | 3.06 | | | $ | 5.81 | | | $ | 3.03 | | Natural gas in cost of materials and other (dollars per MMBtu) (1) | $ | 7.84 | | | $ | 3.78 | | | $ | 6.40 | | | $ | 3.27 | |
|
(1)The feedstock natural gas shown above does not include natural gas used for fuel. The cost of fuel natural gas is included in Direct operating expenses (exclusive of depreciation and amortization).
Nitrogen Fertilizer Segment Financial Highlights (Three and SixNine Months Ended JuneSeptember 30, 2022 versus JuneSeptember 30, 2021)
Overview - For the three months ended JuneSeptember 30, 2022, the Nitrogen Fertilizer Segment’s operating loss and net loss were $12 million and $20 million, respectively, representing reductions of $58 million and $55 million, respectively, compared to operating income and net income of $46 million and $35 million, respectively, for the three months ended September 30, 2021. These decreases were primarily driven by lower production and sales volumes and higher direct operating expenses as a result of the two planned turnarounds during the third quarter of 2022 compared to the three months ended September 30, 2021. For the nine months ended September 30, 2022, the Nitrogen Fertilizer Segment’s operating income and net income were $126$218 million and $118 million, respectively, representing improvements of $96 million and $111 million, respectively, compared to operating income and net income of $30 million and $7 million, respectively, for the three months ended June 30, 2021. For the six months ended June 30, 2022, the Nitrogen Fertilizer Segment’s operating income and net income were $230 million and $211$191 million, respectively, representing a $214$155 million and $229$174 million increase in operating income and net income, respectively, compared to operating income and net lossincome of $16$63 million and $18$17 million, respectively, for the sixnine months ended JuneSeptember 30, 2021. These increases for both periods were primarily driven by higher product sales prices for UAN and ammonia, partially offset by increased costs associated with the two turnarounds during the third quarter of 2022, compared to the prior periods.nine months ended September 30, 2021.
| | | | | | | | |
| Net Sales | | Operating (Loss) Income |
JuneSeptember 30, 2022 | 4142
| | | | | | | | |
Net Sales | | Operating(Loss) Income |
| | | | | | | | |
Net Income (Loss) | | EBITDA (1) |
(1)See “Non-GAAP Reconciliations” section below for reconciliations of the non-GAAP measures shown above.
Net Sales - For the three months ended JuneSeptember 30, 2022, the Nitrogen Fertilizer Segment’s net sales increased by $106$11 million to $244$156 million compared to the three months ended JuneSeptember 30, 2021. This increase was primarily due to favorable UAN and ammonia pricing conditions which contributed $131$44 million in higher revenues, partially offset by decreased sales volumes which contributed $31reduced revenues by $27 million, in lower revenues, as compared to the three months ended JuneSeptember 30, 2021.
The following table demonstrates the impact of changes in sales volumes and pricing for the primary components of net sales, excluding urea products, freight, and other revenue, for the three months ended JuneSeptember 30, 2022 as compared to the three months ended JuneSeptember 30, 2021:
| | (in millions) | (in millions) | Price Variance | | Volume Variance | (in millions) | Price Variance | | Volume Variance |
| UAN | UAN | $ | 91 | | | $ | (20) | | UAN | $ | 35 | | | $ | (14) | |
| Ammonia | Ammonia | 40 | | | (11) | | Ammonia | 9 | | | (13) | |
The $779$330 and $318$128 per ton increases in ammonia and UAN sales pricing, respectively, for the three months ended JuneSeptember 30, 2022 as compared to the three months ended JuneSeptember 30, 2021 were primarily attributable to continued tight market conditions following the production outages relateddue to Hurricane Ida in 2021, heightened turnaround activity during the summer of 2021,
energy shortages in Europe and Asia, and furtherlower fertilizer supply concerns due todriven by ongoing impacts from the Russia-Ukraine conflict, coupled withincluding reduced production from Europe as a result of the high energy price environment, and higher crop pricing. The decreasedecreases in UAN and ammonia sales volumes for the three months ended JuneSeptember 30, 2022 compared to the three months ended JuneSeptember 30, 2021 waswere primarily attributable to lower production due to unplanned downtime associated with the Messer outagesplanned turnarounds at both fertilizer facilities during the Coffeyville Fertilizer Facility and various piecesthird quarter of equipment at the East Dubuque Fertilizer Facility in 2022.
For the sixnine months ended JuneSeptember 30, 2022, the Nitrogen Fertilizer Segment’s net sales increased by $268$280 million to $467$623 million compared to the sixnine months ended JuneSeptember 30, 2021. This increase was primarily due to favorable UAN and ammonia pricing conditions which contributed $262$301 million in higher revenues, partially offset by decreased sales volumes which contributed $8reduced revenues by $30 million, in lower revenues, as compared to the sixnine months ended JuneSeptember 30, 2021.
The following table demonstrates the impact of changes in sales volumes and pricing for the primary components of net sales, excluding urea products, freight, and other revenue, for the sixnine months ended JuneSeptember 30, 2022 as compared to the sixnine months ended JuneSeptember 30, 2021:
| | (in thousands) | (in thousands) | Price Variance | | Volume Variance | (in thousands) | Price Variance | | Volume Variance |
| UAN | UAN | $ | 193 | | | $ | — | | UAN | $ | 225 | | | $ | (11) | |
| Ammonia | Ammonia | 69 | | | (8) | | Ammonia | 76 | | | (19) | |
The $754$646 and $318$256 per ton increases in ammonia and UAN sales pricing, respectively, for the sixnine months ended JuneSeptember 30, 2022 as compared to the sixnine months ended JuneSeptember 30, 2021 were primarily attributable to continued tight market conditions following the production outages relateddue to Hurricane Ida in 2021, heightened turnaround activity during the summer of 2021, energy shortages in Europe and Asia, and furtherlower fertilizer supply concerns due todriven by ongoing impacts from the Russia-Ukraine conflict, coupled withincluding reduced production from Europe as a result of the high energy price environment, and higher crop pricing. The depresseddecreases in UAN and ammonia sales volumes for the sixnine months ended JuneSeptember 30, 2022 compared to the sixnine months ended JuneSeptember 30, 2021 waswere primarily attributable to a higher rate of ammonia production converted to UAN for sale, along with lower ammonia production due to unplanned downtime associated with the Messer outagesOutages at the Coffeyville Fertilizer Facility and various pieces of equipment at the East Dubuque Fertilizer Facility in 2022, along with the completion of the planned turnarounds at both fertilizer facilities during the third quarter of 2022.
Cost of Materials and Other - For the three and six months ended JuneSeptember 30, 2022, cost of materials and other was $41$29 million and $71 million, respectively, compared to $26 million for the three months ended September 30, 2021. The increase was driven primarily by an inventory draw contributing $5 million and $44an increase in purchases of ammonia of $4 million, partially offset by lower petroleum coke, natural gas, and hydrogen feedstock costs of $4 million and reduced distribution costs of $2 million.
For the nine months ended September 30, 2022, cost of materials and other was $100 million compared to $70 million for the three and sixnine months ended JuneSeptember 30, 2021, respectively. For the three and six months ended June 30, 2022, increased costs were comprised2021. The increase was driven primarily of $12 million and $13 millionby increases in purchases of nitrogen and ammonia respectively, $8of $17 million, and $12 million increases inincreased natural gas pricing and usage at the East Dubuque Fertilizer Facility, respectively, $2 million and $5 million increases in distribution costs driven by freight, respectively, and $1 million and $2 million increases in pet coke and hydrogen feedstock costs at the Coffeyville Fertilizer Facility, respectively. Theof $12 million, higher distribution costs of $3 million, and an inventory draw contributing $1 million. These increases were partially offset by a higher build in inventories contributing $7lower petroleum coke costs of $1 million.
Direct Operating Expenses (exclusive of depreciation and amortization) -For the three months ended September 30, 2022, direct operating expenses (exclusive of depreciation and amortization) were $109 million compared to $48 million for the three months ended September 30, 2021. The increase was primarily due to increased costs associated with the planned turnarounds at both fertilizer facilities during 2022, which increased turnaround expenses by $31 million, drew down inventory of $16 million, increased repair and maintenance expenses by $8 million, and increased personnel costs by $5 million, respectively.a portion of which was attributable to share-based compensation as a result of an increase in market prices for CVR Partners’ common units during the current period.
For the nine months ended September 30, 2022, direct operating expenses (exclusive of depreciation and amortization) were $218 million compared to $139 million for the nine months ended September 30, 2021. The increase was primarily due to increased turnaround costs associated with the planned turnarounds at both fertilizer facilities during 2022, which increased turnaround expenses by $32 million, increased repair and maintenance expenses by $15 million, drew down inventory of $8 million, and increased personnel costs by $6 million, partially attributable to share-based compensation as a result of an increase in market prices for CVR Partners’ common units during the current period. In addition to these turnaround related increases, there were $12 million in higher prices for natural gas, $3 million of increased operating materials and office costs, $2 million of higher insurance costs, and $1 million related to higher electricity pricing and usage.
Non-GAAP Measures
Our management uses certain non-GAAP performance measures, and reconciliations to those measures, to evaluate current and past performance and prospects for the future to supplement our financial information presented in accordance with accounting principles generally accepted in the United States (“GAAP”). These non-GAAP financial measures are important factors in assessing our operating results and profitability and include the performance and liquidity measures defined below.
The following are non-GAAP measures we present for the period ended JuneSeptember 30, 2022:
EBITDA - Consolidated net income (loss) before (i) interest expense, net, (ii) income tax expense (benefit) and (iii) depreciation and amortization expense.
Petroleum EBITDA and Nitrogen Fertilizer EBITDA - Segment net income (loss) before segment (i) interest expense, net, (ii) income tax expense (benefit), and (iii) depreciation and amortization.
Refining Margin - The difference between our Petroleum Segment net sales and cost of materials and other.
Refining Margin, adjusted for Inventory Valuation Impacts - Refining Margin adjusted to exclude the impact of current period market price and volume fluctuations on crude oil and refined product inventories purchased in prior periods and lower
JuneSeptember 30, 2022 | 4344
of cost or net realizable value adjustments, if applicable. We record our commodity inventories on the first-in-first-out basis. As a result, significant current period fluctuations in market prices and the volumes we hold in inventory can have favorable or unfavorable impacts on our refining margins as compared to similar metrics used by other publicly-traded companies in the refining industry.
Refining Margin and Refining Margin adjusted for Inventory Valuation Impacts, per Throughput Barrel - Refining Margin and Refining Margin adjusted for Inventory Valuation Impacts divided by the total throughput barrels during the period, which is calculated as total throughput barrels per day times the number of days in the period.
Direct Operating Expenses per Throughput Barrel - Direct operating expenses for our Petroleum Segment divided by total throughput barrels for the period, which is calculated as total throughput barrels per day times the number of days in the period.
Adjusted EBITDA, Adjusted Petroleum EBITDA and Adjusted Nitrogen Fertilizer EBITDA - EBITDA, Petroleum EBITDA and Nitrogen Fertilizer EBITDA adjusted for certain significant non-cash items and items that management believes are not attributable to or indicative of our on-going operations or that may obscure our underlying results and trends.
Adjusted Earnings (Loss) per Share - Earnings (loss) per share adjusted for certain significant non-cash items and items that management believes are not attributable to or indicative of our on-going operations or that may obscure our underlying results and trends.
Free Cash Flow - Net cash provided by (used in) operating activities less capital expenditures and capitalized turnaround expenditures.
Net Debt and Finance Lease Obligations - Net debt and finance lease obligations is total debt and finance lease obligations reduced for cash and cash equivalents.
Total Debt and Net Debt and Finance Lease Obligations to EBITDA Exclusive of Nitrogen Fertilizer - Total debt and net debt and finance lease obligations is calculated as the consolidated debt and net debt and finance lease obligations less the Nitrogen Fertilizer Segment’s debt and net debt and finance lease obligations as of the most recent period ended divided by EBITDA exclusive of the Nitrogen Fertilizer Segment for the most recent twelve-month period.
We present these measures because we believe they may help investors, analysts, lenders and ratings agencies analyze our results of operations and liquidity in conjunction with our U.S. GAAP results, including but not limited to our operating performance as compared to other publicly-traded companies in the refining and fertilizer industries, without regard to historical cost basis or financing methods and our ability to incur and service debt and fund capital expenditures. Non-GAAP measures have important limitations as analytical tools, because they exclude some, but not all, items that affect net earnings and operating income. These measures should not be considered substitutes for their most directly comparable U.S. GAAP financial measures. See “Non-GAAP Reconciliations” included herein for reconciliation of these amounts. Due to rounding, numbers presented within this section may not add or equal to numbers or totals presented elsewhere within this document.
Factors Affecting Comparability of Our Financial Results
Our historical results of operations for the periods presented may not be comparable with prior periods or to our results of operations in the future for the reasons discussed below.
Petroleum Segment
Coffeyville Refinery - During the three and sixnine months ended JuneSeptember 30, 2022, we capitalized $1$4 million and $2$5 million, respectively, related to the pre-planning phase of a major planned turnaround that is currently expected to commence in the spring of 2023.
Wynnewood Refinery - The Petroleum Segment’s Wynnewood Refinery’s major planned turnaround began in late February 2022 and was completed in early April 2022. The pre-planning phase began during the first quarter of 2021. We did not capitalize turnaround expenditures for the three months ended September 30, 2022 and capitalized turnaround expenditures of $68 million for nine months ended September 30, 2022. During the three and sixnine months ended June 30, 2022, we capitalized $4 million and $67 million, respectively, and during the three and six months ended JuneSeptember 30, 2021, we capitalized less than $1 million and $1$2 million, respectively, related to the pre-planning activities.
JuneSeptember 30, 2022 | 4445
Nitrogen Fertilizer Segment
Coffeyville Fertilizer Facility - A planned turnaround at the Coffeyville Fertilizer Facility commenced in July 2022 and is expected to bewas completed in early to mid-August 2022. For the three and sixnine months ended JuneSeptember 30, 2022, we incurred turnaround expense of $12 million for both periods related to this turnaround. For the three and nine months ended September 30, 2021, we incurred turnaround expense of less than $1 million for both periods related to planning for thisthe Coffeyville Fertilizer Facility’s 2022 turnaround.
East Dubuque Fertilizer Facility - The nextA planned turnaround at the East Dubuque Fertilizer Facility is currently expected to commence duringcommenced in August 2022 and was completed in mid-September 2022. For the three and sixnine months ended JuneSeptember 30, 2022, we incurred turnaround expense of approximately$20 million and $21 million, respectively, related to this turnaround. For the three and nine months ended September 30, 2021, we incurred turnaround expense of less than $1 million for both periods related to planning for thisthe East Dubuque Fertilizer Facility’s 2022 turnaround.
Non-GAAP Reconciliations
Reconciliation of Net Income (Loss) to EBITDA and Adjusted EBITDA
| | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | Three Months Ended
September 30, | | Nine Months Ended
September 30, |
| (in millions) | (in millions) | 2022 | | 2021 | | 2022 | | 2021 | (in millions) | 2022 | | 2021 | | 2022 | | 2021 |
| Net income (loss) | $ | 239 | | | $ | (2) | | | $ | 392 | | | $ | (57) | | |
| Net income | | Net income | $ | 80 | | | $ | 106 | | | $ | 472 | | | $ | 49 | |
| Interest expense, net | Interest expense, net | 23 | | | 38 | | | 48 | | | 69 | | Interest expense, net | 19 | | | 23 | | | 67 | | | 92 | |
| Income tax expense (benefit) | Income tax expense (benefit) | 66 | | | (6) | | | 99 | | | (48) | | Income tax expense (benefit) | 7 | | | 47 | | | 106 | | | (1) | |
| Depreciation and amortization | Depreciation and amortization | 73 | | | 72 | | | 140 | | | 138 | | Depreciation and amortization | 75 | | | 67 | | | 215 | | | 205 | |
| EBITDA | EBITDA | 401 | | | 102 | | | 679 | | | 102 | | EBITDA | 181 | | | 243 | | | 860 | | | 345 | |
| Adjustments: | Adjustments: | | Adjustments: | |
| Revaluation of RFS liability | Revaluation of RFS liability | 51 | | | 58 | | | 70 | | | 169 | | Revaluation of RFS liability | 38 | | | (115) | | | 108 | | | 54 | |
| Gain on marketable securities | — | | | (21) | | | — | | | (83) | | |
| Unrealized loss (gain) on derivatives | 21 | | | (37) | | | 15 | | | 7 | | |
| Inventory valuation impacts, favorable | (41) | | | (36) | | | (177) | | | (102) | | |
| Loss (gain) on marketable securities | | Loss (gain) on marketable securities | — | | | 1 | | | — | | | (82) | |
| Unrealized gain on derivatives, net | | Unrealized gain on derivatives, net | (20) | | | (22) | | | (5) | | | (16) | |
| Inventory valuation impacts, unfavorable (favorable) | | Inventory valuation impacts, unfavorable (favorable) | 114 | | | (8) | | | (63) | | | (109) | |
Call Option Lawsuits settlement (1) | Call Option Lawsuits settlement (1) | 79 | | | — | | | 79 | | | — | | Call Option Lawsuits settlement (1) | — | | | — | | | 79 | | | — | |
| | Adjusted EBITDA | Adjusted EBITDA | $ | 511 | | | $ | 66 | | | $ | 666 | | | $ | 93 | | Adjusted EBITDA | $ | 313 | | | $ | 99 | | | $ | 979 | | | $ | 192 | |
Reconciliation of Basic and Diluted Earnings (Loss) per Share to Adjusted Earnings (Loss) per Share
| | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | Three Months Ended
September 30, | | Nine Months Ended
September 30, |
| | 2022 | | 2021 | | 2022 | | 2021 | | 2022 | | 2021 | | 2022 | | 2021 |
| Basic and diluted earnings (loss) per share | $ | 1.64 | | | $ | (0.06) | | | $ | 2.57 | | | $ | (0.45) | | |
| Basic and diluted earnings per share | | Basic and diluted earnings per share | $ | 0.92 | | | $ | 0.83 | | | $ | 3.49 | | | $ | 0.38 | |
Adjustments: (2) | Adjustments: (2) | | Adjustments: (2) | |
| Revaluation of RFS liability | Revaluation of RFS liability | 0.38 | | | 0.42 | | | 0.52 | | | 1.25 | | Revaluation of RFS liability | 0.28 | | | (0.85) | | | 0.80 | | | 0.40 | |
| Gain on marketable securities | — | | | (0.15) | | | — | | | (0.61) | | |
| Unrealized loss (gain) on derivatives | 0.16 | | | (0.27) | | | 0.11 | | | 0.05 | | |
| Inventory valuation impacts, favorable | (0.31) | | | (0.26) | | | (1.31) | | | (0.75) | | |
| Loss (gain) on marketable securities | | Loss (gain) on marketable securities | — | | | 0.01 | | | — | | | (0.60) | |
| Unrealized gain on derivatives, net | | Unrealized gain on derivatives, net | (0.15) | | | (0.17) | | | (0.04) | | | (0.12) | |
| Inventory valuation impacts, unfavorable (favorable) | | Inventory valuation impacts, unfavorable (favorable) | 0.85 | | | (0.06) | | | (0.46) | | | (0.81) | |
Call Option Lawsuits settlement (1) | Call Option Lawsuits settlement (1) | 0.58 | | | — | | | 0.58 | | | — | | Call Option Lawsuits settlement (1) | — | | | — | | | 0.58 | | | — | |
| | Adjusted earnings (loss) per share | Adjusted earnings (loss) per share | $ | 2.45 | | | $ | (0.32) | | | $ | 2.47 | | | $ | (0.51) | | Adjusted earnings (loss) per share | $ | 1.90 | | | $ | (0.24) | | | $ | 4.37 | | | $ | (0.75) | |
(1)Refer to Part I, Item 1, Note 12 (“Commitments and Contingencies”) of this Report for further discussion.
(2)Amounts are shown after-tax, using the Company’s marginal tax rate, and are presented on a per share basis using the weighted average shares outstanding for each period.
JuneSeptember 30, 2022 | 4546
Reconciliation of Net Cash Provided By Operating Activities to Free Cash Flow
| | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | Three Months Ended
September 30, | | Nine Months Ended
September 30, |
| | 2022 | | 2021 | | 2022 | | 2021 | | 2022 | | 2021 | | 2022 | | 2021 |
| Net cash provided by operating activities | Net cash provided by operating activities | $ | 390 | | | $ | 147 | | | $ | 712 | | | $ | 243 | | Net cash provided by operating activities | $ | 156 | | | $ | 139 | | | $ | 868 | | | $ | 382 | |
| Less: | Less: | | Less: | |
| Capital expenditures | Capital expenditures | (62) | | | (92) | | | (88) | | | (126) | | Capital expenditures | (57) | | | (62) | | | (145) | | | (188) | |
| Capitalized turnaround expenditures | Capitalized turnaround expenditures | (53) | | | (1) | | | (68) | | | (2) | | Capitalized turnaround expenditures | (6) | | | (1) | | | (74) | | | (3) | |
| Free cash flow | Free cash flow | $ | 275 | | | $ | 54 | | | $ | 556 | | | $ | 115 | | Free cash flow | $ | 93 | | | $ | 76 | | | $ | 649 | | | $ | 191 | |
Reconciliation of Petroleum Segment Net Income (Loss) to EBITDA and Adjusted EBITDA
| | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | Three Months Ended
September 30, | | Nine Months Ended
September 30, |
| (in millions) | (in millions) | 2022 | | 2021 | | 2022 | | 2021 | (in millions) | 2022 | | 2021 | | 2022 | | 2021 |
| Petroleum net income (loss) | $ | 306 | | | $ | (13) | | | $ | 432 | | | $ | (123) | | |
| Petroleum net income | | Petroleum net income | $ | 152 | | | $ | 146 | | | $ | 584 | | | $ | 23 | |
| Interest income, net | Interest income, net | (5) | | | (5) | | | (11) | | | (8) | | Interest income, net | (13) | | | (8) | | | (24) | | | (16) | |
| | Depreciation and amortization | Depreciation and amortization | 46 | | | 51 | | | 93 | | | 102 | | Depreciation and amortization | 47 | | | 50 | | | 140 | | | 152 | |
| Petroleum EBITDA | Petroleum EBITDA | 347 | | | 33 | | | 514 | | | (29) | | Petroleum EBITDA | 186 | | | 188 | | | 700 | | | 159 | |
| Adjustments: | Adjustments: | | Adjustments: | |
| Revaluation of RFS liability | Revaluation of RFS liability | 51 | | | 58 | | | 70 | | | 169 | | Revaluation of RFS liability | 38 | | | (115) | | | 108 | | | 54 | |
| Unrealized loss (gain) on derivatives | 22 | | | (37) | | | 17 | | | 7 | | |
Inventory valuation impacts, favorable (1) | (37) | | | (36) | | | (170) | | | (102) | | |
| Unrealized gain on derivatives, net | | Unrealized gain on derivatives, net | (25) | | | (22) | | | (8) | | | (16) | |
Inventory valuation impacts, unfavorable (favorable) (1) | | Inventory valuation impacts, unfavorable (favorable) (1) | 107 | | | (8) | | | (63) | | | (109) | |
| Petroleum Adjusted EBITDA | Petroleum Adjusted EBITDA | $ | 383 | | | $ | 18 | | | $ | 431 | | | $ | 45 | | Petroleum Adjusted EBITDA | $ | 306 | | | $ | 43 | | | $ | 737 | | | $ | 88 | |
Reconciliation of Petroleum Segment Gross Profit (Loss) to Refining Margin and Refining Margin Adjusted for Inventory Valuation Impact
| | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | Three Months Ended
September 30, | | Nine Months Ended
September 30, |
| (in millions) | (in millions) | 2022 | | 2021 | | 2022 | | 2021 | (in millions) | 2022 | | 2021 | | 2022 | | 2021 |
| Net sales | Net sales | $ | 2,868 | | | $ | 1,648 | | | $ | 5,022 | | | $ | 3,052 | | Net sales | $ | 2,474 | | | $ | 1,742 | | | $ | 7,497 | | | $ | 4,793 | |
| Less: | Less: | | Less: | |
| Cost of materials and other | Cost of materials and other | (2,390) | | | (1,515) | | | (4,247) | | | (2,868) | | Cost of materials and other | (2,167) | | | (1,450) | | | (6,414) | | | (4,318) | |
| Direct operating expenses (exclusive of depreciation and amortization) | Direct operating expenses (exclusive of depreciation and amortization) | (112) | | | (83) | | | (211) | | | (182) | | Direct operating expenses (exclusive of depreciation and amortization) | (103) | | | (88) | | | (314) | | | (270) | |
| Depreciation and amortization | Depreciation and amortization | (46) | | | (51) | | | (93) | | | (102) | | Depreciation and amortization | (47) | | | (50) | | | (140) | | | (152) | |
| Gross profit (loss) | 320 | | | (1) | | | 471 | | | (100) | | |
| Gross profit | | Gross profit | 157 | | | 154 | | | 629 | | | 53 | |
| Add: | Add: | | Add: | |
| Direct operating expenses (exclusive of depreciation and amortization) | Direct operating expenses (exclusive of depreciation and amortization) | 112 | | | 83 | | | 211 | | | 182 | | Direct operating expenses (exclusive of depreciation and amortization) | 103 | | | 88 | | | 314 | | | 270 | |
| Depreciation and amortization | Depreciation and amortization | 46 | | | 51 | | | 93 | | | 102 | | Depreciation and amortization | 47 | | | 50 | | | 140 | | | 152 | |
| Refining margin | Refining margin | 478 | | | 133 | | | 775 | | | 184 | | Refining margin | 307 | | | 292 | | | 1,083 | | | 475 | |
Inventory valuation impacts, favorable (1) | (37) | | | (36) | | | (170) | | | (102) | | |
Inventory valuation impacts, unfavorable (favorable) (1) | | Inventory valuation impacts, unfavorable (favorable) (1) | 107 | | | (8) | | | (63) | | | (109) | |
| Refining margin, adjusted for inventory valuation impacts | Refining margin, adjusted for inventory valuation impacts | $ | 441 | | | $ | 97 | | | $ | 605 | | | $ | 82 | | Refining margin, adjusted for inventory valuation impacts | $ | 414 | | | $ | 284 | | | $ | 1,020 | | | $ | 366 | |
(1)The Petroleum Segment’s basis for determining inventory value under GAAP is First-In, First-Out (“FIFO”). Changes in crude oil prices can cause fluctuations in the inventory valuation of crude oil, work in process and finished goods, thereby resulting in a favorable inventory valuation impact when crude oil prices increase and an unfavorable inventory valuation impact when crude oil prices decrease. The inventory valuation impact is calculated based upon inventory values at the beginning of the accounting period and at the end of the
JuneSeptember 30, 2022 | 4647
accounting period. In order to derive the inventory valuation impact per total throughput barrel, we utilize the total dollar figures for the inventory valuation impact and divide by the number of total throughput barrels for the period.
Reconciliation of Petroleum Segment Total Throughput Barrels
| | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | Three Months Ended
September 30, | | Nine Months Ended
September 30, |
| | 2022 | | 2021 | | 2022 | | 2021 | | 2022 | | 2021 | | 2022 | | 2021 |
| Total throughput barrels per day | Total throughput barrels per day | 201,246 | | | 216,626 | | | 199,306 | | | 201,444 | | Total throughput barrels per day | 201,657 | | | 210,943 | | | 200,098 | | | 204,645 | |
| Days in the period | Days in the period | 91 | | | 91 | | | 181 | | | 181 | | Days in the period | 92 | | | 92 | | | 273 | | | 273 | |
| Total throughput barrels | Total throughput barrels | 18,313,357 | | | 19,712,929 | | | 36,074,355 | | | 36,461,311 | | Total throughput barrels | 18,552,434 | | | 19,406,776 | | | 54,626,789 | | | 55,868,087 | |
Reconciliation of Petroleum Segment Refining Margin per Total Throughput Barrel
| | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | Three Months Ended
September 30, | | Nine Months Ended
September 30, |
| (in millions, except per total throughput barrel) | (in millions, except per total throughput barrel) | 2022 | | 2021 | | 2022 | | 2021 | (in millions, except per total throughput barrel) | 2022 | | 2021 | | 2022 | | 2021 |
| Refining margin | Refining margin | $ | 478 | | | $ | 133 | | | $ | 775 | | | $ | 184 | | Refining margin | $ | 307 | | | $ | 292 | | | $ | 1,083 | | | $ | 475 | |
| Divided by: total throughput barrels | Divided by: total throughput barrels | 18 | | | 20 | | | 36 | | | 36 | | Divided by: total throughput barrels | 19 | | | 19 | | | 55 | | | 56 | |
| Refining margin per total throughput barrel | Refining margin per total throughput barrel | $ | 26.10 | | | $ | 6.72 | | | $ | 21.50 | | | $ | 5.04 | | Refining margin per total throughput barrel | $ | 16.56 | | | $ | 15.03 | | | $ | 19.82 | | | $ | 8.51 | |
Reconciliation of Petroleum Segment Refining Margin Adjusted for Inventory Valuation Impact per Total Throughput Barrel
| | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | Three Months Ended
September 30, | | Nine Months Ended
September 30, |
| (in millions, except per total throughput barrel) | (in millions, except per total throughput barrel) | 2022 | | 2021 | | 2022 | | 2021 | (in millions, except per total throughput barrel) | 2022 | | 2021 | | 2022 | | 2021 |
| Refining margin, adjusted for inventory valuation impact | Refining margin, adjusted for inventory valuation impact | $ | 441 | | | $ | 97 | | | $ | 605 | | | $ | 82 | | Refining margin, adjusted for inventory valuation impact | $ | 414 | | | $ | 284 | | | $ | 1,020 | | | $ | 366 | |
| Divided by: total throughput barrels | Divided by: total throughput barrels | 18 | | | 20 | | | 36 | | | 36 | | Divided by: total throughput barrels | 19 | | | 19 | | | 55 | | | 56 | |
| Refining margin adjusted for inventory valuation impact per total throughput barrel | Refining margin adjusted for inventory valuation impact per total throughput barrel | $ | 24.08 | | | $ | 4.92 | | | $ | 16.77 | | | $ | 2.25 | | Refining margin adjusted for inventory valuation impact per total throughput barrel | $ | 22.34 | | | $ | 14.62 | | | $ | 18.66 | | | $ | 6.55 | |
Reconciliation of Petroleum Segment Direct Operating Expenses per Total Throughput Barrel
| | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | Three Months Ended
September 30, | | Nine Months Ended
September 30, |
| (in millions, except per total throughput barrel) | (in millions, except per total throughput barrel) | 2022 | | 2021 | | 2022 | | 2021 | (in millions, except per total throughput barrel) | 2022 | | 2021 | | 2022 | | 2021 |
| Direct operating expenses (exclusive of depreciation and amortization) | Direct operating expenses (exclusive of depreciation and amortization) | $ | 112 | | | $ | 83 | | | $ | 211 | | | $ | 182 | | Direct operating expenses (exclusive of depreciation and amortization) | $ | 103 | | | $ | 88 | | | $ | 314 | | | $ | 270 | |
| Divided by: total throughput barrels | Divided by: total throughput barrels | 18 | | | 20 | | | 36 | | | 36 | | Divided by: total throughput barrels | 19 | | | 19 | | | 55 | | | 56 | |
| Direct operating expenses per total throughput barrel | Direct operating expenses per total throughput barrel | $ | 6.12 | | | $ | 4.23 | | | $ | 5.85 | | | $ | 4.99 | | Direct operating expenses per total throughput barrel | $ | 5.53 | | | $ | 4.52 | | | $ | 5.74 | | | $ | 4.83 | |
Reconciliation of Nitrogen Fertilizer Segment Net (Loss) Income (Loss) to EBITDA and Adjusted EBITDA
| | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | Three Months Ended
September 30, | | Nine Months Ended
September 30, |
| (in millions) | (in millions) | 2022 | | 2021 | | 2022 | | 2021 | (in millions) | 2022 | | 2021 | | 2022 | | 2021 |
| Nitrogen Fertilizer net income (loss) | $ | 118 | | | $ | 7 | | | $ | 211 | | | $ | (18) | | |
| Nitrogen Fertilizer net (loss) income | | Nitrogen Fertilizer net (loss) income | $ | (20) | | | $ | 35 | | | $ | 191 | | | $ | 17 | |
| Interest expense, net | Interest expense, net | 8 | | | 23 | | | 18 | | | 39 | | Interest expense, net | 8 | | | 11 | | | 26 | | | 51 | |
| | Depreciation and amortization | Depreciation and amortization | 21 | | | 21 | | | 42 | | | 35 | | Depreciation and amortization | 22 | | | 18 | | | 64 | | | 52 | |
| Nitrogen Fertilizer EBITDA and Adjusted EBITDA | Nitrogen Fertilizer EBITDA and Adjusted EBITDA | $ | 147 | | | $ | 51 | | | $ | 271 | | | $ | 56 | | Nitrogen Fertilizer EBITDA and Adjusted EBITDA | $ | 10 | | | $ | 64 | | | $ | 281 | | | $ | 120 | |
|
JuneSeptember 30, 2022 | 4748
Reconciliation of Total Debt and Net Debt and Finance Lease Obligations to EBITDA Exclusive of Nitrogen Fertilizer
| | | | | |
| |
| (in millions) | Twelve Months Ended JuneSeptember 30, 2022 |
Total debt and finance lease obligations (1) | $ | 1,5941,593 | |
| Less: | |
Nitrogen Fertilizer debt and finance lease obligations (1) | $ | 547 | |
| Total debt and finance lease obligations exclusive of Nitrogen Fertilizer | 1,0471,046 | |
| |
| EBITDA exclusive of Nitrogen Fertilizer | $ | 611603 | |
| |
| Total debt and finance lease obligations to EBITDA exclusive of Nitrogen Fertilizer | 1.711.73 | |
| |
| Consolidated cash and cash equivalents | $ | 893618 | |
| Less: | |
| Nitrogen Fertilizer cash and cash equivalents | 156119 | |
| Cash and cash equivalents exclusive of Nitrogen Fertilizer | 737499 | |
| |
Net debt and finance lease obligations exclusive of Nitrogen Fertilizer (2) | $ | 310547 | |
| |
Net debt and finance lease obligations to EBITDA exclusive of Nitrogen Fertilizer (2) | 0.510.91 | |
(1)Amounts are shown inclusive of the current portion of long-term debt and finance lease obligations.
(2)Net debt represents total debt and finance lease obligations exclusive of cash and cash equivalents.
| | | Three Months Ended | | Twelve Months Ended June 30, 2022 | | Three Months Ended | | Twelve Months Ended September 30, 2022 |
| (in millions) | (in millions) | | September 30, 2021 | | December 31, 2021 | | March 31, 2022 | | June 30, 2022 | | (in millions) | | December 31, 2021 | | March 31, 2022 | | June 30, 2022 | | September 30, 2022 | |
| Consolidated | Consolidated | | | | | | | | | | | Consolidated | | | | | | | | | | |
| Net income | Net income | | $ | 106 | | | $ | 25 | | | $ | 153 | | | $ | 239 | | | $ | 523 | | Net income | | $ | 25 | | | $ | 153 | | | $ | 239 | | | $ | 80 | | | $ | 497 | |
| Interest expense, net | Interest expense, net | | 23 | | | 24 | | | 24 | | | 23 | | | 94 | | Interest expense, net | | 24 | | | 24 | | | 23 | | | 19 | | | 90 | |
| Income tax expense (benefit) | | 47 | | | (7) | | | 34 | | | 66 | | | 140 | | |
| Income tax (benefit) expense | | Income tax (benefit) expense | | (7) | | | 34 | | | 66 | | | 7 | | | 100 | |
| Depreciation and amortization | Depreciation and amortization | | 67 | | | 74 | | | 67 | | | 73 | | | 281 | | Depreciation and amortization | | 74 | | | 67 | | | 73 | | | 75 | | | 289 | |
| EBITDA | EBITDA | | $ | 243 | | | $ | 116 | | | $ | 278 | | | $ | 401 | | | $ | 1,038 | | EBITDA | | $ | 116 | | | $ | 278 | | | $ | 401 | | | $ | 181 | | | $ | 976 | |
| | Nitrogen Fertilizer | Nitrogen Fertilizer | | Nitrogen Fertilizer | |
| Net income | | $ | 35 | | | $ | 61 | | | $ | 94 | | | $ | 118 | | | $ | 308 | | |
| Net income (loss) | | Net income (loss) | | $ | 61 | | | $ | 94 | | | $ | 118 | | | $ | (20) | | | $ | 253 | |
| Interest expense, net | Interest expense, net | | 11 | | | 11 | | | 10 | | | 8 | | | 40 | | Interest expense, net | | 11 | | | 10 | | | 8 | | | 8 | | | 37 | |
| | Depreciation and amortization | Depreciation and amortization | | 18 | | | 21 | | | 19 | | | 21 | | | 79 | | Depreciation and amortization | | 21 | | | 19 | | | 21 | | | 22 | | | 83 | |
| EBITDA | EBITDA | | $ | 64 | | | $ | 93 | | | $ | 123 | | | $ | 147 | | | $ | 427 | | EBITDA | | $ | 93 | | | $ | 123 | | | $ | 147 | | | $ | 10 | | | $ | 373 | |
| | EBITDA exclusive of Nitrogen Fertilizer | EBITDA exclusive of Nitrogen Fertilizer | | $ | 179 | | | $ | 23 | | | $ | 155 | | | $ | 254 | | | $ | 611 | | EBITDA exclusive of Nitrogen Fertilizer | | $ | 23 | | | $ | 155 | | | $ | 254 | | | $ | 171 | | | $ | 603 | |
Liquidity and Capital Resources
Our principal source of liquidity has historically been cash from operations. Our principal uses of cash are for working capital, capital expenditures, funding our debt service obligations, and paying dividends to our stockholders, as further discussed below.
JuneSeptember 30, 2022 | 4849
Following the significant declines in demand and pricing for crude oil and refined products in 2020 due to the COVID-19 pandemic, market conditions improved steadily throughout 2021 and into 2022, as mobility increased amid the spread of vaccinations and general easing of restrictions related to COVID-19. As refined product demand rebounded toward pre-COVID-19 levels, the permanent loss of refined product supply due to refinery closures in 2020 led to a tightening of supply of refined products that, in conjunction with the increase in demand, led to an increase in prices. In the first quarter of 2022, following the Russian invasion of Ukraine, crude oil and refined product prices increased further and have been volatile over concerns of a reduction in global supply of these products due to sanctions placed on Russian exports by the U.S. and numerous other countries. Despite the extreme volatility in commodity pricing, the increase in refined product pricing during 2021 and into 2022 has had a favorable impact on our business and has not significantly impacted our primary source of liquidity.
While we believe demand for crude oil and refined products has nearly returned to pre-COVID-19 levels and commodity prices have rebounded, there is still uncertainty on the horizon due to the potential for recession driven demand destruction and any potential resolution of the Russia-Ukraine conflict. We continue to maintain our focus on safe and reliable operations, maintain an appropriate level of cash to fund ongoing operations, and protect our balance sheet. As a result of these improving factors, the Board elected to declare a $0.40 quarterly cash dividend for the secondthird quarter of 2022 and a special cash dividend of $2.60.$1.00. This supports the Company’s continued focus on financial discipline through a balanced approach of evaluation of strategic investment opportunities and stockholder distributions while maintaining adequate capital requirements for ongoing operations throughout the uncertain environment. The Board will continue to evaluate the economic environment, the Company’s cash needs, optimal uses of cash, and other applicable factors, and may elect to make additional changes to the Company’s dividend (if any) in future periods. Additionally, in executing financial discipline, we have successfully implemented the following measures:
•Deferred the majority of our growth capital spending, with the exception of the RDU project and construction of the pre-treatment unit at the Wynnewood Refinery;
•Focused refining maintenance capital expenditures to only include those projects which are a priority to support continuing safe and reliable operations, or which we consider required to support future activities;
•Focused future capital allocation to high-return assets and opportunities that advance participation in the energy industry transformation;
•Continued to focus on disciplined management of operational and general and administrative cost reductions;
���•For the Petroleum Segment, deferred the Wynnewood Refinery turnaround from the spring of 2021 to the spring of 2022 and deferring the refinery in Coffeyville, Kansas (the “Coffeyville Refinery”) turnaround from fall of 2021 to spring of 2023; and
•For the Nitrogen Fertilizer Segment, took advantage of downtime to perform maintenance activities, which enabled us to defer the turnarounds at the Coffeyville and East Dubuque Fertilizer Facility turnaround from 2021Facilities to the summer of 2022.
When considering the market conditions and actions outlined above, we currently believe that our cash from operations and existing cash and cash equivalents, along with borrowings, as necessary, will be sufficient to satisfy anticipated cash requirements associated with our existing operations for at least the next 12 months. However, our future capital expenditures and other cash requirements could be higher than we currently expect as a result of various factors including, but not limited to, rising material and labor costs, the costs associated with complying with the Renewable Fuel Standard’s outcome of litigation and other factors. Additionally, our ability to generate sufficient cash from our operating activities and secure additional financing depends on our future operational performance, which is subject to general economic, political, financial, competitive, and other factors, some of which may be beyond our control.
Depending on the needs of our business, contractual limitations and market conditions, we may from time to time seek to issue equity securities, incur additional debt, issue debt securities, or redeem, repurchase, refinance, or retire our outstanding debt through privately negotiated transactions, open market repurchases, redemptions, exchanges, tender offers or otherwise, but we are under no obligation to do so. There can be no assurance that we will seek to do any of the foregoing or that we will be able to do any of the foregoing on terms acceptable to us or at all.
On February 22, 2022, CVR Partners redeemed the remaining $65 million in aggregate principal amount of its 2023 UAN Notes at par, plus accrued and unpaid interest. This transaction represents a significant and favorable change in CVR Partners’ cash flow and liquidity position, with annual savings of approximately $6 million in future interest expense. On June 30, 2022, CVR Refining and certain of its subsidiaries entered into Amendment No. 3 to the Amended and Restated ABL Credit
JuneSeptember 30, 2022 | 4950
Agreement, (as amended, the “Petroleum ABL”). The Petroleum ABL is a senior secured asset based revolving credit facility in an aggregate principal amount of up to $275 million and a maturity date of June 30, 2027. Refer to Part I, Item 1, Note 8 (“Long-Term Debt and Finance Lease Obligations”) of this Report for further discussion. The Company and its subsidiaries were in compliance with all covenants under their respective debt instruments as of JuneSeptember 30, 2022, as applicable.
We do not have any “off-balance sheet arrangements” as such term is defined within the rules and regulations of the SEC.
Cash Balances and Other Liquidity
As of JuneSeptember 30, 2022, we had total liquidity of approximately $1.2 billion,$900 million, which consisted of consolidated cash and cash equivalents of $893$618 million, $246$247 million available under the Petroleum ABL, and $35 million available under the Asset Based Credit Agreement (the “Nitrogen Fertilizer ABL”). As of December 31, 2021, we had $510 million in cash and cash equivalents.
| | (in millions) | (in millions) | June 30, 2022 | | December 31, 2021 | (in millions) | September 30, 2022 | | December 31, 2021 |
| CVR Partners: | CVR Partners: | | | | CVR Partners: | | | |
9.25% Senior Secured Notes, due June 2023 (1) | 9.25% Senior Secured Notes, due June 2023 (1) | $ | — | | | $ | 65 | | 9.25% Senior Secured Notes, due June 2023 (1) | $ | — | | | $ | 65 | |
| 6.125% Senior Secured Notes, due June 2028 | 6.125% Senior Secured Notes, due June 2028 | 550 | | | 550 | | 6.125% Senior Secured Notes, due June 2028 | 550 | | | 550 | |
| Unamortized discount and debt issuance costs | Unamortized discount and debt issuance costs | (3) | | | (4) | | Unamortized discount and debt issuance costs | (3) | | | (4) | |
| Total CVR Partners debt | Total CVR Partners debt | $ | 547 | | | $ | 611 | | Total CVR Partners debt | $ | 547 | | | $ | 611 | |
| | CVR Energy: | CVR Energy: | | CVR Energy: | |
| 5.25% Senior Notes, due February 2025 | 5.25% Senior Notes, due February 2025 | $ | 600 | | | $ | 600 | | 5.25% Senior Notes, due February 2025 | $ | 600 | | | $ | 600 | |
| 5.75% Senior Notes, due February 2028 | 5.75% Senior Notes, due February 2028 | 400 | | | 400 | | 5.75% Senior Notes, due February 2028 | 400 | | | 400 | |
| Unamortized debt issuance costs | Unamortized debt issuance costs | (4) | | | (5) | | Unamortized debt issuance costs | (4) | | | (5) | |
| Total CVR Energy debt | Total CVR Energy debt | $ | 996 | | | $ | 995 | | Total CVR Energy debt | $ | 996 | | | $ | 995 | |
| Total long-term debt | Total long-term debt | $ | 1,543 | | | $ | 1,606 | | Total long-term debt | $ | 1,543 | | | $ | 1,606 | |
|
(1)The $65 million outstanding balance of the 2023 UAN Notes was paid in full on February 22, 2022 at par, plus accrued and unpaid interest.
CVR Partners
As of JuneSeptember 30, 2022, the Nitrogen Fertilizer Segment has the 6.125% Senior Secured Notes, due June 2028 (the “2028 UAN Notes”) and the Nitrogen Fertilizer ABL, the proceeds of which may be used to fund working capital, capital expenditures, and for other general corporate purposes. Refer to Part I, Item 1, Note 8 (“Long-Term Debt and Finance Lease Obligations”) of this Report and Part II, Item 8, Note 6 (“Long-Term Debt”) of our 2021 Form 10-K for further discussion.
CVR Refining
On June 30, 2022, CVR Refining amended its Petroleum ABL which provides an aggregate principal amount of up to $275 million, the proceeds of which may be used to fund working capital, capital expenditures, and for other general corporate purposes. Refer to Part I, Item 1, Note 8 (“Long-Term Debt and Finance Lease Obligations”) of this Report and Part II, Item 8, Note 6 (“Long-Term Debt”) of our 2021 Form 10-K for further discussion.
CVR Energy
As of JuneSeptember 30, 2022, CVR Energy has the 5.25% Senior Notes, due 2025 (the “2025 Notes”) and the 5.75% Senior Notes, due 2028 (the “2028 Notes” and together with the 2025 Notes, the “Notes”), the net proceeds of which may be used for general corporate purposes, which may include funding acquisitions, capital projects, and/or share repurchases or other distributions to our stockholders. Refer to Part II, Item 8, Note 6 (“Long-Term Debt”) of our 2021 Form 10-K for further discussion.
JuneSeptember 30, 2022 | 5051
Capital Spending
We divide capital spending needs into two categories: maintenance and growth. Maintenance capital spending includes non-discretionary maintenance projects and projects required to comply with environmental, health, and safety regulations. Growth capital projects generally involve an expansion of existing capacity and/or a reduction in direct operating expenses. We undertake growth capital spending based on the expected return on incremental capital employed.
In December 2020, our Board approved the renewable diesel project at our Wynnewood Refinery, to convert the refinery’s hydrocracker to a RDU capable of producing approximately 100 million gallons of renewable diesel per year. The hydrocracker conversion to renewable diesel service was completed in April 2022, and we are continuing to increase production. In November 2021, the Board approved the pretreater project at the Wynnewood Refinery, which is expected to be completed in the secondthird quarter of 2023 at an estimated cost of $95 million.
Our total capital expenditures for the sixnine months ended JuneSeptember 30, 2022, along with our estimated expenditures for 2022, by segment, are as follows:
| | | Six Months Ended
June 30, 2022 Actual | | 2022 Estimate (1) | | Nine Months Ended
September 30, 2022 Actual | | 2022 Estimate (1) |
| | Maintenance | Growth | Total | | Maintenance | Growth | Total |
| (in millions) | (in millions) | Maintenance | Growth | Total | | Low | High | Low | High | Low | High | (in millions) | Maintenance | Growth | Total | | Low | High | Low | High | Low | High |
| Petroleum | Petroleum | $ | 37 | | $ | 1 | | $ | 38 | | | $ | 85 | | $ | 95 | | $ | 4 | | $ | 8 | | $ | 89 | | $ | 103 | | Petroleum | $ | 59 | | $ | 2 | | $ | 61 | | | $ | 81 | | $ | 91 | | $ | 3 | | $ | 7 | | $ | 84 | | $ | 98 | |
Renewables (2) | Renewables (2) | — | | 38 | | 38 | | | — | | — | | 56 | | 66 | | 56 | | 66 | | Renewables (2) | 1 | | 53 | | 54 | | | 1 | | 2 | | 67 | | 77 | | 68 | | 79 | |
| Nitrogen Fertilizer | Nitrogen Fertilizer | 13 | | 1 | | 14 | | | 43 | | 45 | | 1 | | 2 | | 44 | | 47 | | Nitrogen Fertilizer | 38 | | 1 | | 39 | | | 43 | | 45 | | 1 | | 2 | | 44 | | 47 | |
| Other | Other | 1 | | — | | 1 | | | 6 | | 8 | | — | | — | | 6 | | 8 | | Other | 5 | | — | | 5 | | | 8 | | 10 | | — | | — | | 8 | | 10 | |
| Total | Total | $ | 51 | | $ | 40 | | $ | 91 | | | $ | 134 | | $ | 148 | | $ | 61 | | $ | 76 | | $ | 195 | | $ | 224 | | Total | $ | 103 | | $ | 56 | | $ | 159 | | | $ | 133 | | $ | 148 | | $ | 71 | | $ | 86 | | $ | 204 | | $ | 234 | |
(1)Total 2022 estimated capitalized costs include approximately $1 million of growth related projects that will require additional approvals before commencement.
(2)Renewables reflects spending on the Wynnewood Refinery RDU project. Upon completion and meeting of certain criteria under accounting rules, Renewables is expected to be a new reportable segment. As of JuneSeptember 30, 2022, Renewables does not the meet the definition of a reportable segment as defined under Accounting Standards Codification 280.
Our estimated capital expenditures are subject to change due to unanticipated changes in the cost, scope, and completion time for capital projects. For example, we may experience unexpected changes in labor or equipment costs necessary to comply with government regulations or to complete projects that sustain or improve the profitability of the refineries or nitrogen fertilizer facilities. We may also accelerate or defer some capital expenditures from time to time. Capital spending for CVR Partners is determined by the board of directors of its general partner (the “UAN GP Board”). We will continue to monitor market conditions and make adjustments, if needed, to our current capital spending or turnaround plans.
The Petroleum Segment began a major scheduled turnaround at the Wynnewood Refinery in late February 2022 that was completed in early April 2022. TotalWe did not capitalize turnaround expenditures during the three months ended September 30, 2022 and capitalized expenditures of $68 million for the nine months ended September 30, 2022. For the three and sixnine months ended JuneSeptember 30, 2022 and 2021, were $4 million and $67 million, respectively, and less thanwe capitalized turnaround expenditures of $1 million and $1$2 million, respectively. The Petroleum Segment’s next planned turnaround at the Coffeyville Refinery is currently expected to start in the spring of 2023. For the three and sixnine months ended JuneSeptember 30, 2022, we capitalized $1$4 million and $2$5 million, respectively, related to the pre-planning activities.
The Nitrogen Fertilizer SegmentSegment’s planned turnaround at the Coffeyville Fertilizer Facility commenced in July 2022 and is expected to bewas completed in early to mid-August 2022, with an estimated cost of $12 to $15 million.2022. The next planned turnaround at the East Dubuque Fertilizer Facility is expected to commence duringcommenced in August 2022 with an estimated cost of $19 to $21 million.and was completed in mid-September 2022. For the three and sixnine months ended JuneSeptember 30, 2022, we incurred less than $1 million for both periods in turnaround expense related to planning for the Coffeyville Fertilizer Facility’s turnaround, and approximately $1$12 million in turnaround expense for both periods related to planning forthe Coffeyville Fertilizer Facility’s turnaround, and $20 million and $21 million, respectively, in turnaround expense related to the East Dubuque Fertilizer Facility’s expected turnaround. We will continue to monitor market conditions and make adjustments, if needed, to our current capital spending or turnaround plans.
Dividends to CVR Energy Stockholders
Dividends, if any, including the payment, amount and timing thereof, are determined in the discretion of our Board. IEP, through its ownership of the Company’s common stock, is entitled to receive dividends that are declared and paid by the
Company based on the number of shares held at each record date. The following table presents quarterly dividends, excluding any special dividends, paid to the Company’s stockholders, including IEP, during 2022 (amounts presented in table below may not add to totals presented due to rounding).
| | | | Dividends Paid (in millions) | | Quarterly Dividends Paid (in millions) |
| Related Period | Related Period | | Date Paid | | Dividend Per Share | | Stockholders | | IEP | | Total | Related Period | | Date Paid | | Quarterly Dividend
Per Share | | Public Stockholders | | IEP | | Total |
| 2022 - 1st Quarter | 2022 - 1st Quarter | | May 23, 2022 | | $ | 0.40 | | | $ | 12 | | | $ | 28 | | | $ | 40 | | 2022 - 1st Quarter | | May 23, 2022 | | $ | 0.40 | | | $ | 12 | | | $ | 28 | | | $ | 40 | |
| | 2022 - 2nd Quarter | | 2022 - 2nd Quarter | | August 22, 2022 | | 0.40 | | | 12 | | | 28 | | | 40 | |
| Total 2022 quarterly dividends | | Total 2022 quarterly dividends | | $ | 0.80 | | | $ | 23 | | | $ | 57 | | | $ | 80 | |
No quarterly dividends were paid during the first quarter of 2022 related to the fourth quarter of 2021, and there were no quarterly dividends declared or paid during 2021 related to the first, second, and third quarters of 2021 and fourth quarter of 2020.
On August 1, 2022, the Company also declared a special dividend of $2.60 per share, or $261 million, which was paid on August 22, 2022. Of this amount, IEP received $185 million due to its ownership interest in the Company’s shares.
On May 26, 2021, the Company announced a special dividend of approximately $492 million, or equivalent to $4.89 per share of the Company’s common stock, to be paid in a combination of cash (the “Cash Distribution”) and the common stock of Delek held by the Company (the “Stock Distribution”). On June 10, 2021, the Company distributed an aggregate amount of approximately $241 million, or $2.40 per share of the Company’s common stock, pursuant to the Cash Distribution, and approximately 10,539,880 shares of Delek common stock, which represented approximately 14.3% of the outstanding shares of Delek common stock, pursuant to the Stock Distribution. IEP received approximately 7,464,652 shares of common stock of Delek and $171 million in cash. The Stock Distribution was recorded as a reduction to equity through a derecognition of our investment in Delek, and the Company recognized a gain of $112 million from the initial investment in Delek through the date of the Stock Distribution.
For the secondthird quarter of 2022, the Company, upon approval by the Company’s Board of Directors on August 1,October 31, 2022, declared a cash dividend of $0.40 per share, or $40 million, which is payable August 22,November 21, 2022 to shareholders of record as of August 12,November 14, 2022. Of this amount, IEP will receive $28 million due to its ownership interest in the Company’s shares.
In addition, the Company, upon approval by the Board on August 1,October 31, 2022, declared a special dividend of $2.60$1.00 per share, or $261$101 million, which is payable August 22,November 21, 2022 to shareholders of record as of August 12,November 14, 2022. Of this amount, IEP will receive $185$71 million due to its ownership interest in the Company’s shares.
Distributions to CVR Partners’ Unitholders
Distributions, if any, including the payment, amount and timing thereof, are subject to change at the discretion of the UAN GP Board. The following table presents quarterly distributions paid by CVR Partners to its unitholders, including amounts received by the Company, during 2022 and 2021 (amounts presented in tables below may not add to totals presented due to rounding).
| | | | Distributions Paid (in millions) | | Quarterly Distributions Paid (in millions) |
| Related Period | Related Period | | Date Paid | | Distributions
Per Common Unit | | Public
Unitholders | | CVR Energy | | Total | Related Period | | Date Paid | | Quarterly Distributions
Per Common Unit | | Public
Unitholders | | CVR Energy | | Total |
| 2021 - 4th Quarter | 2021 - 4th Quarter | | March 14, 2022 | | $ | 5.24 | | | $ | 36 | | | $ | 20 | | | $ | 56 | | 2021 - 4th Quarter | | March 14, 2022 | | $ | 5.24 | | | $ | 36 | | | $ | 20 | | | $ | 56 | |
| 2022 - 1st Quarter | 2022 - 1st Quarter | | May 23, 2022 | | 2.26 | | | 15 | | | 9 | | | 24 | | 2022 - 1st Quarter | | May 23, 2022 | | 2.26 | | | 15 | | | 9 | | | 24 | |
| | Total 2022 distributions | | $ | 7.50 | | | $ | 51 | | | $ | 29 | | | $ | 80 | | |
| 2022 - 2nd Quarter | | 2022 - 2nd Quarter | | August 22, 2022 | | 10.05 | | | 67 | | | 39 | | | 106 | |
| Total 2022 quarterly distributions | | Total 2022 quarterly distributions | | $ | 17.55 | | | $ | 118 | | | $ | 68 | | | $ | 186 | |
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| | | | | | Distributions Paid (in millions) |
| Related Period | | Date Paid | | Distributions
Per Common Unit | | Public
Unitholders | | CVR Energy | | Total |
| 2021 - 2nd Quarter | | August 23, 2021 | | $ | 1.72 | | | $ | 11 | | | $ | 7 | | | $ | 18 | |
| 2021 - 3rd Quarter | | November 22, 2021 | | 2.93 | | | 20 | | | 11 | | | 31 | |
| Total 2021 distributions | | $ | 4.65 | | | $ | 31 | | | $ | 18 | | | $ | 50 | |
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| | | | | | | | | | |
| | | | | | Quarterly Distributions Paid (in millions) |
| Related Period | | Date Paid | | Quarterly Distributions
Per Common Unit | | Public
Unitholders | | CVR Energy | | Total |
| 2021 - 2nd Quarter | | August 23, 2021 | | $ | 1.72 | | | $ | 11 | | | $ | 7 | | | $ | 18 | |
| 2021 - 3rd Quarter | | November 22, 2021 | | 2.93 | | | 20 | | | 11 | | | 31 | |
| Total 2021 quarterly distributions | | $ | 4.65 | | | $ | 31 | | | $ | 18 | | | $ | 50 | |
There were no quarterly distributions declared or paid by CVR Partners related to the first quarter of 2021 and fourth quarter of 2020.
For the secondthird quarter of 2022, CVR Partners, upon approval by the UAN GP Board on August 1,October 31, 2022, declared a distribution of $10.05$1.77 per common unit, or $106$19 million, which is payable August 22,November 21, 2022 to unitholders of record as of
August 12, November 14, 2022. Of this amount, CVR Energy will receive approximately $39$7 million, with the remaining amount payable to public unitholders.
Capital Structure
On October 23, 2019, the Board authorized a stock repurchase program (the “Stock Repurchase Program”). The Stock Repurchase Program would enable the Company to repurchase up to $300 million of the Company’s common stock. Repurchases under the Stock Repurchase Program may be made from time-to-time through open market transactions, block trades, privately negotiated transactions or otherwise in accordance with applicable securities laws. The timing, price and amount of repurchases (if any) will be made at the discretion of management and are subject to market conditions as well as corporate, regulatory and other considerations. While the Stock Repurchase Program currently has a duration of four years, it does not obligate the Company to acquire any stock and may be terminated by the Board at any time. As of JuneSeptember 30, 2022, the Company has not repurchased any of the Company’s common stock under the Stock Repurchase Program.
On May 6, 2020, the UAN GP Board, on behalf of CVR Partners, authorized a unit repurchase program (the “Unit Repurchase Program”), which was increased on February 22, 2021. The Unit Repurchase Program, as increased, authorized CVR Partners to repurchase up to $20 million of the CVR Partners’sPartners’ common units. During the three months ended JuneSeptember 30, 2022 and 2021, CVR Partners did not repurchase any common units. During the sixnine months ended JuneSeptember 30, 2022 and 2021, CVR Partners repurchased 111,695 and 24,378 common units, respectively, on the open market in accordance with a repurchase agreement under Rules 10b5-1 and 10b-18 of the Securities Exchange Act of 1934, as amended, at a cost of $12 million and $1 million, respectively, exclusive of transaction costs, or an average price of $110.98 and $21.69 per common unit, respectively. As of JuneSeptember 30, 2022, CVR Partners, considering all repurchases made since inception of the Unit Repurchase Program, had a nominal amount in authority remaining under the Unit Repurchase Program. This Unit Repurchase Program does not obligate CVR Partners to repurchase any common units and may be cancelled or terminated by the UAN GP Board at any time.
Cash Flows
The following table sets forth our consolidated cash flows for the periods indicated below:
| | | Six Months Ended June 30, | | Nine Months Ended September 30, |
| (in millions) | (in millions) | 2022 | | 2021 | | Change | (in millions) | 2022 | | 2021 | | Change |
| Net cash provided by (used in): | Net cash provided by (used in): | | | | | | Net cash provided by (used in): | | | | | |
| Operating activities | Operating activities | $ | 712 | | | $ | 243 | | | $ | 469 | | Operating activities | $ | 868 | | | $ | 382 | | | $ | 486 | |
| Investing activities | Investing activities | (156) | | | (141) | | | (15) | | Investing activities | (217) | | | (204) | | | (13) | |
| Financing activities | Financing activities | (173) | | | (250) | | | 77 | | Financing activities | (543) | | | (279) | | | (264) | |
| Net increase (decrease) in cash, cash equivalents and restricted cash | Net increase (decrease) in cash, cash equivalents and restricted cash | $ | 383 | | | $ | (148) | | | $ | 531 | | Net increase (decrease) in cash, cash equivalents and restricted cash | $ | 108 | | | $ | (101) | | | $ | 209 | |
Operating Activities
The change in net cash provided by operating activities for the sixnine months ended JuneSeptember 30, 2022, as compared to the sixnine months ended JuneSeptember 30, 2021, was primarily due to a $577$515 million increase in EBITDA during 2022 as a result of stronger operations, an increase of $11 million from the non-cash change in the unrealized gain on derivatives, and a $16an increase of $18 million increase in non-cash share based compensation which is due to higher market prices for CVR Partners’ units and CVR Energy’s shares in 2022 compared to 2021. This is partially offset by a decrease in working capital of $166$52 million primarily associated with the increases in our open RFS position.inventory.
Investing Activities
The change in net cash used in investing activities for the sixnine months ended JuneSeptember 30, 2022, as compared to the sixnine months ended JuneSeptember 30, 2021, was primarily due to an increase in our turnaround expenditures of $66$71 million in 2022 compared to 2021 related to the planned turnaround at the Wynnewood Refinery completed in 2022 and a reduction in the proceeds from the sale of assets of $6$7 million. These are partially offset by a reduction in capital expenditures of $38$43 million, as the Wynnewood RDU was completed in April 2022, and a $20 million acquisition of pipeline assets in 2021 with no corresponding asset purchases in 2022.
Financing Activities
The change in net cash used for financing activities for the sixnine months ended JuneSeptember 30, 2022, as compared to the net cash provided in financing activities for the sixnine months ended JuneSeptember 30, 2021, was primarily due to a reduction of $201 millionan increase in dividends paid to CVR Partners non-controlling interest holders and CVR Energy stockholders of $107 million and $101 million, respectively, during 2022 compared to 2021. This is partially offset by2021, a change of $63$48 million in the redemption of the remaining balance of the 2023 UAN Notes in 2022 compared to the partial redemption of the 2023 UAN Notes and the 6.5% UAN Notes due April 2021 in 2021, a distribution of $51 million paid by CVR Partners during 2022 with no distributions in 2021, and an increase of $11 million increase in unit repurchases of CVR Partners’ common unit in 2022 compared to 2021. Additionally, in June 2021, CVR Partners completed a private offering of $550 million aggregate principal amount of the 2028 UAN Notes and used the proceeds, plus cash on hand, to redeem a portion of the 2023 UAN Notes.
Critical Accounting Estimates
Our critical accounting estimates are disclosed in the “Critical Accounting Estimates” section of our 2021 Form 10-K. No modifications have been made during the three and sixnine months ended JuneSeptember 30, 2022 to these estimates.
Item 3. Quantitative and Qualitative Disclosures About Market Risk
There have been no material changes to our market risks as of and for the three and sixnine months ended JuneSeptember 30, 2022, as compared to the risks discussed in Part II, Item 7A of our 2021 Form 10-K.
Item 4. Controls and Procedures
Evaluation of Disclosure Controls and Procedures
The Company has evaluated, under the direction and with the participation of the Chief Executive Officer and Chief Financial Officer, the effectiveness of our disclosure controls and procedures, as defined in Exchange Act Rule 13a-15(e) and 15d-15(e). Based upon this evaluation, the Company’s Chief Executive Officer and Chief Financial Officer concluded that disclosure controls and procedures were effective as of JuneSeptember 30, 2022.
Changes in Internal Control Over Financial Reporting
There have been no material changes in our internal controls over financial reporting required by Rule 13a-15 of the Exchange Act that occurred during the fiscal quarter ended JuneSeptember 30, 2022 that materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.
JuneSeptember 30, 2022 | 5455
PART II. OTHER INFORMATION
Item 1. Legal Proceedings
See Note 12 (“Commitments and Contingencies”) to Part I, Item 1 of this Report, which is incorporated by reference into this Part II, Item 1, for a description of certain litigation, legal, and administrative proceedings and environmental matters.
Item 1A. Risk Factors
There have been no material changes from the risk factors previously disclosed in Part I, Item 1A of our 2021 Form 10-K, which risk factors could be affected by the potential effects of the Russia-Ukraine conflict. Additional risks and uncertainties, including risks and uncertainties not presently known to us, or that we currently deem immaterial, could also have an adverse effect on our business, financial condition, and/or results of operations.
Item 5. Other Information
None.
Item 6. Exhibits | | | | | | | | |
| INDEX TO EXHIBITS |
| Exhibit Number | | Exhibit Description |
| 4.1** | | Supplemental Indenture, dated as of April 12, 2022, among CVR Renewables, LLC, CVR Energy, Inc., the existing guarantors named therein and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.1 to the Company’s Form 10-Q filed on May 3, 2022). |
4.2** | | |
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10.1**Õ
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10.2** | | |
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10.3*10.1** | | |
10.4** | | |
10.5* | | |
10.6*10.2**Õ
| | |
| 31.1* | | |
| 31.2* | | |
| 31.3* | | |
| 32.1† | | |
| | | | | | | | |
| 101* | | The following financial information for CVR Energy, Inc.’s Quarterly Report on Form 10-Q for the quarter ended JuneSeptember 30, 2022 formatted Inline XBRL (“Extensible Business Reporting Language”) includes: (i) Condensed Consolidated Balance Sheets (unaudited), (ii) Condensed Consolidated Statements of Operations (unaudited), (iii) Condensed Consolidated Statements of Comprehensive Income (unaudited), (iv) Condensed Consolidated Statement of Changes in Equity (unaudited), (v) Condensed Consolidated Statements of Cash Flows (unaudited) and (vi) the Notes to Condensed Consolidated Financial Statements (unaudited), tagged in detail. |
| 104* | | Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101). |
* Filed herewith.
** Previously filed.
† Furnished herewith.
+ Denotes management contract or compensatory plan or arrangement.
Õ The exhibits and schedules have been omitted pursuant to Item 601(a)(5) of Regulation S-K and will be provided to the Securities and Exchange Commission upon request.
PLEASE NOTE: Pursuant to the rules and regulations of the SEC, we may file or incorporate by reference agreements as exhibits to the reports that we file with or furnish to the SEC. The agreements are filed to provide investors with information
regarding their respective terms. The agreements are not intended to provide any other factual information about the Company, its business or operations. In particular, the assertions embodied in any representations, warranties and covenants contained in the agreements may be subject to qualifications with respect to knowledge and materiality different from those applicable to investors and may be qualified by information in confidential disclosure schedules not included with the exhibits. These disclosure schedules may contain information that modifies, qualifies and creates exceptions to the representations, warranties and covenants set forth in the agreements. Moreover, certain representations, warranties and covenants in the agreements may have been used for the purpose of allocating risk between the parties, rather than establishing matters as facts. In addition, information concerning the subject matter of the representations, warranties and covenants may have changed after the date of the respective agreement, which subsequent information may or may not be fully reflected in the Company’s public disclosures. Accordingly, investors should not rely on the representations, warranties and covenants in the agreements as characterizations of the actual state of facts about the Company, its business or operations on the date hereof.
JuneSeptember 30, 2022 | 5657
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.
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| | CVR Energy, Inc. |
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August 2,November 1, 2022 | | By: | /s/ Dane J. Neumann |
| | | Executive Vice President, Chief Financial
Officer, Treasurer and Assistant Secretary |
| | | (Principal Financial Officer) |
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August 2,November 1, 2022 | | By: | /s/ Jeffrey D. Conaway |
| | | Vice President, Chief Accounting Officer
and Corporate Controller |
| | | (Principal Accounting Officer) |
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JuneSeptember 30, 2022 | 5758
