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): November 5, 2012
CVR ENERGY, INC.
(Exact name of registrant as specified in its charter)
|
Delaware (State or other |
|
001-33492 (Commission File Number) |
|
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 November 5, 2012, CVR Energy, Inc. (the “Company”) issued a press release announcing information regarding its results of operations and financial condition for the quarter and nine months ended September 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: November 5, 2012 |
| |
|
|
| |
|
|
| |
|
|
CVR Energy, Inc. | |
|
|
|
|
|
|
|
|
|
|
By: |
/s/ Susan M. Ball |
|
|
|
Susan M. Ball, |
|
|
|
Chief Financial Officer and Treasurer |
Exhibit 99.1
CVR ENERGY REPORTS RECORD 2012 THIRD QUARTER EARNINGS
Company Posts Best-Ever Quarterly Net Income Since 2007 IPO
SUGAR LAND, Texas (Nov. 5, 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 record net income in the 2012 third quarter of $208.9 million, or $2.41 per fully diluted share, on net sales of $2,409.6 million, compared to third quarter 2011 net income of $109.3 million, or $1.25 per fully diluted share, on net sales of $1,352.0 million.
Third quarter 2012 adjusted net income, a non-GAAP financial measure, was $260.2 million, or $3.00 per diluted share, compared to $137.4 million, or $1.57 per diluted share, for the third quarter of 2011. Major items impacting the 2012 third quarter adjusted net income, all net of taxes, were a favorable impact from first-in, first-out (FIFO) accounting of $30.9 million and an unrealized loss on derivatives of $70.1 million.
Year-to-date, the company reported net income of $338.4 million, or $3.86 per diluted share, on net sales of $6,686.5 million, compared to net income of $279.9 million, or $3.19 per diluted share, on net sales of $3,966.9 million for the same period in 2011. Operating results for the nine month period of 2012 were impacted by an unrealized loss on derivatives of $119.4 million; an unfavorable impact from FIFO accounting of $32.9 million; major turnaround expenses of $21.1 million; and expenses associated with proxy matters of $26.8 million, all net of taxes.
“Strong operating performance from our refineries in the third quarter allowed us to take advantage of wide Group 3 crack spreads driven by favorable differentials between Brent and WTI crudes and local market conditions,” said Jack Lipinski, CVR Energy’s chief executive officer. “This quarter CVR Energy posted its best-ever net income for any quarter since the company went public in October 2007. Our petroleum segment also set new records with third quarter operating income of $507.5 million and a new crude gathering milestone of an average 47,513 barrels gathered during the quarter.
“Our nitrogen fertilizer segment continues to be supported by strong operating performance and solid industry fundamentals, as well,” he said. “CVR Partners recently announced a third quarter cash distribution of 49.6 cents per common unit.”
Petroleum Business
The petroleum business, which includes the Coffeyville and Wynnewood refineries, reported record third quarter 2012 operating income of $507.5 million, and adjusted EBITDA, a non-
GAAP financial measure, of $444.2 million, on net sales of $2,337.3 million, compared to operating income in the same quarter a year earlier of $179.8 million, and adjusted EBITDA of $232.0 million, on net sales of $1,284.4 million.
Third quarter 2012 throughput of crude oil and all other feedstocks and blendstocks totaled 203,038 barrels per day (bpd), compared to 116,091 bpd for the same period in 2011. Crude oil throughput for the third quarter 2012 averaged 192,563 bpd per day compared with 112,885 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 $33.44 in the third quarter 2012 compared to $27.55 during the same period in 2011. Gross profit per crude oil throughput barrel was $29.75 in the third quarter 2012, as compared to $18.14 during the same period in 2011.
Direct operating expenses, including major scheduled turnaround expenses, per barrel sold, exclusive of depreciation and amortization, for the third quarter 2012 was $4.81, down from $5.19 in the third quarter 2011.
Coffeyville Refinery
The Coffeyville refinery reported third quarter 2012 operating income of $353.6 million, compared to $180.3 million of operating income for the third quarter of 2011. Third quarter 2012 crude oil throughput totaled 124,643 bpd, compared to 112,885 bpd in the third quarter of 2011. Refining margin adjusted for FIFO impact per crude oil throughput barrel for the third quarter of 2012 was $33.56 compared to $27.54 for the same period in 2011. Gross profit per crude oil throughput barrel was $31.76 in the third quarter of 2012, compared to $18.19 for the 2011 third quarter. Direct operating expenses, including major scheduled turnaround expenses, per barrel sold for the 2012 third quarter was $3.83, compared to $5.19 for the 2011 third quarter.
Wynnewood Refinery
CVR Energy acquired the Wynnewood refinery in December 2011. The 2012 third quarter represents the refinery’s third full quarter as a CVR Energy subsidiary.
For the third quarter of 2012, the refinery’s crude oil throughput totaled 67,920 bpd. The refinery’s third quarter 2012 operating income was $154.4 million. Refining margin adjusted for FIFO impact per crude oil throughput barrel for the third quarter of 2012 was $33.07. Direct operating expenses, including major scheduled turnaround expenses, per barrel sold for the third quarter was $6.54.
Nitrogen Fertilizers Business
The fertilizer business operated by CVR Partners, LP reported third quarter 2012 operating income of $32.3 million, and adjusted EBITDA, a non-GAAP financial measure, of $39.0 million, on net sales of $75.0 million, compared to operating income of $37.5 million, and adjusted EBITDA of $43.3 million, on net sales of $77.2 million for the 2011 third quarter.
CVR Partners produced 104,200 tons of ammonia during the third quarter of 2012, of which 29,400 net tons were available for sale while the rest was upgraded to 181,900 tons of more profitable urea ammonium nitrate (UAN). In the 2011 third quarter, the plant produced 102,700 tons of ammonia with 25,900 net tons available for sale with the remainder upgraded to 185,800 tons of UAN.
Third quarter 2012 average realized plant gate prices for ammonia and UAN were $578 per ton and $290 per ton, respectively, as compared to $568 per ton and $294 per ton, respectively, for the same period in 2011.
Cash and Debt
Consolidated cash and cash equivalents, which included $180.3 million for CVR Partners, increased to $988.2 million at the end of the 2012 third quarter, compared to $692.6 million at the end of the second quarter of 2012, primarily due to increased cash flows in the petroleum business. Consolidated long-term debt at the end of the 2012 third quarter, which included $125.0 million for CVR Partners, remained nearly unchanged at $850.9 million.
CVR Energy Third Quarter 2012 Earnings Conference Call Information
CVR Energy previously announced that it will host its third quarter 2012 Earnings Conference Call for analysts and investors on Tuesday, Nov. 6, at 2 p.m. Eastern.
The call will be broadcast live over the Internet at http://www.videonewswire.com/event.asp?id=89676. For investors or analysts who want to participate during the call, the dial-in number is (877) 407-8291.
For those unable to listen live, the Webcast will be archived and available for 28 days at http://www.videonewswire.com/event.asp?id=89676. A repeat of the conference call can be accessed by dialing (877) 660-6853, conference ID 400979.
# # #
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, Missouri, Oklahoma, 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).
|
|
|
Three Months Ended |
|
Change from 2011 |
| |||||||
|
|
|
2012 |
|
2011 |
|
Change |
|
Percent |
| |||
|
|
|
(in millions, except per share data) |
| |||||||||
|
Consolidated Statement of Operations Data: |
|
|
|
|
|
|
|
|
| |||
|
Net sales |
|
$ |
2,409.6 |
|
$ |
1,352.0 |
|
$ |
1,057.6 |
|
78.2 |
% |
|
Cost of product sold |
|
1,702.5 |
|
1,026.0 |
|
676.5 |
|
65.9 |
| |||
|
Direct operating expenses |
|
109.9 |
|
74.6 |
|
35.3 |
|
47.3 |
| |||
|
Insurance recovery — business interruption |
|
— |
|
(0.5 |
) |
0.5 |
|
(100.0 |
) | |||
|
Selling, general and administrative expenses |
|
30.4 |
|
17.7 |
|
12.7 |
|
71.8 |
| |||
|
Depreciation and amortization |
|
33.1 |
|
22.0 |
|
11.1 |
|
50.5 |
| |||
|
Operating income |
|
533.7 |
|
212.2 |
|
321.5 |
|
151.5 |
| |||
|
Interest expense and other financing costs |
|
(18.9 |
) |
(13.8 |
) |
(5.1 |
) |
37.0 |
| |||
|
Gain (loss) on derivatives, net |
|
|
|
|
|
|
|
|
| |||
|
Realized |
|
(53.2 |
) |
0.1 |
|
(53.3 |
) |
(53,300.0 |
) | |||
|
Unrealized |
|
(115.7 |
) |
(10.0 |
) |
(105.7 |
) |
1,057.0 |
| |||
|
Other income, net |
|
0.2 |
|
0.4 |
|
(0.2 |
) |
(50.0 |
) | |||
|
Income before income tax expense |
|
346.1 |
|
188.9 |
|
157.2 |
|
83.2 |
| |||
|
Income tax expense |
|
127.6 |
|
68.6 |
|
59.0 |
|
86.0 |
| |||
|
Net income |
|
218.5 |
|
120.3 |
|
98.2 |
|
81.6 |
| |||
|
Net income attributable to noncontrolling interest |
|
9.6 |
|
11.0 |
|
(1.4 |
) |
(12.7 |
) | |||
|
Net income attributable to CVR Energy stockholders |
|
$ |
208.9 |
|
$ |
109.3 |
|
$ |
99.6 |
|
91.1 |
% |
|
|
|
|
|
|
|
|
|
|
| |||
|
Basic earnings per share |
|
$ |
2.41 |
|
$ |
1.26 |
|
$ |
1.15 |
|
91.3 |
% |
|
Diluted earnings per share |
|
$ |
2.41 |
|
$ |
1.25 |
|
$ |
1.16 |
|
92.8 |
% |
|
|
|
|
|
|
|
|
|
|
| |||
|
Adjusted net income |
|
$ |
260.2 |
|
$ |
137.4 |
|
$ |
122.8 |
|
89.4 |
% |
|
Adjusted net income, per diluted share |
|
$ |
3.00 |
|
$ |
1.57 |
|
$ |
1.43 |
|
91.1 |
% |
|
|
|
|
|
|
|
|
|
|
| |||
|
Weighted-average common shares outstanding: |
|
|
|
|
|
|
|
|
| |||
|
Basic |
|
86,831,050 |
|
86,549,846 |
|
281,204 |
|
0.3 |
% | |||
|
Diluted |
|
86,831,050 |
|
87,743,600 |
|
(912,550 |
) |
(1.0 |
)% | |||
|
|
|
Nine Months Ended |
|
Change from 2011 |
| |||||||
|
|
|
2012 |
|
2011 |
|
Change |
|
Percent |
| |||
|
|
|
(in millions, except per share data) |
| |||||||||
|
Consolidated Statement of Operations Data: |
|
|
|
|
|
|
|
|
| |||
|
Net sales |
|
$ |
6,686.5 |
|
$ |
3,966.9 |
|
$ |
2,719.6 |
|
68.6 |
% |
|
Cost of product sold |
|
5,211.9 |
|
3,086.2 |
|
2,125.7 |
|
68.9 |
| |||
|
Direct operating expenses |
|
319.5 |
|
209.3 |
|
110.2 |
|
52.7 |
| |||
|
Insurance recovery — business interruption |
|
— |
|
(3.4 |
) |
3.4 |
|
(100.0 |
) | |||
|
Selling, general and administrative expenses |
|
147.7 |
|
69.0 |
|
78.7 |
|
114.1 |
| |||
|
Depreciation and amortization |
|
97.4 |
|
66.1 |
|
31.3 |
|
47.4 |
| |||
|
Operating income |
|
910.0 |
|
539.7 |
|
370.3 |
|
68.6 |
| |||
|
Interest expense and other financing costs |
|
(57.1 |
) |
(41.2 |
) |
(15.9 |
) |
38.6 |
| |||
|
Gain (loss) on derivatives, net |
|
|
|
|
|
|
|
|
| |||
|
Realized |
|
(80.4 |
) |
(18.3 |
) |
(62.1 |
) |
339.3 |
| |||
|
Unrealized |
|
(197.0 |
) |
(6.8 |
) |
(190.2 |
) |
2,797.1 |
| |||
|
Loss on extinguishment of debt |
|
— |
|
(2.1 |
) |
2.1 |
|
(100.0 |
) | |||
|
Other income, net |
|
1.3 |
|
1.4 |
|
(0.1 |
) |
(7.1 |
) | |||
|
Income before income tax expense |
|
576.8 |
|
472.7 |
|
104.1 |
|
22.0 |
| |||
|
Income tax expense |
|
209.0 |
|
172.5 |
|
36.5 |
|
21.2 |
| |||
|
Net income |
|
367.8 |
|
300.2 |
|
67.6 |
|
22.5 |
| |||
|
Net income attributable to noncontrolling interest |
|
29.4 |
|
20.3 |
|
9.1 |
|
44.8 |
| |||
|
Net income attributable to CVR Energy stockholders |
|
$ |
338.4 |
|
$ |
279.9 |
|
$ |
58.5 |
|
20.9 |
% |
|
|
|
|
|
|
|
|
|
|
| |||
|
Basic earnings per share |
|
$ |
3.90 |
|
$ |
3.24 |
|
$ |
0.66 |
|
20.4 |
% |
|
Diluted earnings per share |
|
$ |
3.86 |
|
$ |
3.19 |
|
$ |
0.67 |
|
21.0 |
% |
|
|
|
|
|
|
|
|
|
|
| |||
|
Adjusted net income |
|
$ |
562.1 |
|
$ |
310.9 |
|
$ |
251.2 |
|
80.8 |
% |
|
Adjusted net income, per diluted share |
|
$ |
6.42 |
|
$ |
3.54 |
|
$ |
2.88 |
|
81.4 |
% |
|
|
|
|
|
|
|
|
|
|
| |||
|
Weighted-average common shares outstanding: |
|
|
|
|
|
|
|
|
| |||
|
Basic |
|
86,820,181 |
|
86,462,668 |
|
357,513 |
|
0.4 |
% | |||
|
Diluted |
|
87,580,588 |
|
87,772,169 |
|
(191,581 |
) |
(0.2 |
)% | |||
|
|
|
As of September 30, |
|
As of December 31, |
| ||
|
|
|
2012 |
|
2011 |
| ||
|
|
|
|
|
(audited) |
| ||
|
|
|
(in millions) |
| ||||
|
Balance Sheet Data: |
|
|
|
|
| ||
|
Cash and cash equivalents |
|
$ |
988.2 |
|
$ |
388.3 |
|
|
Working capital |
|
1,137.7 |
|
769.2 |
| ||
|
Total assets |
|
3,652.4 |
|
3,119.3 |
| ||
|
Long-term debt |
|
850.9 |
|
853.9 |
| ||
|
Total CVR stockholders’ equity |
|
1,485.1 |
|
1,151.6 |
| ||
|
|
|
Three Months Ended |
|
Nine Months Ended |
| ||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
| ||||
|
|
|
(in millions) |
| ||||||||||
|
Cash Flow Data |
|
|
|
|
|
|
|
|
| ||||
|
Net cash flow provided by (used in): |
|
|
|
|
|
|
|
|
| ||||
|
Operating activities |
|
$ |
347.9 |
|
$ |
183.3 |
|
$ |
783.8 |
|
$ |
345.9 |
|
|
Investing activities |
|
(38.8 |
) |
(23.1 |
) |
(143.6 |
) |
(43.8 |
) | ||||
|
Financing activities |
|
(13.5 |
) |
(9.7 |
) |
(40.3 |
) |
396.3 |
| ||||
|
Net cash flow |
|
$ |
295.6 |
|
$ |
150.5 |
|
$ |
599.9 |
|
$ |
698.4 |
|
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 September 30, 2012 are included in CVR Partners’ press release dated November 5, 2012.
|
|
|
Petroleum |
|
Nitrogen |
|
Corporate |
|
Consolidated |
| ||||
|
|
|
(in millions) |
| ||||||||||
|
Three months ended September 30, 2012 |
|
|
|
|
|
|
|
|
| ||||
|
Net sales |
|
$ |
2,337.3 |
|
$ |
75.0 |
|
$ |
(2.7 |
) |
$ |
2,409.6 |
|
|
Cost of product sold |
|
1,694.0 |
|
11.3 |
|
(2.8 |
) |
1,702.5 |
| ||||
|
Direct operating expenses (1) |
|
77.7 |
|
20.9 |
|
— |
|
98.6 |
| ||||
|
Major scheduled turnaround expense |
|
11.1 |
|
0.2 |
|
— |
|
11.3 |
| ||||
|
Selling, general & administrative |
|
19.5 |
|
5.1 |
|
5.8 |
|
30.4 |
| ||||
|
Depreciation and amortization |
|
27.5 |
|
5.2 |
|
0.4 |
|
33.1 |
| ||||
|
Operating income (loss) |
|
$ |
507.5 |
|
$ |
32.3 |
|
$ |
(6.1 |
) |
$ |
533.7 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Capital expenditures |
|
$ |
20.2 |
|
$ |
18.2 |
|
$ |
1.5 |
|
$ |
39.9 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Nine months ended September 30, 2012 |
|
|
|
|
|
|
|
|
| ||||
|
Net sales |
|
$ |
6,465.3 |
|
$ |
234.7 |
|
$ |
(13.5 |
) |
$ |
6,686.5 |
|
|
Cost of product sold |
|
5,190.8 |
|
34.6 |
|
(13.5 |
) |
5,211.9 |
| ||||
|
Direct operating expenses (1) |
|
218.5 |
|
66.2 |
|
— |
|
284.7 |
| ||||
|
Major scheduled turnaround expense |
|
34.6 |
|
0.2 |
|
— |
|
34.8 |
| ||||
|
Selling, general & administrative |
|
49.8 |
|
18.1 |
|
79.8 |
|
147.7 |
| ||||
|
Depreciation and amortization |
|
80.4 |
|
15.8 |
|
1.2 |
|
97.4 |
| ||||
|
Operating income (loss) |
|
$ |
891.2 |
|
$ |
99.8 |
|
$ |
(81.0 |
) |
$ |
910.0 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Capital expenditures |
|
$ |
82.6 |
|
$ |
57.4 |
|
$ |
5.1 |
|
$ |
145.1 |
|
|
|
|
Petroleum |
|
Nitrogen |
|
Corporate |
|
Consolidated |
| ||||
|
|
|
(in millions) |
| ||||||||||
|
Three months ended September 30, 2011 |
|
|
|
|
|
|
|
|
| ||||
|
Net sales |
|
$ |
1,284.4 |
|
$ |
77.2 |
|
$ |
(9.6 |
) |
$ |
1,352.0 |
|
|
Cost of product sold |
|
1,024.5 |
|
10.9 |
|
(9.4 |
) |
1,026.0 |
| ||||
|
Direct operating expenses (1) |
|
46.5 |
|
20.1 |
|
— |
|
66.6 |
| ||||
|
Major scheduled turnaround expense |
|
8.0 |
|
— |
|
— |
|
8.0 |
| ||||
|
Insurance recovery – business interruption |
|
— |
|
(0.5 |
) |
— |
|
(0.5 |
) | ||||
|
Selling, general & administrative |
|
8.6 |
|
4.5 |
|
4.6 |
|
17.7 |
| ||||
|
Depreciation and amortization |
|
17.0 |
|
4.7 |
|
0.3 |
|
22.0 |
| ||||
|
Operating income (loss) |
|
$ |
179.8 |
|
$ |
37.5 |
|
$ |
(5.1 |
) |
$ |
212.2 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Capital expenditures |
|
$ |
20.2 |
|
$ |
4.5 |
|
$ |
1.0 |
|
$ |
25.7 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Nine months ended September 30, 2011 |
|
|
|
|
|
|
|
|
| ||||
|
Net sales |
|
$ |
3,772.3 |
|
$ |
215.3 |
|
$ |
(20.7 |
) |
$ |
3,966.9 |
|
|
Cost of product sold |
|
3,077.5 |
|
28.2 |
|
(19.5 |
) |
3,086.2 |
| ||||
|
Direct operating expenses (1) |
|
131.8 |
|
65.4 |
|
(0.1 |
) |
197.1 |
| ||||
|
Major scheduled turnaround expense |
|
12.2 |
|
— |
|
— |
|
12.2 |
| ||||
|
Insurance recovery — business interruption |
|
— |
|
(3.4 |
) |
— |
|
(3.4 |
) | ||||
|
Selling, general & administrative |
|
30.9 |
|
17.6 |
|
20.5 |
|
69.0 |
| ||||
|
Depreciation and amortization |
|
50.9 |
|
13.9 |
|
1.3 |
|
66.1 |
| ||||
|
Operating income (loss) |
|
$ |
469.0 |
|
$ |
93.6 |
|
$ |
(22.9 |
) |
$ |
539.7 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Capital expenditures |
|
$ |
33.4 |
|
$ |
10.5 |
|
$ |
2.7 |
|
$ |
46.6 |
|
(1) Excluding turnaround expenses.
|
|
|
Petroleum |
|
Nitrogen |
|
Corporate |
|
Consolidated |
| ||||
|
|
|
(in millions) |
| ||||||||||
|
September 30, 2012 |
|
|
|
|
|
|
|
|
| ||||
|
Cash and cash equivalents (1) |
|
$ |
— |
|
$ |
180.3 |
|
$ |
807.9 |
|
$ |
988.2 |
|
|
Total assets |
|
2,189.0 |
|
653.2 |
|
810.2 |
|
3,652.4 |
| ||||
|
Long-term debt (1) |
|
— |
|
125.0 |
|
725.9 |
|
850.9 |
| ||||
|
|
|
|
|
|
|
|
|
|
| ||||
|
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 |
|
Nine Months Ended |
| ||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
| ||||
|
|
|
(in millions, except operating statistics) |
| ||||||||||
|
Petroleum Segment Summary Financial Results: |
|
|
|
|
|
|
|
|
| ||||
|
Net sales |
|
$ |
2,337.3 |
|
$ |
1,284.4 |
|
$ |
6,465.3 |
|
$ |
3,772.3 |
|
|
Cost of product sold |
|
1,694.0 |
|
1,024.5 |
|
5,190.8 |
|
3,077.5 |
| ||||
|
Refining margin* |
|
643.3 |
|
259.9 |
|
1,274.5 |
|
694.8 |
| ||||
|
Direct operating expenses |
|
77.7 |
|
46.5 |
|
218.5 |
|
131.8 |
| ||||
|
Major scheduled turnaround expense |
|
11.1 |
|
8.0 |
|
34.6 |
|
12.2 |
| ||||
|
Depreciation and amortization |
|
27.5 |
|
17.0 |
|
80.4 |
|
50.9 |
| ||||
|
Gross profit |
|
527.0 |
|
188.4 |
|
941.0 |
|
499.9 |
| ||||
|
Selling, general and administrative expenses |
|
19.5 |
|
8.6 |
|
49.8 |
|
30.9 |
| ||||
|
Operating income |
|
$ |
507.5 |
|
$ |
179.8 |
|
$ |
891.2 |
|
$ |
469.0 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Refining margin adjusted for FIFO impact* |
|
$ |
592.4 |
|
$ |
286.1 |
|
$ |
1,328.8 |
|
$ |
696.3 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Adjusted Petroleum EBITDA* |
|
$ |
444.2 |
|
$ |
232.0 |
|
$ |
989.7 |
|
$ |
525.2 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Petroleum Segment Key Operating Statistics: |
|
|
|
|
|
|
|
|
| ||||
|
Per crude oil throughput barrel: |
|
|
|
|
|
|
|
|
| ||||
|
Refining margin* |
|
$ |
36.31 |
|
$ |
25.03 |
|
$ |
26.34 |
|
$ |
23.77 |
|
|
FIFO impact (favorable) unfavorable |
|
(2.87 |
) |
2.52 |
|
1.12 |
|
0.05 |
| ||||
|
Refining margin adjusted for FIFO impact* |
|
33.44 |
|
27.55 |
|
27.46 |
|
23.82 |
| ||||
|
Gross profit |
|
29.75 |
|
18.14 |
|
19.45 |
|
17.10 |
| ||||
|
Direct operating expenses and major scheduled turnaround expenses |
|
5.02 |
|
5.25 |
|
5.23 |
|
4.93 |
| ||||
|
Direct operating expenses and major scheduled turnaround expenses per barrel sold |
|
$ |
4.81 |
|
$ |
5.19 |
|
$ |
4.75 |
|
$ |
4.71 |
|
|
Barrels sold (barrels per day) |
|
200,683 |
|
114,061 |
|
194,638 |
|
111,939 |
| ||||
|
|
|
Three Months Ended |
|
Nine Months Ended |
| ||||||||||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
| ||||||||||||
|
Petroleum Segment Summary Refining Throughput and Production Data: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
(barrels per day) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Throughput: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Sweet |
|
149,768 |
|
73.8 |
% |
91,498 |
|
78.8 |
% |
136,463 |
|
73.4 |
% |
85,401 |
|
75.8 |
% | ||||
|
Light/medium sour |
|
21,188 |
|
10.4 |
% |
994 |
|
0.8 |
% |
21,708 |
|
11.7 |
% |
598 |
|
0.5 |
% | ||||
|
Heavy sour |
|
21,607 |
|
10.6 |
% |
20,393 |
|
17.6 |
% |
18,418 |
|
9.9 |
% |
21,071 |
|
18.7 |
% | ||||
|
Total crude oil throughput |
|
192,563 |
|
94.8 |
% |
112,885 |
|
97.2 |
% |
176,589 |
|
95.0 |
% |
107,070 |
|
95.0 |
% | ||||
|
All other feedstocks and blendstocks |
|
10,475 |
|
5.2 |
% |
3,206 |
|
2.8 |
% |
9,448 |
|
5.0 |
% |
5,671 |
|
5.0 |
% | ||||
|
Total throughput |
|
203,038 |
|
100.0 |
% |
116,091 |
|
100.0 |
% |
186,037 |
|
100.0 |
% |
112,741 |
|
100.0 |
% | ||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Production: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Gasoline |
|
98,016 |
|
48.5 |
% |
49,886 |
|
42.7 |
% |
92,114 |
|
49.7 |
% |
50,998 |
|
45.0 |
% | ||||
|
Distillate |
|
82,224 |
|
40.7 |
% |
50,189 |
|
43.0 |
% |
75,568 |
|
40.8 |
% |
47,368 |
|
41.8 |
% | ||||
|
Other (excluding internally produced fuel) |
|
21,928 |
|
10.8 |
% |
16,770 |
|
14.3 |
% |
17,588 |
|
9.5 |
% |
15,038 |
|
13.2 |
% | ||||
|
Total refining production (excluding internally produced fuel) |
|
202,168 |
|
100.0 |
% |
116,845 |
|
100.0 |
% |
185,270 |
|
100.0 |
% |
113,404 |
|
100.0 |
% | ||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Product price (dollars per gallon): |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Gasoline |
|
$ |
3.03 |
|
|
|
$ |
2.95 |
|
|
|
$ |
2.93 |
|
|
|
$ |
2.89 |
|
|
|
|
Distillate |
|
3.15 |
|
|
|
3.07 |
|
|
|
3.07 |
|
|
|
3.04 |
|
|
| ||||
|
|
|
Three Months Ended |
|
Nine Months Ended |
| ||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
| ||||
|
Market Indicators (dollars per barrel): |
|
|
|
|
|
|
|
|
| ||||
|
West Texas Intermediate (WTI) NYMEX |
|
$ |
92.20 |
|
$ |
89.54 |
|
$ |
96.16 |
|
$ |
95.47 |
|
|
Crude Oil Differentials: |
|
|
|
|
|
|
|
|
| ||||
|
WTI less WTS (light/medium sour) |
|
3.34 |
|
0.82 |
|
4.10 |
|
2.46 |
| ||||
|
WTI less WCS (heavy sour) |
|
15.53 |
|
14.09 |
|
21.06 |
|
17.86 |
| ||||
|
NYMEX Crack Spreads: |
|
|
|
|
|
|
|
|
| ||||
|
Gasoline |
|
31.70 |
|
32.01 |
|
29.21 |
|
26.04 |
| ||||
|
Heating Oil |
|
33.86 |
|
35.82 |
|
30.54 |
|
28.51 |
| ||||
|
NYMEX 2-1-1 Crack Spread |
|
32.78 |
|
33.92 |
|
29.87 |
|
27.27 |
| ||||
|
PADD II Group 3 Basis: |
|
|
|
|
|
|
|
|
| ||||
|
Gasoline |
|
2.22 |
|
(0.03 |
) |
(2.58 |
) |
(1.21 |
) | ||||
|
Ultra Low Sulfur Diesel |
|
2.53 |
|
2.54 |
|
2.04 |
|
2.32 |
| ||||
|
PADD II Group 3 Product Crack: |
|
|
|
|
|
|
|
|
| ||||
|
Gasoline |
|
33.92 |
|
31.98 |
|
26.63 |
|
24.82 |
| ||||
|
Ultra Low Sulfur Diesel |
|
39.38 |
|
38.36 |
|
32.58 |
|
30.82 |
| ||||
|
PADD II Group 3 2-1-1 |
|
36.65 |
|
35.17 |
|
29.60 |
|
27.82 |
| ||||
|
|
|
Three Months Ended |
|
Nine Months Ended |
| ||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
| ||||
|
|
|
(in millions, except operating statistics) |
| ||||||||||
|
Coffeyville Refinery Financial Results: |
|
|
|
|
|
|
|
|
| ||||
|
Net sales |
|
$ |
1,564.3 |
|
$ |
1,284.4 |
|
$ |
4,084.3 |
|
$ |
3,772.1 |
|
|
Cost of product sold |
|
1,135.2 |
|
1,024.6 |
|
3,268.2 |
|
3,077.7 |
| ||||
|
Refining margin* |
|
429.1 |
|
259.8 |
|
816.1 |
|
694.4 |
| ||||
|
Direct operating expenses |
|
47.3 |
|
46.5 |
|
134.7 |
|
131.7 |
| ||||
|
Turnaround expenses |
|
0.2 |
|
8.0 |
|
21.2 |
|
12.2 |
| ||||
|
Depreciation and amortization |
|
17.4 |
|
16.4 |
|
52.1 |
|
49.0 |
| ||||
|
Gross profit |
|
364.2 |
|
188.9 |
|
608.1 |
|
501.5 |
| ||||
|
Selling, general and administrative expenses |
|
10.6 |
|
8.6 |
|
34.8 |
|
29.4 |
| ||||
|
Operating income |
|
$ |
353.6 |
|
$ |
180.3 |
|
$ |
573.3 |
|
$ |
472.1 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Refining margin adjusted for FIFO impact* |
|
$ |
384.8 |
|
$ |
286.1 |
|
$ |
857.8 |
|
$ |
696.3 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Coffeyville Refinery Key Operating Statistics: |
|
|
|
|
|
|
|
|
| ||||
|
Per crude oil throughput barrel: |
|
|
|
|
|
|
|
|
| ||||
|
Refining margin* |
|
$ |
37.42 |
|
$ |
25.02 |
|
$ |
26.71 |
|
$ |
23.76 |
|
|
FIFO impact (favorable) unfavorable |
|
(3.86 |
) |
2.52 |
|
1.37 |
|
0.05 |
| ||||
|
Refining margin adjusted for FIFO impact* |
|
33.56 |
|
27.54 |
|
28.08 |
|
23.81 |
| ||||
|
Gross profit |
|
31.76 |
|
18.19 |
|
19.90 |
|
17.16 |
| ||||
|
Direct operating expenses and major scheduled turnaround expenses |
|
4.14 |
|
5.25 |
|
5.10 |
|
4.92 |
| ||||
|
Direct operating expenses and major scheduled turnaround expenses per barrel sold |
|
$ |
3.83 |
|
$ |
5.19 |
|
$ |
4.65 |
|
$ |
4.71 |
|
|
Barrels sold (barrels per day) |
|
134,873 |
|
114,061 |
|
122,482 |
|
111,939 |
| ||||
|
|
|
Three Months Ended |
|
Nine Months Ended |
| ||||||||||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
| ||||||||||||
|
Coffeyville Refinery Throughput and Production Data: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
(barrels per day) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Throughput: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Sweet |
|
100,427 |
|
76.0 |
% |
91,498 |
|
78.8 |
% |
90,871 |
|
77.0 |
% |
85,401 |
|
75.8 |
% | ||||
|
Light/medium sour |
|
2,609 |
|
2.0 |
% |
994 |
|
0.8 |
% |
2,216 |
|
1.9 |
% |
598 |
|
0.5 |
% | ||||
|
Heavy sour |
|
21,607 |
|
16.4 |
% |
20,393 |
|
17.6 |
% |
18,418 |
|
15.6 |
% |
21,071 |
|
18.7 |
% | ||||
|
Total crude oil throughput |
|
124,643 |
|
94.4 |
% |
112,885 |
|
97.2 |
% |
111,505 |
|
94.5 |
% |
107,070 |
|
95.0 |
% | ||||
|
All other feedstocks and blendstocks |
|
7,465 |
|
5.6 |
% |
3,206 |
|
2.8 |
% |
6,448 |
|
5.5 |
% |
5,671 |
|
5.0 |
% | ||||
|
Total throughput |
|
132,108 |
|
100.0 |
% |
116,091 |
|
100.0 |
% |
117,953 |
|
100.0 |
% |
112,741 |
|
100.0 |
% | ||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Production: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Gasoline |
|
63,991 |
|
47.8 |
% |
49,886 |
|
42.7 |
% |
58,889 |
|
49.2 |
% |
50,998 |
|
45.0 |
% | ||||
|
Distillate |
|
56,230 |
|
42.0 |
% |
50,189 |
|
43.0 |
% |
50,766 |
|
42.4 |
% |
47,368 |
|
41.8 |
% | ||||
|
Other (excluding internally produced fuel) |
|
13,756 |
|
10.2 |
% |
16,770 |
|
14.3 |
% |
10,014 |
|
8.4 |
% |
15,038 |
|
13.2 |
% | ||||
|
Total refining production (excluding internally produced fuel) |
|
133,977 |
|
100.0 |
% |
116,845 |
|
100.0 |
% |
119,669 |
|
100.0 |
% |
113,404 |
|
100.0 |
% | ||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Product price (dollars per gallon): |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Gasoline |
|
$ |
3.03 |
|
|
|
$ |
2.95 |
|
|
|
$ |
2.94 |
|
|
|
$ |
2.89 |
|
|
|
|
Distillate |
|
3.15 |
|
|
|
3.07 |
|
|
|
3.06 |
|
|
|
3.04 |
|
|
| ||||
|
|
|
Three Months Ended |
|
Nine Months Ended |
| ||
|
|
|
(in millions, except operating statistics) |
| ||||
|
Wynnewood Refinery Financial Results: |
|
|
|
|
| ||
|
Net sales |
|
$ |
772.8 |
|
$ |
2,380.6 |
|
|
Cost of product sold |
|
559.5 |
|
1,924.5 |
| ||
|
Refining margin* |
|
213.3 |
|
456.1 |
| ||
|
Direct operating expenses |
|
30.1 |
|
83.6 |
| ||
|
Turnaround expenses |
|
11.0 |
|
13.4 |
| ||
|
Depreciation and amortization |
|
9.0 |
|
25.7 |
| ||
|
Gross profit |
|
163.2 |
|
333.4 |
| ||
|
Selling, general and administrative expenses |
|
8.8 |
|
14.3 |
| ||
|
Operating income |
|
$ |
154.4 |
|
$ |
319.1 |
|
|
|
|
|
|
|
| ||
|
Refining margin adjusted for FIFO impact* |
|
$ |
206.7 |
|
$ |
468.7 |
|
|
|
|
|
|
|
| ||
|
Wynnewood Refinery Key Operating Statistics: |
|
|
|
|
| ||
|
Per crude oil throughput barrel: |
|
|
|
|
| ||
|
Refining margin* |
|
$ |
34.13 |
|
$ |
25.58 |
|
|
FIFO impact (favorable) unfavorable |
|
(1.06 |
) |
0.70 |
| ||
|
Refining margin adjusted for FIFO impact* |
|
33.07 |
|
26.28 |
| ||
|
Gross profit |
|
26.12 |
|
18.70 |
| ||
|
Direct operating expenses and major scheduled turnaround expenses |
|
6.58 |
|
5.44 |
| ||
|
Direct operating expenses and major scheduled turnaround expenses per barrel sold |
|
$ |
6.54 |
|
$ |
4.91 |
|
|
Barrels sold (barrels per day) |
|
68,311 |
|
72,087 |
| ||
|
|
|
Three Months Ended |
|
Nine Months Ended |
| ||||||
|
|
|
|
|
% |
|
|
|
% |
| ||
|
Wynnewood Refinery Throughput and Production Data: |
|
|
|
|
|
|
|
|
| ||
|
(barrels per day) |
|
|
|
|
|
|
|
|
| ||
|
Throughput: |
|
|
|
|
|
|
|
|
| ||
|
Sweet |
|
49,341 |
|
69.6 |
% |
45,592 |
|
67.0 |
% | ||
|
Light/medium sour |
|
18,579 |
|
26.2 |
% |
19,492 |
|
28.6 |
% | ||
|
Heavy sour |
|
— |
|
— |
% |
— |
|
— |
% | ||
|
Total crude oil throughput |
|
67,920 |
|
95.8 |
% |
65,084 |
|
95.6 |
% | ||
|
All other feedstocks and blendstocks |
|
3,010 |
|
4.2 |
% |
3,000 |
|
4.4 |
% | ||
|
Total throughput |
|
70,930 |
|
100.0 |
% |
68,084 |
|
100.0 |
% | ||
|
|
|
|
|
|
|
|
|
|
| ||
|
Production: |
|
|
|
|
|
|
|
|
| ||
|
Gasoline |
|
34,025 |
|
49.9 |
% |
33,225 |
|
50.7 |
% | ||
|
Distillate |
|
25,994 |
|
38.1 |
% |
24,802 |
|
37.8 |
% | ||
|
Other (excluding internally produced fuel) |
|
8,172 |
|
12.0 |
% |
7,574 |
|
11.5 |
% | ||
|
Total refining production (excluding internally produced fuel) |
|
68,191 |
|
100.0 |
% |
65,601 |
|
100.0 |
% | ||
|
|
|
|
|
|
|
|
|
|
| ||
|
Product price (dollars per gallon): |
|
|
|
|
|
|
|
|
| ||
|
Gasoline |
|
$ |
3.02 |
|
|
|
$ |
2.93 |
|
|
|
|
Distillate |
|
3.13 |
|
|
|
3.08 |
|
|
| ||
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 September 30, 2012 are included in CVR Partners’ press release dated November 5, 2012.
|
|
|
Three Months Ended |
|
Nine Months Ended |
| ||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
| ||||
|
|
|
(in millions, except as noted) |
| ||||||||||
|
Nitrogen Fertilizer Segment Financial Results: |
|
|
|
|
|
|
|
|
| ||||
|
Net sales |
|
$ |
75.0 |
|
$ |
77.2 |
|
$ |
234.7 |
|
$ |
215.3 |
|
|
Cost of product sold |
|
11.3 |
|
10.9 |
|
34.6 |
|
28.2 |
| ||||
|
Direct operating expenses |
|
21.1 |
|
20.1 |
|
66.4 |
|
65.4 |
| ||||
|
Insurance recovery — business interruption |
|
— |
|
(0.5 |
) |
— |
|
(3.4 |
) | ||||
|
Selling, general and administrative expenses |
|
5.1 |
|
4.5 |
|
18.1 |
|
17.6 |
| ||||
|
Depreciation and amortization |
|
5.2 |
|
4.7 |
|
15.8 |
|
13.9 |
| ||||
|
|
|
|
|
|
|
|
|
|
| ||||
|
Operating income |
|
$ |
32.3 |
|
$ |
37.5 |
|
$ |
99.8 |
|
$ |
93.6 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Adjusted Nitrogen Fertilizer EBITDA* |
|
$ |
39.0 |
|
$ |
43.3 |
|
$ |
121.1 |
|
$ |
114.0 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
|
|
Three Months Ended |
|
Nine Months Ended |
| ||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
| ||||
|
|
|
(in millions, except as noted) |
| ||||||||||
|
Nitrogen Fertilizer Segment Key Operating Statistics: |
|
|
|
|
|
|
|
|
| ||||
|
Production (thousand tons): |
|
|
|
|
|
|
|
|
| ||||
|
Ammonia (gross produced) (1) |
|
104.2 |
|
102.7 |
|
302.3 |
|
310.4 |
| ||||
|
Ammonia (net available for sale) (1) |
|
29.4 |
|
25.9 |
|
89.3 |
|
89.3 |
| ||||
|
UAN |
|
181.9 |
|
185.8 |
|
516.5 |
|
535.8 |
| ||||
|
|
|
|
|
|
|
|
|
|
| ||||
|
Petroleum coke consumed (thousand tons) |
|
126.9 |
|
131.2 |
|
377.7 |
|
391.0 |
| ||||
|
Petroleum coke (cost per ton) |
|
$ |
30 |
|
$ |
43 |
|
$ |
34 |
|
$ |
30 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Sales (thousand tons): |
|
|
|
|
|
|
|
|
| ||||
|
Ammonia |
|
30.2 |
|
22.6 |
|
89.5 |
|
83.5 |
| ||||
|
UAN |
|
175.1 |
|
179.2 |
|
510.5 |
|
524.7 |
| ||||
|
|
|
|
|
|
|
|
|
|
| ||||
|
Product pricing (plant gate) (dollars per ton) (2): |
|
|
|
|
|
|
|
|
| ||||
|
Ammonia |
|
$ |
578 |
|
$ |
568 |
|
$ |
586 |
|
$ |
569 |
|
|
UAN |
|
$ |
290 |
|
$ |
294 |
|
$ |
311 |
|
$ |
266 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
On-stream factors (3): |
|
|
|
|
|
|
|
|
| ||||
|
Gasification |
|
99.1 |
% |
99.2 |
% |
97.2 |
% |
99.5 |
% | ||||
|
Ammonia |
|
98.4 |
% |
98.6 |
% |
96.0 |
% |
98.0 |
% | ||||
|
UAN |
|
96.9 |
% |
97.0 |
% |
92.4 |
% |
95.9 |
% | ||||
|
|
|
|
|
|
|
|
|
|
| ||||
|
Market Indicators: |
|
|
|
|
|
|
|
|
| ||||
|
Ammonia — Southern Plains (dollars per ton) |
|
$ |
677 |
|
$ |
619 |
|
$ |
616 |
|
$ |
609 |
|
|
UAN — Mid Cornbelt (dollars per ton) |
|
$ |
356 |
|
$ |
401 |
|
$ |
372 |
|
$ |
373 |
|
* 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 |
|
Nine 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 |
|
$ |
208.9 |
|
$ |
109.3 |
|
$ |
338.4 |
|
$ |
279.9 |
|
|
Adjustments (all net of taxes): |
|
|
|
|
|
|
|
|
| ||||
|
FIFO impact (favorable) unfavorable |
|
(30.9 |
) |
15.8 |
|
32.9 |
|
0.9 |
| ||||
|
Share-based compensation |
|
4.0 |
|
1.5 |
|
17.3 |
|
16.5 |
| ||||
|
Loss on extinguishment of debt |
|
— |
|
— |
|
— |
|
1.2 |
| ||||
|
Major scheduled turnaround expense |
|
6.9 |
|
4.8 |
|
21.1 |
|
7.4 |
| ||||
|
Loss on disposition of fixed assets |
|
— |
|
— |
|
— |
|
0.9 |
| ||||
|
Unrealized (gain) loss on derivatives |
|
70.1 |
|
6.0 |
|
119.4 |
|
4.1 |
| ||||
|
Expenses associated with proxy matters |
|
— |
|
— |
|
26.8 |
|
— |
| ||||
|
Expenses associated with the acquisition of Gary-Williams (1) |
|
1.2 |
|
— |
|
6.2 |
|
— |
| ||||
|
Adjusted net income |
|
$ |
260.2 |
|
$ |
137.4 |
|
$ |
562.1 |
|
$ |
310.9 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
Adjusted net income per diluted share |
|
$ |
3.00 |
|
$ |
1.57 |
|
$ |
6.42 |
|
$ |
3.54 |
|
(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 nine months ended September 30, 2012 and 2011:
|
|
|
Three Months Ended |
|
Nine Months Ended |
| ||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
| ||||
|
|
|
(in millions) |
| ||||||||||
|
Petroleum: |
|
|
|
|
|
|
|
|
| ||||
|
Petroleum operating income |
|
$ |
507.5 |
|
$ |
179.8 |
|
$ |
891.2 |
|
$ |
469.0 |
|
|
FIFO impacts (favorable) unfavorable |
|
(50.9 |
) |
26.2 |
|
54.3 |
|
1.5 |
| ||||
|
Share-based compensation |
|
2.3 |
|
0.8 |
|
8.8 |
|
8.0 |
| ||||
|
Major scheduled turnaround expenses |
|
11.1 |
|
8.0 |
|
34.6 |
|
12.2 |
| ||||
|
Loss on disposition of fixed assets |
|
— |
|
— |
|
— |
|
1.5 |
| ||||
|
Realized gain (loss) on derivatives, net |
|
(53.3 |
) |
0.1 |
|
(80.4 |
) |
(18.3 |
) | ||||
|
Depreciation and amortization |
|
27.5 |
|
17.0 |
|
80.4 |
|
50.9 |
| ||||
|
Other income |
|
— |
|
0.1 |
|
0.8 |
|
0.4 |
| ||||
|
Adjusted Petroleum EBITDA |
|
$ |
444.2 |
|
$ |
232.0 |
|
$ |
989.7 |
|
$ |
525.2 |
|
|
|
|
|
|
|
|
|
|
|
| ||||
|
|
|
Three Months Ended |
|
Nine Months Ended |
| ||||||||
|
|
|
2012 |
|
2011 |
|
2012 |
|
2011 |
| ||||
|
|
|
(in millions) |
| ||||||||||
|
Nitrogen Fertilizer: |
|
|
|
|
|
|
|
|
| ||||
|
Nitrogen Fertilizer operating income |
|
$ |
32.3 |
|
$ |
37.5 |
|
$ |
99.8 |
|
$ |
93.6 |
|
|
Share-based compensation |
|
1.2 |
|
0.9 |
|
5.2 |
|
6.4 |
| ||||
|
Depreciation and amortization |
|
5.2 |
|
4.7 |
|
15.8 |
|
13.9 |
| ||||
|
Major scheduled turnaround expense |
|
0.2 |
|
— |
|
0.2 |
|
— |
| ||||
|
Other income, net |
|
0.1 |
|
0.2 |
|
0.1 |
|
0.1 |
| ||||
|
Adjusted Nitrogen Fertilizer EBITDA |
|
$ |
39.0 |
|
$ |
43.3 |
|
$ |
121.1 |
|
$ |
114.0 |
|
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 September 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.
|
Commodity Swaps |
|
Barrels |
|
Fixed Price(1) |
| |
|
Fourth Quarter 2012 |
|
5,850,000 |
|
$ |
23.50 |
|
|
|
|
|
|
|
| |
|
First Quarter 2013 |
|
6,375,000 |
|
24.95 |
| |
|
Second Quarter 2013 |
|
5,400,000 |
|
26.85 |
| |
|
Third Quarter 2013 |
|
5,175,000 |
|
25.31 |
| |
|
Fourth Quarter 2013 |
|
3,525,000 |
|
24.66 |
| |
|
|
|
|
|
|
| |
|
Total |
|
26,325,000 |
|
$ |
25.05 |
|
(1) Weighted-average price of all positions for period indicated.