UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
___________________________________
FORM 8-K
CURRENT REPORT
Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
___________________________________
Date of Report (Date of earliest event reported): July 24, 2019
CVR ENERGY, INC.
(Exact name of registrant as specified in its charter)
Delaware (State or other jurisdiction of incorporation) | 001-33492 (Commission File Number) | 61-1512186 (I.R.S. Employer Identification Number) |
2277 Plaza Drive, Suite 500 Sugar Land, Texas 77479 (Address of principal executive offices, including zip code) | ||
Registrant’s telephone number, including area code: (281) 207-3200
Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:
o Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)
o Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)
o Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))
o Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))
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 is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter).
Emerging growth company o
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. o
Item 2.02. Results of Operations and Financial Condition.
On July 24, 2019, CVR Energy, Inc. (the “Company”) issued a press release announcing information regarding its results of operations and financial condition for the three months ended June 30, 2019, which is attached hereto as Exhibit 99.1 and is incorporated herein by reference.
The information in Items 2.02 and 7.01 of this Current Report on Form 8-K (“Current Report”) and Exhibit 99.1 attached hereto is being “furnished” and shall not be deemed “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), or otherwise subject to the liabilities of that Section, nor shall it be deemed incorporated by reference into any filing under the Securities Act of 1933, as amended, or the Exchange Act, unless specifically identified therein as being incorporated by reference. The furnishing of information in this Current Report (including Exhibit 99.1) is not intended to, and does not, constitute a determination or admission by the Company that the information in this Current Report is material or complete, or that investors should consider this information before making an investment decision with respect to any securities of the Company or its affiliates.
Item 7.01. Regulation FD Disclosure.
The information set forth under Item 2.02 is incorporated by reference as if fully set forth herein.
Item 9.01. Financial Statements and Exhibits
(d) Exhibits
The following exhibit is being “furnished” as part of this Current Report on Form 8-K:
Exhibit Number | Exhibit Description |
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 hereunto duly authorized.
Date: July 24, 2019
CVR Energy, Inc. | |
By: | /s/ Tracy D. Jackson |
Tracy D. Jackson | |
Executive Vice President and Chief Financial Officer | |
Exhibit 99.1
CVR Energy Reports Second Quarter 2019 Results
and Announces Cash Dividend of 75 Cents
SUGAR LAND, Texas (July 24, 2019) – CVR Energy, Inc. (NYSE: CVI) today announced net income of $116 million, or $1.16 per diluted share, on net sales of $1,687 million for the second quarter of 2019, compared to net income of $43 million, or 50 cents per diluted share, on net sales of $1,914 million for the second quarter of 2018. Second quarter 2019 EBITDA was $273 million, compared to second quarter 2018 EBITDA of $180 million.
“CVR Energy delivered strong results for the second quarter 2019, primarily attributable to safe and reliable operations, lower Renewable Identification Number prices, higher crack spreads and increased fertilizer sales volumes and pricing,” said Dave Lamp, CVR Energy’s Chief Executive Officer. “In addition, in May we announced that our subsidiary had successfully sold its 1.5 million barrel Cushing, Oklahoma, crude oil terminal and related assets, resulting in an asset sale gain.
“During the 2019 second quarter, CVR Partners continued to be impacted by wet weather across the Midwest. However, it experienced solid demand for nitrogen fertilizer during the quarter and was able to deliver significant volumes of products to customers at netback prices much higher than the same period last year,” Lamp said. “CVR Partners’ plants ran well during the quarter, with ammonia utilization rates of 97 percent at Coffeyville and 98 percent at East Dubuque. CVR Partners also created positive distributable cash and declared a second quarter distribution of 14 cents per unit.”
Petroleum
The petroleum segment reported second quarter 2019 operating income of $163 million on net sales of $1,552 million, compared to operating income of $113 million on net sales of $1,824 million in the second quarter of 2018.
Refining margin per total throughput barrel was $15.66 in the second quarter of 2019, compared to $14.13 during the same period in 2018. Crude oil pricing during the quarter led to an inventory valuation impact of less than $1 million, or 2 cents per total throughout barrel, compared to $22 million, or $1.10 per total throughput barrel, in the second quarter of 2018. The petroleum segment also recognized a second quarter 2019 derivative gain of $4 million, or 22 cents per total throughput barrel, compared to a gain of $10 million, or 51 cents per total throughput barrel, for the prior year period. Included in the total derivative gain for the second quarter of 2019 was an unrealized gain of $2 million, compared to an unrealized loss of $7 million a year earlier.
Second quarter 2019 combined total throughput was approximately 216,000 barrels per day (bpd), compared to approximately 218,000 bpd of combined total throughput for the second quarter of 2018.
Fertilizer
The nitrogen fertilizer segment reported operating income of $35 million on net sales of $138 million for the second quarter of 2019, compared to an operating loss of less than $1 million on net sales of $93 million for the second quarter of 2018.
For the second quarter of 2019, CVR Partners’ consolidated average realized gate prices for urea ammonia nitrate (UAN) improved significantly over the prior year, up 14 percent to $217 per ton, while ammonia was up 31 percent over the prior year to $456 per ton. Average realized gate prices for UAN and ammonia were $191 per ton and $348 per ton, respectively, for the second quarter of 2018.
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CVR Partners’ fertilizer facilities produced a combined 211,000 tons of ammonia during the second quarter 2019, of which 71,000 net tons were available for sale while the rest was upgraded to other fertilizer products, including 316,000 tons of UAN. During the second quarter 2018, the fertilizer facilities produced 174,000 tons of ammonia, of which 65,000 net tons were available for sale while the remainder was upgraded to other fertilizer products, including 241,000 tons of UAN.
Cash, Debt and Dividend
Consolidated cash and cash equivalents was $540 million at June 30, 2019. Consolidated total debt and finance lease obligations was $1,195 million at June 30, 2019, with no debt other than the Company’s segments’ debt.
CVR Energy also announced a second quarter 2019 cash dividend of 75 cents per share. The dividend, as declared by CVR Energy’s Board of Directors, will be paid on Aug 12, 2019, to stockholders of record as of the close of market on Aug 5, 2019. The annualized dividend of $3 per share represents an industry leading dividend yield of 6 percent based on the July 23, 2019, closing stock price.
Today, CVR Partners announced that the Board of Directors of its general partner declared a second quarter 2019 cash distribution of 14 cents per common unit, which will be paid on Aug 12, 2019, to common unitholders of record as of the close of market on Aug 5, 2019.
Second Quarter 2019 Earnings Conference Call
CVR Energy previously announced that it will host its second quarter 2019 Earnings Conference Call on Thursday, July 25, at 1 p.m. Eastern. The Earnings Conference Call may also include discussion of Company developments, forward-looking information and other material information about business and financial matters.
The second quarter 2019 Earnings Conference Call will be webcast live and can be accessed on the Investor Relations section of CVR Energy’s website at www.CVREnergy.com. For investors or analysts who want to participate during the call, the dial-in number is (877) 407-8291. The webcast will be archived and available for 14 days at https://edge.media-server.com/mmc/p/u8jjdt8s. A repeat of the call also can be accessed for 14 days by dialing (877) 660-6853, conference ID 13692311.
Forward-Looking Statements
This news release may contain forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Statements concerning current estimates, expectations and projections about future results, performance, prospects, opportunities, plans, actions and events and other statements, concerns, or matters that are not historical facts are “forward-looking statements,” as that term is defined under the federal securities laws. These forward-looking statements include, but are not limited to, statements regarding future: dividends and distributions including the amount and timing thereof; refinery throughput, direct operating expenses, capital spending, depreciation and amortization and turnaround expense; continued safe and reliable operations; and other matters. You can generally identify forward-looking statements by our use of forward-looking terminology such as “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “explore,” “evaluate,” “intend,” “may,” “might,” “plan,” “potential,” “predict,” “seek,” “should,” or “will,” or the negative thereof or other variations thereon or comparable terminology. These forward-looking statements are only predictions and involve known and unknown risks and uncertainties, many of which are beyond our control. Investors are cautioned that various factors may affect these forward-looking statements, including (among others) price volatility of crude oil, other feedstocks and refined products; the ability of CVR Refining and CVR Partners to make cash distributions; potential operating hazards; costs of compliance with existing, or compliance with new, laws and regulations and potential liabilities arising therefrom; impacts of planting season on CVR Partners; general economic and business conditions; and other risks. For additional discussion of risk factors which may affect our results, please see the risk factors and other disclosures included in our most recent Annual Report on Form 10-K, any subsequently filed Quarterly Reports on Form 10-Q and our other SEC filings. These and other risks may cause our actual results, performance or achievements to differ materially from any future results, performance or achievements expressed or implied by these forward-looking statements. Given these risks and uncertainties, you are cautioned not to place undue reliance on such forward-looking statements. The forward-looking statements included in this news release are made only as of the date hereof. CVR Energy disclaims any intention or obligation to update publicly or revise any forward-looking statements, whether as a result of new information, future events or otherwise, except to the extent required by law.
About CVR Energy, Inc.
Headquartered in Sugar Land, Texas, CVR Energy is a diversified holding company primarily engaged in the petroleum refining and marketing business through its interest in CVR Refining and the nitrogen fertilizer manufacturing business through
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its interest in CVR Partners, LP. CVR Energy subsidiaries serve as the general partner and own 34 percent of the common units of CVR Partners.
For further information, please contact:
Investor Contact:
Richard Roberts
CVR Energy, Inc.
(281) 207-3205
InvestorRelations@CVREnergy.com
Media Relations:
Brandee Stephens
CVR Energy, Inc.
(281) 207-3516
MediaRelations@CVREnergy.com
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Non-GAAP Measures
Our management uses certain non-GAAP performance measures to evaluate current and past performance and prospects for the future to supplement our GAAP financial information presented in accordance with U.S. 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.
Effective January 1, 2019, the Company revised its accounting policy method for the costs of planned major maintenance activities (turnarounds) specific to the Petroleum Segment from being expensed as incurred (the direct expensing method) to the deferral method. See Note 3 (“Recent Accounting Pronouncements and Accounting Changes”) in the notes to our condensed consolidated quarterly financial statements for a further discussion of the impacts of this change in accounting policy. As a result of this change in accounting policy, the non-GAAP measures of Adjusted EBITDA, Petroleum Adjusted EBITDA, Nitrogen Fertilizer Adjusted EBITDA, Adjusted Net Income (Loss) and Direct Operating Expenses per Total Throughput Barrel net of Turnaround Expense are no longer being presented.
The following are non-GAAP measures that continue to be presented for the period ended June 30, 2019:
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 Impact - Refining Margin adjusted to exclude the impact of current period market price and volume fluctuations on crude oil and refined product inventories recognized in prior periods. 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. The inventory valuation impact is calculated based upon inventory values at the beginning of the accounting period and at the end of the accounting period.
Refining Margin and Refining Margin adjusted for Inventory Valuation Impact, per Throughput Barrel - Refining Margin adjusted to exclude the impact of current period market price and volume fluctuations on crude oil and refined product inventories recognized in prior periods, 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.
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 industry, 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” section 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.
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CVR Energy, Inc.
(all information in this release is unaudited)
Financial and Operational Data
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
(in millions, except share data) | 2019 | 2018 | 2019 | 2018 | |||||||||||
Consolidated Statement of Operations Data | |||||||||||||||
Net sales | $ | 1,687 | $ | 1,914 | $ | 3,173 | $ | 3,451 | |||||||
Operating costs and expenses: | |||||||||||||||
Cost of materials and other | 1,267 | 1,560 | 2,368 | 2,739 | |||||||||||
Direct operating expenses (exclusive of depreciation and amortization as reflected below) | 132 | 140 | 258 | 271 | |||||||||||
Depreciation and amortization | 76 | 68 | 141 | 131 | |||||||||||
Cost of sales | 1,475 | 1,768 | 2,767 | 3,141 | |||||||||||
Selling, general and administrative expenses (exclusive of depreciation and amortization as reflected below) | 27 | 31 | 57 | 55 | |||||||||||
Depreciation and amortization | 2 | 3 | 4 | 6 | |||||||||||
(Gain) loss on asset disposals | (9 | ) | 5 | (7 | ) | 5 | |||||||||
Operating income | 192 | 107 | 352 | 244 | |||||||||||
Other (expense) income: | |||||||||||||||
Interest expense, net | (26 | ) | (26 | ) | (52 | ) | (53 | ) | |||||||
Other income, net | 3 | 2 | 6 | 3 | |||||||||||
Income before income tax expense | 169 | 83 | 306 | 194 | |||||||||||
Income tax expense | 41 | 15 | 76 | 33 | |||||||||||
Net income | 128 | 68 | 230 | 161 | |||||||||||
Less: Net income attributable to noncontrolling interest | 12 | 25 | 13 | 58 | |||||||||||
Net income attributable to CVR Energy stockholders | $ | 116 | $ | 43 | $ | 217 | $ | 103 | |||||||
Basic and diluted earnings per share | $ | 1.16 | $ | 0.50 | $ | 2.16 | $ | 1.19 | |||||||
Dividends declared per share | $ | 0.75 | $ | 0.75 | $ | 1.50 | $ | 1.25 | |||||||
EBITDA* | $ | 273 | $ | 180 | $ | 503 | $ | 384 | |||||||
Weighted-average common shares outstanding - basic and diluted | 100.5 | 86.8 | 100.5 | 86.8 | |||||||||||
* See “Non-GAAP Reconciliations” section below.
Selected Balance Sheet Data
(in millions) | June 30, 2019 | December 31, 2018 | |||||
Cash and cash equivalents | $ | 540 | $ | 668 | |||
Working capital | 675 | 797 | |||||
Total assets | 3,830 | 4,000 | |||||
Total debt and finance lease obligations | 1,195 | 1,170 | |||||
Total liabilities | 2,124 | 2,057 | |||||
Total CVR stockholders’ equity | 1,384 | 1,286 | |||||
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Selected Cash Flow Data
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
(in millions) | 2019 | 2018 | 2019 | 2018 | |||||||||||
Net cash flow provided by (used in): | |||||||||||||||
Operating activities | $ | 156 | $ | 212 | $ | 384 | $ | 238 | |||||||
Investing activities | (1 | ) | (29 | ) | (43 | ) | (50 | ) | |||||||
Financing activities | (82 | ) | (69 | ) | (469 | ) | (136 | ) | |||||||
Net increase (decrease) in cash and cash equivalents | $ | 73 | $ | 114 | $ | (128 | ) | $ | 52 | ||||||
Selected Segment Data
(in millions) | Petroleum | Nitrogen Fertilizer | Consolidated | ||||||||
Three Months Ended June 30, 2019 | |||||||||||
Net sales | $ | 1,552 | $ | 138 | $ | 1,687 | |||||
Operating income | 163 | 35 | 192 | ||||||||
Net income | 158 | 19 | 128 | ||||||||
EBITDA* | 216 | 60 | 273 | ||||||||
Capital expenditures (1) | |||||||||||
Maintenance capital expenditures | $ | 15 | $ | 2 | $ | 20 | |||||
Growth capital expenditures | 2 | — | 2 | ||||||||
Total capital expenditures | $ | 17 | $ | 2 | $ | 22 | |||||
Six Months Ended June 30, 2019 | |||||||||||
Net sales | $ | 2,949 | $ | 230 | $ | 3,173 | |||||
Operating income | 319 | 44 | 352 | ||||||||
Net income | 307 | 13 | 230 | ||||||||
EBITDA* | 425 | 86 | 503 | ||||||||
Capital expenditures (1) | |||||||||||
Maintenance capital expenditures | $ | 34 | $ | 5 | $ | 42 | |||||
Growth capital expenditures | 4 | — | 4 | ||||||||
Total capital expenditures | $ | 38 | $ | 5 | $ | 46 | |||||
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(in millions) | Petroleum | Nitrogen Fertilizer | Consolidated | ||||||||
Three Months Ended June 30, 2018 | |||||||||||
Net sales | $ | 1,824 | $ | 93 | $ | 1,914 | |||||
Operating income | 113 | — | 107 | ||||||||
Net income (loss) | 104 | (16 | ) | 68 | |||||||
EBITDA* | 164 | 20 | 180 | ||||||||
Capital expenditures (1) | |||||||||||
Maintenance capital expenditures | $ | 11 | $ | 5 | $ | 17 | |||||
Growth capital expenditures | 4 | 2 | 6 | ||||||||
Total capital expenditures | $ | 15 | $ | 7 | $ | 23 | |||||
Six months ended June 30, 2018 | |||||||||||
Net sales | $ | 3,282 | $ | 173 | $ | 3,451 | |||||
Operating income (loss) | 256 | (4 | ) | 244 | |||||||
Net income (loss) | 237 | (36 | ) | 161 | |||||||
EBITDA* | 356 | 33 | 384 | ||||||||
Capital expenditures (1) | |||||||||||
Maintenance capital expenditures | $ | 21 | $ | 9 | $ | 32 | |||||
Growth capital expenditures | 8 | 2 | 10 | ||||||||
Total capital expenditures | $ | 29 | $ | 11 | $ | 42 | |||||
* See “Non-GAAP Reconciliations” section below.
(1) | Capital expenditures are shown exclusive of turnaround costs. |
Selected Balance Sheet Data
(in millions) | Petroleum | Nitrogen Fertilizer | Consolidated | ||||||||
June 30, 2019 | |||||||||||
Cash and cash equivalents | $ | 419 | $ | 69 | $ | 540 | |||||
Total assets | 2,833 | 1,190 | 3,830 | ||||||||
Total debt and finance lease obligations | 564 | 631 | 1,195 | ||||||||
December 31, 2018 | |||||||||||
Cash and cash equivalents | $ | 353 | $ | 62 | $ | 668 | |||||
Total assets | 2,453 | 1,254 | 4,000 | ||||||||
Total debt and finance lease obligations | 541 | 629 | 1,170 | ||||||||
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Petroleum Segment
Key Operating Metrics per Total Throughput Barrel
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
2019 | 2018 | 2019 | 2018 | ||||||||||||
Refining margin* | $ | 15.66 | $ | 14.13 | $ | 16.10 | $ | 15.72 | |||||||
Refining margin adjusted for inventory valuation impact * | 15.68 | 13.03 | 15.28 | 14.58 | |||||||||||
Direct operating expenses * | 4.40 | 4.68 | 4.57 | 5.00 | |||||||||||
* See “Non-GAAP Reconciliations” section below.
Throughput Data by Refinery
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||
(in bpd) | 2019 | 2018 | 2019 | 2018 | |||||||
Coffeyville | |||||||||||
Regional crude | 49,979 | 28,538 | 45,808 | 29,116 | |||||||
WTI | 75,090 | 75,595 | 71,075 | 63,280 | |||||||
Midland WTI | 863 | 16,842 | 6,750 | 8,467 | |||||||
Condensate | 3,125 | 1,547 | 4,203 | 9,586 | |||||||
Heavy Canadian | 3,511 | 6,249 | 5,526 | 3,385 | |||||||
Other feedstocks and blendstocks | 8,083 | 7,543 | 8,685 | 6,843 | |||||||
Wynnewood | |||||||||||
Regional crude | 52,359 | 56,773 | 48,383 | 52,669 | |||||||
WTI | — | 2,108 | — | 4,514 | |||||||
Midland WTI | 13,410 | 10,739 | 12,961 | 14,922 | |||||||
Condensate | 7,038 | 7,580 | 7,394 | 5,974 | |||||||
Other feedstocks and blendstocks | 2,825 | 4,591 | 3,770 | 5,174 | |||||||
Total throughput | 216,283 | 218,105 | 214,555 | 203,930 | |||||||
Production Data by Refinery
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||
(in bpd) | 2019 | 2018 | 2019 | 2018 | |||||||
Coffeyville | |||||||||||
Gasoline | 70,506 | 67,390 | 72,170 | 58,357 | |||||||
Distillate | 59,049 | 59,855 | 59,288 | 52,093 | |||||||
Other liquid products | 6,786 | 5,231 | 6,631 | 6,900 | |||||||
Solids | 5,113 | 5,267 | 5,042 | 4,758 | |||||||
Wynnewood | |||||||||||
Gasoline | 39,153 | 39,853 | 36,746 | 41,714 | |||||||
Distillate | 31,997 | 34,985 | 29,689 | 34,804 | |||||||
Other liquid products | 1,360 | 5,060 | 3,728 | 4,787 | |||||||
Solids | 33 | 49 | 31 | 51 | |||||||
Total production | 213,997 | 217,690 | 213,325 | 203,464 | |||||||
Liquid volume yield (as % of total throughput) | 96.6 | % | 97.4 | % | 97.1 | % | 97.4 | % | |||
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Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
2019 | 2018 | 2019 | 2018 | ||||||||||||
Market Indicators (dollars per barrel) | |||||||||||||||
West Texas Intermediate (WTI) NYMEX | $ | 59.91 | $ | 67.91 | $ | 57.44 | $ | 65.46 | |||||||
Crude Oil Differentials: | |||||||||||||||
WTI less WTS (light/medium sour) | — | 8.50 | — | 5.05 | |||||||||||
WTI less WCS (heavy sour) | 12.63 | 18.02 | 11.59 | 21.81 | |||||||||||
WTI less condensate | — | 0.46 | — | 0.42 | |||||||||||
Midland Cushing Differential | 2.27 | 8.12 | 1.74 | 4.34 | |||||||||||
NYMEX Crack Spreads: | |||||||||||||||
Gasoline | 21.37 | 20.63 | 16.64 | 18.06 | |||||||||||
Heating Oil | 23.46 | 22.22 | 24.90 | 21.36 | |||||||||||
NYMEX 2-1-1 Crack Spread | 22.41 | 21.43 | 20.77 | 19.71 | |||||||||||
PADD II Group 3 Basis: | |||||||||||||||
Gasoline | (2.56 | ) | (4.44 | ) | (2.31 | ) | (3.19 | ) | |||||||
Ultra Low Sulfur Diesel | (0.93 | ) | (0.05 | ) | (1.24 | ) | (0.33 | ) | |||||||
PADD II Group 3 Product Crack Spread: | |||||||||||||||
Gasoline | 18.81 | 16.19 | 14.33 | 14.87 | |||||||||||
Ultra Low Sulfur Diesel | 22.52 | 22.17 | 23.65 | 21.03 | |||||||||||
PADD II Group 3 2-1-1 | 20.67 | 19.18 | 18.99 | 17.95 | |||||||||||
Q3 2019 Petroleum Segment Outlook
The table below summarizes our outlook for certain refining statistics and financial information for the third quarter of 2019. See “forward looking statements.”
Q3 2019 | |||||||
Low | High | ||||||
Refinery Statistics: | |||||||
Total throughput (bpd) | 215,000 | 225,000 | |||||
Direct operating expenses (1) (in millions) | $ | 90 | $ | 100 | |||
Total capital spending (in millions) | $ | 40 | $ | 60 | |||
(1) | Direct operating expenses are shown exclusive of depreciation and amortization and turnaround expenses. |
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Nitrogen Fertilizer Segment:
Key Operating Data:
Ammonia Utilization Rates (1)
Two Years Ended June 30, | |||||
(percent of capacity utilization) | 2019 | 2018 | |||
Consolidated | 92 | % | 94 | % | |
Coffeyville | 94 | % | 93 | % | |
East Dubuque | 90 | % | 95 | % | |
(1) | Reflects ammonia utilization rates on a consolidated basis and at each of the Nitrogen Fertilizer facilities. Utilization is an important measure used by management to assess operational output at each of the facilities. Utilization is calculated as actual tons produced divided by capacity. The Nitrogen Fertilizer Segment presents utilization on a two-year rolling average to take into account the impact of current turnaround cycles on any specific period. The two-year rolling average is a more useful presentation of the long-term utilization performance of our plants. Additionally, we present utilization solely on ammonia production rather than each nitrogen product as it provides a comparative baseline against industry peers and eliminates the disparity of plant configurations for upgrade of ammonia into other nitrogen products. With the Nitrogen Fertilizer Segments’ efforts being primarily focused on ammonia upgrade capabilities, this measure provides a meaningful view of how well the facilities operate. |
Sales and Production Data
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
2019 | 2018 | 2019 | 2018 | ||||||||||||
Consolidated sales (thousand tons): | |||||||||||||||
Ammonia | 110 | 82 | 146 | 118 | |||||||||||
UAN | 340 | 270 | 628 | 615 | |||||||||||
Consolidated product pricing at gate (dollars per ton): | |||||||||||||||
Ammonia | $ | 456 | $ | 348 | $ | 434 | $ | 340 | |||||||
UAN | $ | 217 | $ | 191 | $ | 219 | $ | 169 | |||||||
Consolidated production volume (thousand tons): | |||||||||||||||
Ammonia (gross produced) | 211 | 174 | 390 | 373 | |||||||||||
Ammonia (net available for sale) | 71 | 65 | 112 | 124 | |||||||||||
UAN | 316 | 241 | 651 | 580 | |||||||||||
Feedstock: | |||||||||||||||
Petroleum coke used in production (thousand tons) | 134 | 90 | 266 | 208 | |||||||||||
Petroleum coke (dollars per ton) | $ | 34.60 | $ | 25.33 | $ | 36.14 | $ | 21.34 | |||||||
Natural gas used in production (thousands of MMBtu) (2) | 2,070 | 1,964 | 3,510 | 3,814 | |||||||||||
Natural gas used in production (dollars per MMBtu) (2) | $ | 2.61 | $ | 2.78 | $ | 3.11 | $ | 3.00 | |||||||
Natural gas in cost of materials and other (thousands of MMBtus) (2) | 3,185 | 2,571 | 4,193 | 3,829 | |||||||||||
Natural gas in cost of materials and other (dollars per MMBtu) (2) | $ | 3.32 | $ | 2.84 | $ | 3.45 | $ | 3.05 | |||||||
(2) | 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 expense (exclusive of depreciation and amortization). |
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Key Market Indicators
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
2019 | 2018 | 2019 | 2018 | ||||||||||||
Ammonia — Southern Plains (dollars per ton) | $ | 382 | $ | 343 | $ | 404 | $ | 362 | |||||||
Ammonia — Corn belt (dollars per ton) | 495 | 396 | 496 | 412 | |||||||||||
UAN — Corn belt (dollars per ton) | 226 | 211 | 228 | 211 | |||||||||||
Natural gas NYMEX (dollars per MMBtu) | $ | 2.51 | $ | 2.83 | $ | 2.69 | $ | 2.84 | |||||||
Non-GAAP Reconciliations:
Reconciliation of Net Income to EBITDA
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
(in millions) | 2019 | 2018 | 2019 | 2018 | |||||||||||
Net income | $ | 128 | $ | 68 | $ | 230 | $ | 161 | |||||||
Add: | |||||||||||||||
Interest expense, net | 26 | 26 | 52 | 53 | |||||||||||
Income tax expense | 41 | 15 | 76 | 33 | |||||||||||
Depreciation and amortization | 78 | 71 | 145 | 137 | |||||||||||
EBITDA | $ | 273 | $ | 180 | $ | 503 | $ | 384 | |||||||
Reconciliation of Petroleum Segment Net Income to EBITDA
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
(in millions) | 2019 | 2018 | 2019 | 2018 | |||||||||||
Petroleum net income | $ | 158 | $ | 104 | $ | 307 | $ | 237 | |||||||
Add: | |||||||||||||||
Interest expense, net | 6 | 11 | 17 | 22 | |||||||||||
Depreciation and amortization | 52 | 49 | 101 | 97 | |||||||||||
Petroleum EBITDA | $ | 216 | $ | 164 | $ | 425 | $ | 356 | |||||||
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Reconciliation of Petroleum Segment gross profit to Refining Margin and Refining Margin adjusted for inventory valuation impact (in millions and on per total throughput barrel basis) and Direct operating expenses per total throughput barrel
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
(in millions) | 2019 | 2018 | 2019 | 2018 | |||||||||||
Net sales | $ | 1,552 | $ | 1,824 | $ | 2,949 | $ | 3,282 | |||||||
Cost of materials and other | 1,244 | 1,543 | 2,324 | 2,701 | |||||||||||
Direct operating expenses (exclusive of depreciation and amortization as reflected below) | 86 | 93 | 177 | 185 | |||||||||||
Depreciation and amortization | 52 | 49 | 101 | 97 | |||||||||||
Gross profit | 170 | 139 | 347 | 299 | |||||||||||
Add: | |||||||||||||||
Direct operating expenses (exclusive of depreciation and amortization as reflected below) | 86 | 93 | 177 | 185 | |||||||||||
Depreciation and amortization | 52 | 49 | 101 | 97 | |||||||||||
Refining margin | 308 | 281 | 625 | 581 | |||||||||||
Inventory valuation impact, (favorable) unfavorable (1) | — | (22 | ) | (32 | ) | (42 | ) | ||||||||
Refining margin adjusted for inventory valuation impact | $ | 308 | $ | 259 | $ | 593 | $ | 539 | |||||||
(1) | FIFO is the petroleum business’ basis for determining inventory value under GAAP. 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 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, | ||||||||||
2019 | 2018 | 2019 | 2018 | ||||||||
Total throughput barrels per day | 216,283 | 218,105 | 214,555 | 203,930 | |||||||
Days in the period | 91 | 91 | 181 | 181 | |||||||
Total throughput barrels | 19,681,753 | 19,847,555 | 38,834,455 | 36,911,330 | |||||||
Reconciliation of Petroleum Segment Refining Margin (in millions and on per total throughput barrel basis)
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
(in millions, except for per throughput barrel data) | 2019 | 2018 | 2019 | 2018 | |||||||||||
Refining margin | $ | 308 | $ | 281 | $ | 625 | $ | 581 | |||||||
Divided by: total throughput barrels | 20 | 20 | 39 | 37 | |||||||||||
Refining margin per total throughput barrel | $ | 15.66 | $ | 14.13 | $ | 16.10 | $ | 15.72 | |||||||
Reconciliation of Petroleum Segment Refining Margin adjusted for inventory valuation impact (in millions and on per total throughput barrel basis)
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
(in millions, except for throughput barrel data) | 2019 | 2018 | 2019 | 2018 | |||||||||||
Refining margin adjusted for inventory valuation impact | $ | 308 | $ | 259 | $ | 593 | $ | 539 | |||||||
Divided by: total throughput barrels | 20 | 20 | 39 | 37 | |||||||||||
Refining margin adjusted for inventory valuation impact per total throughput barrel | $ | 15.68 | $ | 13.03 | $ | 15.28 | $ | 14.58 | |||||||
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Reconciliation of Petroleum Segment Direct operating expenses (in millions and on per total throughput barrel basis)
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
(in millions, except for throughput barrel data) | 2019 | 2018 | 2019 | 2018 | |||||||||||
Direct operating expenses (exclusive of depreciation and amortization) | $ | 86 | $ | 93 | $ | 177 | $ | 185 | |||||||
Divided by: total throughput barrels | 20 | 20 | 39 | 37 | |||||||||||
Direct operating expenses per total throughput barrel | $ | 4.40 | $ | 4.68 | $ | 4.57 | $ | 5.00 | |||||||
Reconciliation of Nitrogen Fertilizer Segment Net Income (Loss) to EBITDA
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
(in millions) | 2019 | 2018 | 2019 | 2018 | |||||||||||
Nitrogen fertilizer net income (loss) | $ | 19 | $ | (16 | ) | $ | 13 | $ | (36 | ) | |||||
Add: | |||||||||||||||
Interest expense, net | 16 | 16 | 31 | 32 | |||||||||||
Depreciation and amortization | 25 | 20 | 42 | 37 | |||||||||||
Nitrogen Fertilizer EBITDA | $ | 60 | $ | 20 | $ | 86 | $ | 33 | |||||||
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