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): August 1, 2012
CVR ENERGY, INC.
(Exact name of registrant as specified in its charter)
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Delaware (State or other |
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001-33492 (Commission File Number) |
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61-1512186 (I.R.S. Employer |
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))
Item 2.02. Results of Operations and Financial Condition.
On August 1, 2012, CVR Energy, Inc. (the “Company”) issued a press release announcing information regarding its results of operations and financial condition for the quarter and six months ended June 30, 2012, the text of which is attached hereto as Exhibit 99.1 and is incorporated herein by reference.
The information in Item 2.02 of this Current Report on Form 8-K and in Exhibit 99.1 attached hereto is being “furnished” and is not deemed “filed” by the Company for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, or otherwise subject to the liabilities of that Section, nor is it deemed incorporated by reference into any filing under the Securities Act of 1933, as amended, or the Securities Exchange Act of 1934, as amended.
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:
99.1 Press release.
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: August 1, 2012
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CVR Energy, Inc. | |
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By: |
/s/ Frank A. Pici |
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Frank A. Pici, |
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Chief Financial Officer and Treasurer |
Exhibit 99.1
CVR ENERGY REPORTS 2012 SECOND QUARTER RESULTS
SUGAR LAND, Texas (August 1, 2012) — CVR Energy, Inc. (NYSE: CVI), a refiner and marketer of petroleum fuels and the majority owner in nitrogen fertilizer manufacturer CVR Partners, LP (NYSE: UAN), today reported second quarter 2012 net income of $154.7 million, or $1.75 per fully diluted share, on net sales of $2,308.3 million, compared to second quarter 2011 net income of $124.9 million, or $1.42 per fully diluted share, on net sales of $1,447.7 million.
Second quarter 2012 adjusted net income, a non-GAAP financial measure, was $223.1 million, or $2.52 per diluted share, compared to $126.4 million, or $1.44 per diluted share, for the second quarter of 2011. Major items impacting the 2012 second quarter adjusted net income, all net of taxes, were an unfavorable impact from first-in, first-out (FIFO) accounting of $63.9 million; an unrealized gain on derivatives of $28.4 million; expenses associated with proxy matters of $17.8 million; and share-based compensation of $10.8 million.
Year-to-date, the company reported net income of $129.5 million, or $1.46 per diluted share, on net sales of $4,276.9 million compared to net income of $170.7 million, or $1.94 per diluted share, on net sales of $2,615.0 million for the first six months of 2011. Strong operating results for the first six months of 2012 were negatively impacted by an unrealized loss before tax on derivatives of $81.3 million and an unfavorable impact from FIFO accounting of $95.0 million.
“Our solid second quarter results were driven by wide crack spreads, favorable crude differentials and strong operational performance from both of our refineries,” said Jack Lipinski, CVR Energy’s chief executive officer. “Following the completion of a scheduled turnaround in March, our Coffeyville plant has run exceptionally well. In fact, the refinery set a new crude throughput record of 125,900 barrels per day for the month of June.
“Our continuing integration efforts are paying off handsomely at the Wynnewood refinery, as well,” he said. “Wynnewood posted $97.2 million of operating income for the quarter.
“Our results were also supported by our nitrogen fertilizer segment, which performed very well in the second quarter, reporting operating income of $36.1 million,” Lipinski said.
Petroleum Business
The petroleum business, which includes the Coffeyville and Wynnewood refineries, reported second quarter 2012 operating income of $248.9 million, and adjusted EBITDA, a non-GAAP financial measure, of $381.4 million, on net sales of $2,229.5 million, compared to operating
income in the same quarter a year earlier of $183.5 million, and adjusted EBITDA of $208.4 million, on net sales of $1,376.7 million.
Second quarter 2012 throughput of crude oil and all other feedstocks and blendstocks totaled 199,501 barrels per day (bpd), compared to 116,459 bpd for the same period in 2011. Crude oil throughput for the second quarter 2012 averaged 190,372 bpd per day compared with 109,486 bpd for the same period in 2011. The year-over-year increase in throughput was mostly driven by the addition of the Wynnewood refinery.
Refining margin adjusted for FIFO impact per crude oil throughput barrel, a non-GAAP financial measure, was $20.98 in the second quarter 2012 compared to $25.49 during the same period in 2011. Gross profit per crude oil throughput barrel was $15.31 in the second quarter 2012, as compared to $19.36 during the same period in 2011.
Direct operating expense per barrel sold, exclusive of depreciation and amortization, for the second quarter 2012 was $3.81, down from $4.09 in the second quarter 2011, driven by increased throughput at the Coffeyville refinery.
Coffeyville Refinery
The Coffeyville refinery reported second quarter 2012 operating income of $151.9 million on net sales of $2,162.2 million, compared to $185.4 million of operating income on net sales of $1,376.6 million for the second quarter of 2011. Second quarter 2012 crude oil throughput totaled 121,325 bpd, compared to 109,486 bpd in the second quarter of 2011. Refining margin per crude oil throughput barrel for the second quarter of 2012 was $20.61, compared to $25.46 for the same period in 2011. Gross profit per crude oil throughput barrel was $15.00 in the second quarter of 2012, compared to $19.40 for the 2011 second quarter. The refining margin adjusted for FIFO impact was $309.4 million for the 2012 second quarter, compared to $257.8 million for the same period in 2011. Direct operating expense per barrel sold for the 2012 second quarter was $3.62, compared to $4.09 for the 2011 second quarter.
Wynnewood Refinery
CVR Energy acquired the Wynnewood refinery in December 2011. The 2012 second quarter represents the refinery’s second full quarter of production as a CVR Energy subsidiary.
For the second quarter of 2012, the refinery’s crude oil throughput totaled 69,046 bpd. The refinery’s second quarter 2012 operating income was $97.2 million on net sales of $782.3 million. The refining margin adjusted for FIFO impact in the second quarter 2012 was $158.5 million and direct operating expense per barrel sold for the quarter was $4.02.
Nitrogen Fertilizers Business
The fertilizer business operated by CVR Partners, LP reported second quarter 2012 operating income of $36.1 million, and adjusted EBITDA, a non-GAAP financial measure, of $44.1 million, on net sales of $81.4 million, compared to operating income of $39.3 million, and adjusted EBITDA of $45.0 million, on net sales of $80.7 million for the 2011 second quarter.
CVR Partners produced 108,900 tons of ammonia during the second quarter of 2012, of which 34,900 net tons were available for sale while the rest was upgraded to 180,000 tons of more profitable urea ammonium nitrate (UAN). In the 2011 second quarter, the plant produced 102,300 tons of ammonia with 28,200 net tons available for sale with the remainder upgraded to 179,400 tons of UAN.
Second quarter 2012 average realized plant gate prices for ammonia and UAN were $568 per ton and $329 per ton, respectively, as compared to $574 per ton and $300 per ton, respectively, for the same period in 2011.
Cash and Debt
Consolidated cash and cash equivalents, which included $196.4 million for CVR Partners, increased to $692.6 million at the end of the 2012 second quarter, compared to $500.9 million at the end of the first quarter of 2012, primarily due to increased cash flows in the petroleum business. Consolidated long-term debt at the end of the 2012 second quarter, which included $125.0 million for CVR Partners, remained nearly unchanged at $851.9 million.
# # #
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. 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. For a discussion of risk factors which may affect our results, please see the risk factors and other disclosures included in our Annual Report on Form 10-K for the year ended Dec. 31, 2011, and any subsequently filed quarterly reports on Form 10-Q. These 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 press 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, Inc.’s subsidiary and affiliated businesses operate independent refining assets in Coffeyville, Kan., and Wynnewood, Okla., with more than 185,000 barrels per day of processing capacity, a marketing network for supplying high value transportation fuels to customers through tanker trucks and pipeline terminals, and a crude oil gathering system serving Kansas, Oklahoma, western Missouri, southwestern Nebraska and Texas. In addition, CVR Energy subsidiaries own a majority interest in and serve as the general partner of CVR Partners, LP, a producer of ammonia and urea ammonium nitrate, or UAN, fertilizers.
For further information, please contact:
Investor Relations:
Jay Finks
CVR Energy, Inc.
281-207-3588
InvestorRelations@CVREnergy.com
Media Relations:
Angie Dasbach
CVR Energy, Inc.
913-982-0482
MediaRelations@CVREnergy.com
CVR Energy, Inc.
Financial and Operational Data (all information in this release is unaudited unless noted otherwise).
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Three Months Ended |
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Change from 2011 |
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2012 |
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2011 |
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Change |
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Percent |
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(in millions, except per share data) |
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Consolidated Statement of Operations Data: |
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Net sales |
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$ |
2,308.3 |
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$ |
1,447.7 |
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$ |
860.6 |
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59.4 |
% |
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Cost of product sold |
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1,874.2 |
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1,123.4 |
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750.8 |
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66.8 |
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Direct operating expenses |
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94.1 |
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66.2 |
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27.9 |
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42.1 |
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Insurance recovery — business interruption |
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— |
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— |
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— |
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— |
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Selling, general and administrative expenses |
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72.0 |
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18.2 |
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53.8 |
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295.6 |
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Depreciation and amortization |
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32.2 |
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22.0 |
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10.2 |
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46.4 |
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Operating income |
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235.8 |
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217.9 |
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17.9 |
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8.2 |
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Interest expense and other financing costs |
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(19.0 |
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(14.2 |
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(4.8 |
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33.8 |
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Gain (loss) on derivatives, net |
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Realized |
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(8.1 |
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0.5 |
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(8.6 |
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(1,720.0 |
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Unrealized |
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46.9 |
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6.4 |
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40.5 |
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632.8 |
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Loss on extinguishment of debt |
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— |
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(0.2 |
) |
0.2 |
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— |
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Other income, net |
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0.8 |
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0.5 |
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0.3 |
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60.0 |
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Income before income tax expense |
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256.4 |
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210.9 |
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45.5 |
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21.6 |
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Income tax expense |
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91.1 |
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76.7 |
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14.4 |
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18.8 |
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Net income |
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165.3 |
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134.2 |
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31.1 |
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23.2 |
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Net income attributable to noncontrolling interest |
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10.6 |
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9.3 |
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1.3 |
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14.0 |
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Net income attributable to CVR Energy stockholders |
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$ |
154.7 |
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$ |
124.9 |
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$ |
29.8 |
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23.9 |
% |
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Basic earnings per share |
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$ |
1.78 |
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$ |
1.44 |
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$ |
0.34 |
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23.6 |
% |
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Diluted earnings per share |
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$ |
1.75 |
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$ |
1.42 |
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$ |
0.33 |
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23.2 |
% |
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Adjusted net income |
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$ |
223.1 |
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$ |
126.4 |
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$ |
96.7 |
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76.5 |
% |
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Adjusted net income, per diluted share |
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$ |
2.52 |
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$ |
1.44 |
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$ |
1.08 |
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75.0 |
% |
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Weighted-average common shares outstanding: |
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Basic |
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86.8 |
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86.4 |
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0.4 |
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0.5 |
% | |||
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Diluted |
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88.5 |
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87.8 |
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0.6 |
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0.7 |
% | |||
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Six Months Ended |
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Change from 2011 |
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2012 |
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2011 |
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Change |
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Percent |
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(in millions, except per share data) |
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Consolidated Statement of Operations Data: |
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Net sales |
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$ |
4,276.9 |
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$ |
2,615.0 |
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$ |
1,661.9 |
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63.6 |
% |
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Cost of product sold |
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3,509.4 |
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2,060.2 |
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1,449.2 |
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70.3 |
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Direct operating expenses |
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209.6 |
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134.6 |
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75.0 |
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55.7 |
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Insurance recovery — business interruption |
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— |
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(2.9 |
) |
2.9 |
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— |
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Selling, general and administrative expenses |
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117.3 |
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51.5 |
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65.8 |
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127.8 |
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Depreciation and amortization |
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64.3 |
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44.1 |
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20.2 |
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45.8 |
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Operating income |
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376.3 |
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327.5 |
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48.8 |
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14.9 |
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Interest expense and other financing costs |
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(38.2 |
) |
(27.4 |
) |
(10.8 |
) |
39.4 |
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Gain (loss) on derivatives, net |
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Realized |
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(27.2 |
) |
(18.4 |
) |
(8.8 |
) |
47.8 |
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Unrealized |
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(81.3 |
) |
3.2 |
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(84.5 |
) |
(2,640.6 |
) | |||
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Loss on extinguishment of debt |
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— |
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(2.1 |
) |
2.1 |
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— |
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Other income, net |
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1.1 |
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1.1 |
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— |
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— |
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Income before income tax expense |
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230.7 |
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283.9 |
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(53.2 |
) |
(18.7 |
) | |||
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Income tax expense |
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81.4 |
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103.9 |
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(22.5 |
) |
(21.7 |
) | |||
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Net income |
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149.3 |
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180.0 |
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(30.7 |
) |
(17.1 |
) | |||
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Net income attributable to noncontrolling interest |
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19.8 |
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9.3 |
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10.5 |
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112.9 |
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Net income attributable to CVR Energy stockholders |
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$ |
129.5 |
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$ |
170.7 |
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$ |
(41.2 |
) |
(24.1 |
)% |
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Basic earnings per share |
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$ |
1.49 |
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$ |
1.97 |
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$ |
(0.48 |
) |
(24.4 |
)% |
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Diluted earnings per share |
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$ |
1.46 |
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$ |
1.94 |
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$ |
(0.48 |
) |
(24.7 |
)% |
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Adjusted net income |
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$ |
295.7 |
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$ |
175.6 |
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$ |
120.1 |
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68.4 |
% |
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Adjusted net income, per diluted share |
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$ |
3.34 |
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$ |
2.00 |
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$ |
1.34 |
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67.0 |
% |
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Weighted-average common shares outstanding: |
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Basic |
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86.8 |
|
86.4 |
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0.4 |
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0.5 |
% | |||
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Diluted |
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88.5 |
|
87.8 |
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0.7 |
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0.8 |
% | |||
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As of June 30, |
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As of December 31, |
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2012 |
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2011 |
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(audited) |
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(in millions) |
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Balance Sheet Data: |
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Cash and cash equivalents |
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$ |
692.6 |
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$ |
388.3 |
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Working capital |
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904.5 |
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769.2 |
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Total assets |
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3,284.7 |
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3,119.3 |
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Long-term debt |
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851.9 |
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853.9 |
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Total CVR stockholders’ equity |
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1,276.5 |
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1,151.6 |
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Three Months Ended |
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Six Months Ended |
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2012 |
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2011 |
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2012 |
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2011 |
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(in millions) |
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Cash Flow Data |
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Net cash flow provided by (used in): |
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Operating activities |
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$ |
249.6 |
|
$ |
178.6 |
|
$ |
435.9 |
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$ |
162.6 |
|
|
Investing activities |
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(45.4 |
) |
(13.6 |
) |
(104.8 |
) |
(20.7 |
) | ||||
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Financing activities |
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(12.4 |
) |
417.1 |
|
(26.8 |
) |
406.0 |
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Net cash flow |
|
$ |
191.8 |
|
$ |
582.1 |
|
$ |
304.3 |
|
$ |
547.9 |
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Segment Information
Our operations are organized into two reportable segments, Petroleum and Nitrogen Fertilizer. Our operations that are not included in the Petroleum and Nitrogen Fertilizer segments are included in Corporate and Other segment (along with elimination of intersegment transactions). The Petroleum segment includes the operations of our Coffeyville, Kansas and Wynnewood, Oklahoma refineries along with our crude oil gathering and pipeline systems. The Nitrogen Fertilizer segment is operated by CVR Partners, LP, (“CVR Partners”) of which we own a majority interest and serve as general partner. It consists of a nitrogen fertilizer manufacturing facility that utilizes a pet coke gasification process in producing nitrogen fertilizer. Detailed operating results for the Nitrogen Fertilizer segment for the quarter ended June 30, 2012 are included in CVR Partners’ press release dated August 1, 2012.
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Petroleum |
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Nitrogen |
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Corporate |
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Consolidated |
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(in millions) |
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Three months ended June 30, 2012 |
|
|
|
|
|
|
|
|
| ||||
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Net sales |
|
$ |
2,229.5 |
|
$ |
81.4 |
|
$ |
(2.6 |
) |
$ |
2,308.3 |
|
|
Cost of product sold |
|
1,866.1 |
|
10.7 |
|
(2.6 |
) |
1,874.2 |
| ||||
|
Direct operating expenses (1) |
|
69.1 |
|
22.4 |
|
0.1 |
|
91.6 |
| ||||
|
Major scheduled turnaround expense |
|
2.5 |
|
— |
|
— |
|
2.5 |
| ||||
|
Selling, general & administrative |
|
16.3 |
|
7.0 |
|
48.7 |
|
72.0 |
| ||||
|
Depreciation and amortization |
|
26.6 |
|
5.2 |
|
0.4 |
|
32.2 |
| ||||
|
Operating income (loss) |
|
$ |
248.9 |
|
$ |
36.1 |
|
$ |
(49.2 |
) |
$ |
235.8 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Capital expenditures |
|
$ |
27.0 |
|
$ |
16.9 |
|
$ |
1.7 |
|
$ |
45.6 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Six months ended June 30, 2012 |
|
|
|
|
|
|
|
|
| ||||
|
Net sales |
|
$ |
4,128.0 |
|
$ |
159.7 |
|
$ |
(10.8 |
) |
$ |
4,276.9 |
|
|
Cost of product sold |
|
3,496.8 |
|
23.3 |
|
(10.7 |
) |
3,509.4 |
| ||||
|
Direct operating expenses (1) |
|
140.8 |
|
45.3 |
|
— |
|
186.1 |
| ||||
|
Major scheduled turnaround expense |
|
23.5 |
|
— |
|
— |
|
23.5 |
| ||||
|
Selling, general & administrative |
|
30.2 |
|
13.0 |
|
74.0 |
|
117.3 |
| ||||
|
Depreciation and amortization |
|
52.9 |
|
10.6 |
|
0.8 |
|
64.3 |
| ||||
|
Operating income (loss) |
|
$ |
383.8 |
|
$ |
67.5 |
|
$ |
(74.9 |
) |
$ |
376.3 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Capital expenditures |
|
$ |
62.4 |
|
$ |
39.2 |
|
$ |
3.6 |
|
$ |
105.2 |
|
|
|
|
Petroleum |
|
Nitrogen |
|
Corporate |
|
Consolidated |
| ||||
|
|
|
(in millions) |
| ||||||||||
|
Three months ended June 30, 2011 |
|
|
|
|
|
|
|
|
| ||||
|
Net sales |
|
$ |
1,376.7 |
|
$ |
80.7 |
|
$ |
(9.7 |
) |
$ |
1,447.7 |
|
|
Cost of product sold |
|
1,122.8 |
|
9.7 |
|
(9.1 |
) |
1,123.4 |
| ||||
|
Direct operating expenses (1) |
|
44.0 |
|
22.3 |
|
(0.1 |
) |
66.2 |
| ||||
|
Major scheduled turnaround expense |
|
— |
|
— |
|
— |
|
— |
| ||||
|
Insurance recovery — business interruption |
|
— |
|
— |
|
— |
|
— |
| ||||
|
Selling, general & administrative |
|
9.4 |
|
4.7 |
|
4.1 |
|
18.2 |
| ||||
|
Depreciation and amortization |
|
17.0 |
|
4.7 |
|
0.3 |
|
22.0 |
| ||||
|
Operating income (loss) |
|
$ |
183.5 |
|
$ |
39.3 |
|
$ |
(4.9 |
) |
$ |
217.9 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Capital expenditures |
|
$ |
8.6 |
|
$ |
4.0 |
|
$ |
1.0 |
|
$ |
13.6 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Six months ended June 30, 2011 |
|
|
|
|
|
|
|
|
| ||||
|
Net sales |
|
$ |
2,487.9 |
|
$ |
138.1 |
|
$ |
(11.0 |
) |
$ |
2,615.0 |
|
|
Cost of product sold |
|
2,053.0 |
|
17.2 |
|
(10.0 |
) |
2,060.2 |
| ||||
|
Direct operating expenses (1) |
|
89.5 |
|
45.3 |
|
(0.2 |
) |
134.6 |
| ||||
|
Major scheduled turnaround expense |
|
— |
|
— |
|
— |
|
— |
| ||||
|
Insurance recovery — business interruption |
|
— |
|
(2.9 |
) |
— |
|
(2.9 |
) | ||||
|
Selling, general & administrative |
|
22.3 |
|
13.1 |
|
16.1 |
|
51.5 |
| ||||
|
Depreciation and amortization |
|
33.9 |
|
9.3 |
|
0.9 |
|
44.1 |
| ||||
|
Operating income (loss) |
|
$ |
289.2 |
|
$ |
56.1 |
|
$ |
(17.8 |
) |
$ |
327.5 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Capital expenditures |
|
$ |
13.2 |
|
$ |
6.0 |
|
$ |
1.8 |
|
$ |
21.0 |
|
(1) Excluding turnaround expenses.
|
|
|
Petroleum |
|
Nitrogen |
|
Corporate |
|
Consolidated |
| ||||
|
|
|
(in millions) |
| ||||||||||
|
June 30, 2012 |
|
|
|
|
|
|
|
|
| ||||
|
Cash and cash equivalents (1) |
|
$ |
— |
|
$ |
196.4 |
|
$ |
496.2 |
|
$ |
692.6 |
|
|
Total assets |
|
2,540.0 |
|
639.7 |
|
105.0 |
|
3,284.7 |
| ||||
|
Long-term debt (1) |
|
— |
|
125.0 |
|
726.9 |
|
851.9 |
| ||||
|
|
|
|
|
|
|
|
|
|
| ||||
|
December 31, 2011 |
|
|
|
|
|
|
|
|
| ||||
|
Cash and cash equivalents (1) |
|
$ |
— |
|
$ |
237.0 |
|
$ |
151.3 |
|
$ |
388.3 |
|
|
Total assets |
|
2,322.1 |
|
659.3 |
|
137.9 |
|
3,119.3 |
| ||||
|
Long-term debt (1) |
|
— |
|
125.0 |
|
728.9 |
|
853.9 |
| ||||
(1) Corporate and Other is inclusive of the Petroleum segment’s cash and cash equivalents and long-term debt.
Petroleum Segment Operating Data
The following tables set forth information about our consolidated Petroleum segment operations and our Coffeyville and Wynnewood refineries. Reconciliations of certain non-GAAP financial measures are provided under “Use of Non-GAAP Financial Measures” below.
|
|
|
Three Months Ended |
|
Six Months Ended |
| ||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
| ||||
|
|
|
(in millions, except operating statistics) |
| ||||||||||
|
Petroleum Segment Summary Financial Results: |
|
|
|
|
|
|
|
|
| ||||
|
Net sales |
|
$ |
2,229.5 |
|
$ |
1,376.7 |
|
$ |
4,128.0 |
|
$ |
2,487.9 |
|
|
Cost of product sold |
|
1,866.1 |
|
1,122.8 |
|
3,496.8 |
|
2,053.0 |
| ||||
|
Refining margin* |
|
363.4 |
|
253.9 |
|
631.2 |
|
434.9 |
| ||||
|
Direct operating expenses |
|
69.1 |
|
44.0 |
|
140.8 |
|
89.5 |
| ||||
|
Major scheduled turnaround expense |
|
2.5 |
|
— |
|
23.5 |
|
— |
| ||||
|
Depreciation and amortization |
|
26.6 |
|
17.0 |
|
52.9 |
|
33.9 |
| ||||
|
Gross profit |
|
265.2 |
|
192.9 |
|
414.0 |
|
311.5 |
| ||||
|
Selling, general and administrative expenses |
|
16.3 |
|
9.4 |
|
30.2 |
|
22.3 |
| ||||
|
Operating income |
|
$ |
248.9 |
|
$ |
183.5 |
|
$ |
383.8 |
|
$ |
289.2 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Refining margin adjusted for FIFO impact* |
|
$ |
468.8 |
|
$ |
258.0 |
|
$ |
726.2 |
|
$ |
413.6 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Adjusted Petroleum EBITDA* |
|
$ |
381.4 |
|
$ |
208.4 |
|
$ |
535.2 |
|
$ |
296.6 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Petroleum Segment Key Operating Statistics: |
|
|
|
|
|
|
|
|
| ||||
|
Per crude oil throughput barrel: |
|
|
|
|
|
|
|
|
| ||||
|
Refining margin* |
|
$ |
20.98 |
|
$ |
25.49 |
|
$ |
20.58 |
|
$ |
23.08 |
|
|
FIFO impact (favorable) unfavorable |
|
6.09 |
|
0.41 |
|
3.10 |
|
(1.13 |
) | ||||
|
Refining margin adjusted for FIFO impact* |
|
27.07 |
|
25.90 |
|
23.68 |
|
21.95 |
| ||||
|
Gross profit |
|
15.31 |
|
19.36 |
|
13.50 |
|
16.53 |
| ||||
|
Direct operating expenses |
|
4.13 |
|
4.42 |
|
5.36 |
|
4.74 |
| ||||
|
Direct operating expenses per barrel sold |
|
$ |
3.81 |
|
$ |
4.09 |
|
$ |
4.69 |
|
$ |
4.45 |
|
|
Barrels sold (barrels per day) |
|
206,606 |
|
118,435 |
|
190,319 |
|
110,860 |
| ||||
|
|
|
Three Months Ended |
|
Six Months Ended |
| ||||||||||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
| ||||||||||||
|
Petroleum Segment Summary Refining Throughput and Production Data: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
(barrels per day) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Throughput: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Sweet |
|
148,912 |
|
74.6 |
% |
84,654 |
|
72.6 |
% |
129,781 |
|
73.1 |
% |
82,302 |
|
74.1 |
% | ||||
|
Light/medium sour |
|
20,488 |
|
10.3 |
% |
198 |
|
0.2 |
% |
22,728 |
|
12.8 |
% |
397 |
|
0.4 |
% | ||||
|
Heavy sour |
|
20,972 |
|
10.5 |
% |
24,634 |
|
21.2 |
% |
16,006 |
|
9.0 |
% |
21,416 |
|
19.3 |
% | ||||
|
Total crude oil throughput |
|
190,372 |
|
95.4 |
% |
109,486 |
|
94.0 |
% |
168,515 |
|
94.9 |
% |
104,115 |
|
93.8 |
% | ||||
|
All other feedstocks and blendstocks |
|
9,129 |
|
4.6 |
% |
6,973 |
|
6.0 |
% |
8,929 |
|
5.1 |
% |
6,923 |
|
6.2 |
% | ||||
|
Total throughput |
|
199,501 |
|
100.0 |
% |
116,459 |
|
100.0 |
% |
174,444 |
|
100.0 |
% |
111,038 |
|
100.0 |
% | ||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Production: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Gasoline |
|
96,972 |
|
48.7 |
% |
53,495 |
|
45.5 |
% |
89,131 |
|
50.4 |
% |
51,564 |
|
46.2 |
% | ||||
|
Distillate |
|
82,075 |
|
41.3 |
% |
48,959 |
|
41.6 |
% |
72,202 |
|
40.9 |
% |
45,934 |
|
41.1 |
% | ||||
|
Other (excluding internally produced fuel) |
|
19,910 |
|
10.0 |
% |
15,106 |
|
12.9 |
% |
15,396 |
|
8.7 |
% |
14,158 |
|
12.7 |
% | ||||
|
Total refining production (excluding internally produced fuel) |
|
198,957 |
|
100.0 |
% |
117,560 |
|
100.0 |
% |
176,729 |
|
100.0 |
% |
111,656 |
|
100.0 |
% | ||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Product price (dollars per gallon): |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Gasoline |
|
$ |
2.89 |
|
|
|
$ |
3.07 |
|
|
|
$ |
2.88 |
|
|
|
$ |
2.86 |
|
|
|
|
Distillate |
|
2.95 |
|
|
|
3.14 |
|
|
|
3.03 |
|
|
|
3.03 |
|
|
| ||||
|
|
|
Three Months Ended |
|
Six Months Ended |
| ||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
| ||||
|
Market Indicators (dollars per barrel): |
|
|
|
|
|
|
|
|
| ||||
|
West Texas Intermediate (WTI) NYMEX |
|
$ |
93.35 |
|
$ |
102.34 |
|
$ |
98.15 |
|
$ |
98.50 |
|
|
Crude Oil Differentials: |
|
|
|
|
|
|
|
|
| ||||
|
WTI less WTS (light/medium sour) |
|
5.28 |
|
2.51 |
|
4.48 |
|
3.30 |
| ||||
|
WTI less WCS (heavy sour) |
|
20.45 |
|
17.61 |
|
23.79 |
|
19.76 |
| ||||
|
NYMEX Crack Spreads: |
|
|
|
|
|
|
|
|
| ||||
|
Gasoline |
|
30.42 |
|
27.85 |
|
27.95 |
|
22.98 |
| ||||
|
Heating Oil |
|
28.13 |
|
25.56 |
|
28.87 |
|
24.76 |
| ||||
|
NYMEX 2-1-1 Crack Spread |
|
29.27 |
|
26.71 |
|
28.41 |
|
23.87 |
| ||||
|
PADD II Group 3 Basis: |
|
|
|
|
|
|
|
|
| ||||
|
Gasoline |
|
(3.24 |
) |
(1.59 |
) |
(5.00 |
) |
(1.82 |
) | ||||
|
Ultra Low Sulfur Diesel |
|
2.16 |
|
3.24 |
|
0.28 |
|
2.21 |
| ||||
|
PADD II Group 3 Product Crack: |
|
|
|
|
|
|
|
|
| ||||
|
Gasoline |
|
27.18 |
|
26.26 |
|
22.95 |
|
21.16 |
| ||||
|
Ultra Low Sulfur Diesel |
|
30.29 |
|
28.81 |
|
29.14 |
|
26.97 |
| ||||
|
PADD II Group 3 2-1-1 |
|
28.74 |
|
27.53 |
|
26.05 |
|
24.06 |
| ||||
|
|
|
Three Months Ended |
|
Six Months Ended |
| ||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
| ||||
|
|
|
(in millions, except operating statistics) |
| ||||||||||
|
Coffeyville Refinery Financial Results: |
|
|
|
|
|
|
|
|
| ||||
|
Net sales |
|
$ |
2,162.2 |
|
$ |
1,376.6 |
|
$ |
3,457.9 |
|
$ |
2,487.7 |
|
|
Cost of product sold |
|
1,934.6 |
|
1,122.9 |
|
3,070.9 |
|
2,053.1 |
| ||||
|
Refining margin* |
|
227.6 |
|
253.7 |
|
387.0 |
|
434.6 |
| ||||
|
Direct operating expenses |
|
43.6 |
|
43.0 |
|
87.4 |
|
85.2 |
| ||||
|
Turnaround expenses |
|
0.9 |
|
1.1 |
|
21.0 |
|
4.3 |
| ||||
|
Depreciation and amortization |
|
17.4 |
|
16.3 |
|
34.7 |
|
32.6 |
| ||||
|
Gross profit |
|
165.7 |
|
193.3 |
|
243.9 |
|
312.5 |
| ||||
|
Selling, general and administrative expenses |
|
13.8 |
|
7.9 |
|
24.2 |
|
20.7 |
| ||||
|
Operating income |
|
$ |
151.9 |
|
$ |
185.4 |
|
$ |
219.7 |
|
$ |
291.8 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Refining margin adjusted for FIFO impact* |
|
$ |
309.4 |
|
$ |
257.8 |
|
$ |
455.8 |
|
$ |
413.3 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Coffeyville Refinery Key Operating Statistics: |
|
|
|
|
|
|
|
|
| ||||
|
Per crude oil throughput barrel: |
|
|
|
|
|
|
|
|
| ||||
|
Refining margin* |
|
$ |
20.61 |
|
$ |
25.46 |
|
$ |
20.27 |
|
$ |
23.06 |
|
|
FIFO impact (favorable) unfavorable |
|
7.41 |
|
0.41 |
|
3.61 |
|
(1.13 |
) | ||||
|
Refining margin adjusted for FIFO impact* |
|
28.02 |
|
25.87 |
|
23.88 |
|
21.93 |
| ||||
|
Gross profit |
|
15.00 |
|
19.40 |
|
12.78 |
|
16.59 |
| ||||
|
Direct operating expenses |
|
4.03 |
|
4.42 |
|
5.68 |
|
4.74 |
| ||||
|
Direct operating expenses per barrel sold |
|
$ |
3.62 |
|
$ |
4.09 |
|
$ |
5.02 |
|
$ |
4.45 |
|
|
Barrels sold (barrels per day) |
|
135,062 |
|
118,435 |
|
118,569 |
|
110,860 |
| ||||
|
|
|
Three Months Ended |
|
Six Months Ended |
| ||||||||||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
| ||||||||||||
|
Coffeyville Refinery Throughput and Production Data: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
(barrels per day) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Throughput: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Sweet |
|
100,166 |
|
78.4 |
% |
84,654 |
|
72.6 |
% |
86,041 |
|
77.7 |
% |
82,302 |
|
74.1 |
% | ||||
|
Light/medium sour |
|
187 |
|
0.1 |
% |
198 |
|
0.2 |
% |
2,817 |
|
2.5 |
% |
397 |
|
0.4 |
% | ||||
|
Heavy sour |
|
20,972 |
|
16.4 |
% |
24,634 |
|
21.2 |
% |
16,006 |
|
14.4 |
% |
21,415 |
|
19.3 |
% | ||||
|
Total crude oil throughput |
|
121,325 |
|
94.9 |
|
109,486 |
|
94.0 |
% |
104,864 |
|
94.6 |
% |
104,114 |
|
93.8 |
% | ||||
|
All other feedstocks and blendstocks |
|
6,500 |
|
5.1 |
% |
6,973 |
|
6.0 |
% |
5,934 |
|
5.4 |
% |
6,923 |
|
6.2 |
% | ||||
|
Total throughput |
|
127,825 |
|
100.0 |
% |
116,459 |
|
100.0 |
% |
110,798 |
|
100.0 |
% |
111,037 |
|
100.0 |
% | ||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Production: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Gasoline |
|
62,351 |
|
47.9 |
% |
53,495 |
|
45.5 |
% |
56,310 |
|
50.1 |
% |
51,564 |
|
46.2 |
% | ||||
|
Distillate |
|
54,933 |
|
42.3 |
% |
48,959 |
|
41.6 |
% |
48,004 |
|
42.7 |
% |
45,934 |
|
41.1 |
% | ||||
|
Other (excluding internally produced fuel) |
|
12,753 |
|
9.8 |
% |
15,106 |
|
12.9 |
% |
8,123 |
|
7.2 |
% |
14,157 |
|
12.7 |
% | ||||
|
Total refining production (excluding internally produced fuel) |
|
130,037 |
|
100.0 |
% |
117,560 |
|
100.0 |
% |
112,437 |
|
100.0 |
% |
111,655 |
|
100.0 |
% | ||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Product price (dollars per gallon): |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Gasoline |
|
$ |
2.89 |
|
|
|
$ |
3.07 |
|
|
|
$ |
2.89 |
|
|
|
$ |
2.86 |
|
|
|
|
Distillate |
|
2.94 |
|
|
|
3.14 |
|
|
|
3.00 |
|
|
|
3.03 |
|
|
| ||||
|
|
|
Three Months Ended |
|
Six Months Ended |
| ||
|
|
|
(in millions, except operating statistics) |
| ||||
|
Wynnewood Refinery Financial Results: |
|
|
|
|
| ||
|
Net sales |
|
$ |
782.3 |
|
$ |
1,607.8 |
|
|
Cost of product sold |
|
647.5 |
|
1,365.0 |
| ||
|
Refining margin* |
|
134.8 |
|
242.8 |
| ||
|
Direct operating expenses |
|
25.5 |
|
53.4 |
| ||
|
Turnaround expenses |
|
1.6 |
|
2.5 |
| ||
|
Depreciation and amortization |
|
8.4 |
|
16.7 |
| ||
|
Gross profit |
|
99.3 |
|
170.2 |
| ||
|
Selling, general and administrative expenses |
|
2.1 |
|
5.5 |
| ||
|
Operating income |
|
$ |
97.2 |
|
$ |
164.7 |
|
|
|
|
|
|
|
| ||
|
Refining margin adjusted for FIFO impact* |
|
$ |
158.5 |
|
$ |
269.0 |
|
|
|
|
|
|
|
| ||
|
Wynnewood Refinery Key Operating Statistics: |
|
|
|
|
| ||
|
Per crude oil throughput barrel: |
|
|
|
|
| ||
|
Refining margin* |
|
$ |
21.47 |
|
$ |
20.97 |
|
|
FIFO impact (favorable) unfavorable |
|
3.76 |
|
2.25 |
| ||
|
Refining margin adjusted for FIFO impact* |
|
25.23 |
|
23.22 |
| ||
|
Gross profit |
|
15.82 |
|
14.70 |
| ||
|
Direct operating expenses |
|
4.30 |
|
4.83 |
| ||
|
Direct operating expenses per barrel sold |
|
$ |
4.02 |
|
$ |
4.15 |
|
|
Barrels sold (barrels per day) |
|
74,072 |
|
73,996 |
| ||
|
|
|
Three Months Ended |
|
Six Months Ended |
| ||||||
|
|
|
|
|
% |
|
|
|
% |
| ||
|
Wynnewood Refinery Throughput and Production Data: |
|
|
|
|
|
|
|
|
| ||
|
(barrels per day) |
|
|
|
|
|
|
|
|
| ||
|
Throughput: |
|
|
|
|
|
|
|
|
| ||
|
Sweet |
|
48,745 |
|
68.0 |
% |
43,740 |
|
65.6 |
% | ||
|
Light/medium sour |
|
20,301 |
|
28.3 |
% |
19,911 |
|
29.9 |
% | ||
|
Heavy sour |
|
— |
|
— |
% |
— |
|
— |
% | ||
|
Total crude oil throughput |
|
69,046 |
|
96.3 |
% |
63,651 |
|
95.5 |
% | ||
|
All other feedstocks and blendstocks |
|
2,629 |
|
3.7 |
% |
2,995 |
|
4.5 |
% | ||
|
Total throughput |
|
71,675 |
|
100.0 |
% |
66,646 |
|
100.0 |
% | ||
|
|
|
|
|
|
|
|
|
|
| ||
|
Production: |
|
|
|
|
|
|
|
|
| ||
|
Gasoline |
|
34,621 |
|
50.2 |
% |
32,821 |
|
51.0 |
% | ||
|
Distillate |
|
27,142 |
|
39.4 |
% |
24,198 |
|
37.6 |
% | ||
|
Other (excluding internally produced fuel) |
|
7,157 |
|
10.4 |
% |
7,273 |
|
11.4 |
% | ||
|
Total refining production (excluding internally produced fuel) |
|
68,920 |
|
100.0 |
% |
64,292 |
|
100.0 |
% | ||
|
|
|
|
|
|
|
|
|
|
| ||
|
Product price (dollars per gallon): |
|
|
|
|
|
|
|
|
| ||
|
Gasoline |
|
$ |
2.88 |
|
|
|
$ |
2.90 |
|
|
|
|
Distillate |
|
2.95 |
|
|
|
3.06 |
|
|
| ||
Nitrogen Fertilizer Segment Operating Data
The following tables set forth information about the Nitrogen Fertilizer segment operated by CVR Partners, of which we own a majority interest and serve as general partner. Reconciliations of certain non-GAAP financial measures are provided under “Use of Non-GAAP Financial Measures” below. Additional discussion of operating results for the Nitrogen Fertilizer segment for the quarter ended June 30, 2012 are included in CVR Partners’ press release dated August 1, 2012.
|
|
|
Three Months Ended |
|
Six Months Ended |
| ||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
| ||||
|
|
|
(in millions, except as noted) |
| ||||||||||
|
Nitrogen Fertilizer Segment Financial Results: |
|
|
|
|
|
|
|
|
| ||||
|
Net sales |
|
$ |
81.4 |
|
$ |
80.7 |
|
$ |
159.7 |
|
$ |
138.1 |
|
|
Cost of product sold |
|
10.7 |
|
9.7 |
|
23.3 |
|
17.2 |
| ||||
|
Direct operating expenses |
|
22.4 |
|
22.3 |
|
45.3 |
|
45.3 |
| ||||
|
Insurance recovery — business interruption |
|
— |
|
— |
|
— |
|
(2.9 |
) | ||||
|
Selling, general and administrative expenses |
|
7.0 |
|
4.7 |
|
13.0 |
|
13.1 |
| ||||
|
Depreciation and amortization |
|
5.2 |
|
4.7 |
|
10.6 |
|
9.3 |
| ||||
|
|
|
|
|
|
|
|
|
|
| ||||
|
Operating income |
|
$ |
36.1 |
|
$ |
39.3 |
|
$ |
67.5 |
|
$ |
56.1 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Adjusted Nitrogen Fertilizer EBITDA* |
|
$ |
44.1 |
|
$ |
45.0 |
|
$ |
82.1 |
|
$ |
70.9 |
|
|
|
|
Three Months Ended |
|
Six Months Ended |
| ||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
| ||||
|
|
|
(in millions, except as noted) |
| ||||||||||
|
Nitrogen Fertilizer Segment Key Operating Statistics: |
|
|
|
|
|
|
|
|
| ||||
|
Production (thousand tons): |
|
|
|
|
|
|
|
|
| ||||
|
Ammonia (gross produced) (1) |
|
108.9 |
|
102.3 |
|
198.2 |
|
207.6 |
| ||||
|
Ammonia (net available for sale) (1) |
|
34.9 |
|
28.2 |
|
59.9 |
|
63.4 |
| ||||
|
UAN |
|
180.0 |
|
179.4 |
|
334.6 |
|
350.0 |
| ||||
|
|
|
|
|
|
|
|
|
|
| ||||
|
Petroleum coke consumed (thousand tons) |
|
130.2 |
|
135.8 |
|
250.7 |
|
259.9 |
| ||||
|
Petroleum coke (cost per ton) |
|
$ |
31 |
|
$ |
30 |
|
$ |
36 |
|
$ |
23 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Sales (thousand tons): |
|
|
|
|
|
|
|
|
| ||||
|
Ammonia |
|
29.4 |
|
33.6 |
|
59.3 |
|
60.9 |
| ||||
|
UAN |
|
177.2 |
|
166.1 |
|
335.5 |
|
345.4 |
| ||||
|
|
|
|
|
|
|
|
|
|
| ||||
|
Product pricing (plant gate) (dollars per ton) (2): |
|
|
|
|
|
|
|
|
| ||||
|
Ammonia |
|
$ |
568 |
|
$ |
574 |
|
$ |
591 |
|
$ |
570 |
|
|
UAN |
|
$ |
329 |
|
$ |
300 |
|
$ |
322 |
|
$ |
252 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
On-stream factors (3): |
|
|
|
|
|
|
|
|
| ||||
|
Gasification |
|
99.2 |
% |
99.3 |
% |
96.2 |
% |
99.6 |
% | ||||
|
Ammonia |
|
98.0 |
% |
98.5 |
% |
94.7 |
% |
97.6 |
% | ||||
|
UAN |
|
96.7 |
% |
97.6 |
% |
90.1 |
% |
95.4 |
% | ||||
|
|
|
|
|
|
|
|
|
|
| ||||
|
Market Indicators: |
|
|
|
|
|
|
|
|
| ||||
|
Ammonia — Southern Plains (dollars per ton) |
|
$ |
585 |
|
$ |
604 |
|
$ |
585 |
|
$ |
605 |
|
|
UAN — Mid Cornbelt (dollars per ton) |
|
$ |
417 |
|
$ |
366 |
|
$ |
380 |
|
$ |
358 |
|
* See Use of Non-GAAP Financial Measures below.
(1) Gross tons produced for ammonia represent the total ammonia produced, including ammonia produced that was upgraded into UAN. The net tons available for sale represent the ammonia available for sale that was not upgraded into UAN.
(2) Plant gate sales per ton represent net sales less freight and hydrogen revenue divided by product sales volume in tons in the reporting period and is shown in order to provide a pricing measure that is comparable across the fertilizer industry.
(3) On-stream factor is the total number of hours operated divided by the total number of hours in the reporting period and is included as a measure of operating efficiency.
Use of Non-GAAP Financial Measures
To supplement the actual results in accordance with GAAP for the applicable periods, the Company also uses non-GAAP measures as discussed below, which are adjusted for GAAP-based results. The use of non-GAAP adjustments are not in accordance with or an alternative for GAAP. The adjustments are provided to enhance an overall understanding of the Company’s financial performance for the applicable periods and are indicators management believes are relevant and useful for planning and forecasting future periods.
Adjusted net income is not a recognized term under GAAP and should not be substituted for net income (loss) as a measure of our performance but rather should be utilized as a supplemental measure of financial performance in evaluating our business. Management believes that adjusted net income provides relevant and useful information that enables external users of our financial statements, such as industry analysts, investors, lenders and rating agencies to better understand and evaluate our ongoing operating results and allow for greater transparency in the review of our overall financial, operational and economic performance.
|
|
|
Three Months Ended |
|
Six Months Ended |
| ||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
| ||||
|
|
|
(in millions, except per share data) |
| ||||||||||
|
Reconciliation of Net Income to Adjusted Net Income: |
|
|
|
|
|
|
|
|
| ||||
|
Net Income attributable to CVR Energy stockholders |
|
$ |
154.7 |
|
$ |
124.9 |
|
$ |
129.5 |
|
$ |
170.7 |
|
|
Adjustments (all net of taxes): |
|
|
|
|
|
|
|
|
| ||||
|
FIFO impact (favorable) unfavorable |
|
63.9 |
|
2.5 |
|
57.6 |
|
(12.9 |
) | ||||
|
Share-based compensation |
|
10.8 |
|
1.3 |
|
13.3 |
|
15.0 |
| ||||
|
Loss on extinguishment of debt |
|
— |
|
0.1 |
|
— |
|
1.3 |
| ||||
|
Major scheduled turnaround expense |
|
1.5 |
|
0.6 |
|
14.2 |
|
2.5 |
| ||||
|
Loss on disposition of fixed assets |
|
— |
|
0.9 |
|
— |
|
0.9 |
| ||||
|
Unrealized (gain) loss on derivatives |
|
(28.4 |
) |
(3.9 |
) |
49.3 |
|
(1.9 |
) | ||||
|
Expenses associated with proxy matters |
|
17.8 |
|
— |
|
26.8 |
|
— |
| ||||
|
Expenses associated with the acquisition of Gary-Williams (1) |
|
2.8 |
|
— |
|
5.0 |
|
— |
| ||||
|
Adjusted net income |
|
$ |
223.1 |
|
$ |
126.4 |
|
$ |
295.7 |
|
$ |
175.6 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Adjusted net income per diluted share |
|
$ |
2.52 |
|
$ |
1.44 |
|
$ |
3.34 |
|
$ |
2.00 |
|
(1) Legal, professional and integration expenses related to acquisition of Gary-Williams in December 2011.
Refining margin per crude oil throughput barrel is a measurement calculated as the difference between net sales and cost of product sold (exclusive of depreciation and amortization). Refining margin is a non-GAAP measure that we believe is important to investors in evaluating our refinery’s performance as a general indication of the amount above our cost of product sold that we are able to sell refined products. Each of the components used in this calculation (net sales and cost of product sold exclusive of depreciation and amortization) can be taken directly from our Statement of Operations. Our calculation of refining margin may differ from similar calculations of other companies in our industry, thereby limiting its usefulness as a comparative measure. In order to derive the refining margin per crude oil throughput barrel, we utilize the total dollar figures for refining margin as derived above and divide by the applicable number of crude oil throughput barrels for the period. We believe that refining margin is important to enable investors to better understand and evaluate our ongoing operating results and allow for greater transparency in the review of our overall financial, operational and economic performance.
Refining margin per crude oil throughput barrel adjusted for FIFO impact is a measurement calculated as the difference between net sales and cost of product sold (exclusive of depreciation and amortization) adjusted for FIFO impacts. Refining margin adjusted for FIFO impact is a non-GAAP measure that we believe is important to investors in evaluating our refinery’s performance as a general indication of the amount above our cost of product sold (taking into account the impact of our utilization of FIFO) that we are able to sell refined products. Our calculation of refining margin adjusted for FIFO impact may differ from calculations of other companies in our industry, thereby limiting its usefulness as a comparative measure. Under our FIFO accounting method, changes in crude oil prices can cause fluctuations in the inventory valuation of our crude oil, work in process and finished goods, thereby resulting in favorable FIFO impacts when crude oil prices increase and unfavorable FIFO impacts when crude oil prices decrease.
Adjusted Petroleum and Nitrogen Fertilizer EBITDA represents operating income adjusted for FIFO impacts (favorable) unfavorable, share-based compensation, major scheduled turnaround expenses, realized gain (loss) on derivatives, net, loss on disposition of fixed assets, depreciation and amortization and other income (expense). Adjusted EBITDA by operating segment results from operating income by segment adjusted for items that we believe are needed in order to evaluate results in a more comparative analysis from period to period. Adjusted EBITDA by operating segment is not a recognized term under GAAP and should not be substituted for operating income as a measure of performance but should be utilized as a supplemental measure of performance in evaluating our business. Management believes that adjusted EBITDA by operating segment provides relevant and useful information that enables investors to better understand and evaluate our ongoing operating results and allows for greater transparency in the reviewing of our overall financial, operational and economic performance. Below is a reconciliation of operating income to adjusted EBITDA for the petroleum and nitrogen fertilizer segments for the three and six months ended June 30, 2012 and 2011:
|
|
|
Three Months Ended |
|
Six Months Ended |
| ||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
| ||||
|
|
|
(in millions) |
| ||||||||||
|
Petroleum: |
|
|
|
|
|
|
|
|
| ||||
|
Petroleum operating income |
|
$ |
248.9 |
|
$ |
183.5 |
|
$ |
383.8 |
|
$ |
289.2 |
|
|
FIFO impacts (favorable) unfavorable |
|
105.4 |
|
4.1 |
|
95.0 |
|
(21.3 |
) | ||||
|
Share-based compensation |
|
5.4 |
|
0.5 |
|
6.4 |
|
7.1 |
| ||||
|
Major scheduled turnaround expenses |
|
2.5 |
|
1.1 |
|
23.5 |
|
4.3 |
| ||||
|
Loss on disposition of fixed assets |
|
— |
|
1.5 |
|
— |
|
1.5 |
| ||||
|
Realized gain (loss) on derivatives, net |
|
(8.1 |
) |
0.5 |
|
(27.2 |
) |
(18.4 |
) | ||||
|
Depreciation and amortization |
|
26.6 |
|
17.0 |
|
52.9 |
|
33.9 |
| ||||
|
Other income |
|
0.7 |
|
0.2 |
|
0.8 |
|
0.3 |
| ||||
|
Adjusted Petroleum EBITDA |
|
$ |
381.4 |
|
$ |
208.4 |
|
$ |
535.2 |
|
$ |
296.6 |
|
|
|
|
Three Months Ended |
|
Six Months Ended |
| ||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
| ||||
|
|
|
(in millions) |
| ||||||||||
|
Nitrogen Fertilizer: |
|
|
|
|
|
|
|
|
| ||||
|
Nitrogen Fertilizer operating income |
|
$ |
36.1 |
|
$ |
39.3 |
|
$ |
67.5 |
|
$ |
56.1 |
|
|
Share-based compensation |
|
2.8 |
|
0.9 |
|
4.0 |
|
5.5 |
| ||||
|
Depreciation and amortization |
|
5.2 |
|
4.7 |
|
10.6 |
|
9.3 |
| ||||
|
Other income, net |
|
— |
|
0.1 |
|
— |
|
— |
| ||||
|
Adjusted Nitrogen Fertilizer EBITDA |
|
$ |
44.1 |
|
$ |
45.0 |
|
$ |
82.1 |
|
$ |
70.9 |
|
Derivatives Summary. To reduce the basis risk between the price of products for Group 3 and that of the NYMEX associated with selling forward derivative contracts for NYMEX crack spreads, we may enter into basis swap positions to lock the price difference. If the difference between the price of products on the NYMEX and Group 3 (or some other price benchmark as we may deem appropriate) is different than the value contracted in the swap, then we will receive from or owe to the counterparty the difference on each unit of product contracted in the swap, thereby completing the locking of our margin. From time to time our petroleum segment holds various NYMEX positions through a third-party clearing house. In addition, the Company enters into commodity swap contracts. The physical volumes are not exchanged and these contracts are net settled with cash.
The table below summarizes our open commodity derivatives positions as of June 30, 2012. The positions are primarily in the form of ‘crack spread’ swap agreements with financial counterparties, wherein the Company will receive the fixed prices noted below.
|
|
|
Barrels |
|
Fixed Price(1) |
| |
|
Commodity Swaps |
|
|
|
|
| |
|
Third Quarter 2012 |
|
4,950,000 |
|
$ |
23.62 |
|
|
Fourth Quarter 2012 |
|
3,075,000 |
|
20.54 |
| |
|
|
|
|
|
|
| |
|
First Quarter 2013 |
|
2,100,000 |
|
24.31 |
| |
|
Second Quarter 2013 |
|
1,125,000 |
|
24.85 |
| |
|
Third Quarter 2013 |
|
1,125,000 |
|
23.86 |
| |
|
Fourth Quarter 2013 |
|
1,125,000 |
|
22.51 |
| |
|
|
|
|
|
|
| |
|
Total |
|
13,500,000 |
|
$ |
23.06 |
|
(1) Weighted-average price of all positions for period indicated.