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February 19, 2020 at 4:15 PM EST

CVR Energy Reports Fourth Quarter and Full-Year 2019 Results and Announces Cash Dividend of 80 Cents

  • Achieved year-over-year environmental, health and safety improvements.
  • Completed Wynnewood’s BenFree repositioning project.
  • Received Board approval for Wynnewood’s Isomerization project. 
  • Increased cash dividend to $3.20 per share annualized for an industry-leading dividend yield.

SUGAR LAND, Texas, Feb. 19, 2020 (GLOBE NEWSWIRE) -- CVR Energy, Inc. (NYSE: CVI) today announced fourth quarter 2019 net income of $44 million, or 44 cents per diluted share, on net sales of $1.6 billion, compared to net income of $73 million, or 73 cents per diluted share, on net sales of $1.7 billion for the fourth quarter of 2018. Fourth quarter 2019 EBITDA was $142 million, compared to fourth quarter 2018 EBITDA of $202 million.

For full-year 2019, the Company reported net income of $380 million, or $3.78 per diluted share, on net sales of $6.4 billion, compared to net income for full-year 2018 of $259 million, or $2.80 per diluted share, on net sales of $7.1 billion. Full-year 2019 EBITDA was $880 million, compared to $821 million for 2018.

“CVR Energy delivered solid 2019 full-year and fourth quarter results, led by continuous improvement in our core values of environmental, health and safety across both our petroleum and nitrogen fertilizer segments,” said Dave Lamp, CVR Energy’s Chief Executive Officer. “Our petroleum business again posted increased earnings year-over-year, driven by higher throughput rates, increased capture rates and higher refining margins despite lower crack spreads. In addition, we began our multi-year approach intended to improve crude oil optionality, market capture and reliability at our refineries.

“CVR Partners achieved year-over-year increases in net income and EBITDA and benefited from higher fertilizer sales volumes and stronger product pricing in 2019,” Lamp said. “As a result, CVR Partners distributed a total of 40 cents per unit during 2019 despite poor weather during the year, which impacted market conditions. Looking forward, we anticipate strong demand for spring nitrogen fertilizer application and currently expect 92 million to 95 million acres of corn to be planted this year.” 

Petroleum

The Petroleum Segment reported fourth quarter 2019 operating income of $82 million, on net sales of $1.5 billion, compared to operating income of $122 million, on net sales of $1.6 billion in the fourth quarter of 2018.

Refining margin per total throughput barrel was $12.47 in the fourth quarter 2019, compared to $13.67 during the same period in 2018. Crude oil pricing during the quarter led to a favorable inventory valuation impact of $12 million, or 61 cents per total throughput barrel, compared to an unfavorable impact of $77 million, or $3.80 per total throughput barrel, in the fourth quarter of 2018. The Petroleum Segment also recognized a fourth quarter 2019 derivative loss of $19 million, or 99 cents per total throughput barrel, compared to a gain of $70 million, or $3.45 per total throughput barrel, for the fourth quarter of 2018. Included in the total derivative loss for the fourth quarter of 2019 was an unrealized loss of $24 million, compared to an unrealized gain of $37 million for the fourth quarter of 2018.

Fourth quarter 2019 combined total throughput was approximately 213,000 barrels per day (bpd), compared to approximately 221,000 bpd of combined total throughput for the fourth quarter 2018. 

For full-year 2019, operating income was $574 million, on net sales of $6.0 billion, compared to operating income of $544 million, on net sales of $6.8 billion for the year ended 2018.

The Petroleum Segment’s refining margin per total throughput barrel for 2019 was $15.26, compared to $15.18 for 2018. This year-over-year increase was driven in part by lower renewable identification number (RIN) expenses resulting from a reduction in market prices. In addition, operating income in the Petroleum segment was positively impacted by a $9 million gain on sale of the Cushing, Oklahoma, crude oil terminal. Combined total throughput increased to approximately 216,000 bpd, compared to approximately 213,000 bpd in the year ended 2018.

Nitrogen Fertilizer

The Nitrogen Fertilizer Segment reported an operating loss of $9 million on net sales of $86 million for the fourth quarter of 2019, compared to operating income of $8 million on net sales of $98 million for the fourth quarter of 2018.

Fourth quarter 2019 average realized gate prices for urea ammonia nitrate (UAN) decreased compared to the prior year, down 2 percent to $176 per ton, while ammonia was flat at $324 per ton. Average realized gate prices for UAN and ammonia were $180 per ton and $324 per ton, respectively, for the fourth quarter of 2018.

CVR Partners’ fertilizer facilities produced a combined 180,000 tons of ammonia during the fourth quarter of 2019, of which 55,000 net tons were available for sale while the rest was upgraded to other fertilizer products, including 286,000 tons of UAN. During the fourth quarter 2018, the fertilizer facilities produced 209,000 tons of ammonia, of which 59,000 net tons were available for sale while the remainder was upgraded to other fertilizer products, including 357,000 tons of UAN.

For full-year 2019, operating income was $27 million on net sales of $404 million, compared to operating income of $6 million on net sales of $351 million for the year ended 2018.

The average realized gate price for UAN increased 15 percent to $199 per ton, coupled with a 20 percent increase in ammonia to $392 per ton for full-year 2019. Average realized gate prices for UAN and ammonia were $173 per ton and $328 per ton, respectively, for the year ended 2018. In 2019, our fertilizer facilities produced a combined 766,000 tons of ammonia, of which 223,000 tons were available for sale, while the rest was upgraded to other fertilizer products, including 1,255,000 tons of UAN. For the year ended 2018, the fertilizer facilities produced 794,000 tons of ammonia, of which 246,000 net tons were available for sale while the remainder was upgraded to other fertilizer products, including 1,276,000 tons of UAN.

Cash, Debt and Dividend

Consolidated cash and cash equivalents was $652 million at Dec. 31, 2019. Consolidated total debt was $1.2 billion at Dec. 31, 2019, with no debt other than the Petroleum and Nitrogen Fertilizer segments’ debt.

CVR Energy announced a fourth quarter 2019 cash dividend of 80 cents per share. The dividend, as declared by CVR Energy’s Board of Directors, will be paid on March 9, 2020, to stockholders of record as of the close of market on March 2, 2020. CVR Energy’s fourth quarter cash dividend brings the cumulative cash dividends declared for the 2019 full year to $3.10 per share.

CVR Partners will not pay a cash distribution for the 2019 fourth quarter.

Fourth Quarter 2019 Earnings Conference Call

CVR Energy previously announced that it will host its fourth quarter and full-year 2019 Earnings Conference Call on Thursday, Feb. 20, at 1 p.m. Eastern. This Earnings Conference Call may also include discussion of Company developments, forward-looking information and other material information about business and financial matters.

The fourth quarter and full-year 2019 Earnings Conference Call will be webcast live and can be accessed on the Investor Relations section of CVR Energy’s website at www.CVREnergy.com. For investors or analysts who want to participate during the call, the dial-in number is (877) 407-8291. The webcast will be archived and available for 14 days at https://edge.media-server.com/mmc/p/9nek858g. A repeat of the call can be accessed for 14 days by dialing (877) 660-6853, conference ID 13698196.

Forward-Looking Statements
This news release may contain forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Statements concerning current estimates, expectations and projections about future results, performance, prospects, opportunities, plans, actions and events and other statements, concerns, or matters that are not historical facts are “forward-looking statements,” as that term is defined under the federal securities laws. These forward-looking statements include, but are not limited to, statements regarding future: dividends and distributions including the timing, payment and amount (if any) thereof; improvement of crude oil optionality, market capture and reliability at our refineries; demand for spring nitrogen fertilizer application; planted corn acres; refinery throughput, direct operating expenses, capital expenditures, depreciation and amortization and turnaround expense; continued safe and reliable operations; ammonia utilization rates including impact of turnarounds; inventory adjustments; and other matters. You can generally identify forward-looking statements by our use of forward-looking terminology such as “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “explore,” “evaluate,” “intend,” “may,” “might,” “plan,” “potential,” “predict,” “seek,” “should,” or “will,” or the negative thereof or other variations thereon or comparable terminology. These forward-looking statements are only predictions and involve known and unknown risks and uncertainties, many of which are beyond our control. Investors are cautioned that various factors may affect these forward-looking statements, including (among others) price volatility of crude oil, other feedstocks and refined products; the ability of CVR Partners to make cash distributions; potential operating hazards; costs of compliance with existing, or compliance with new, laws and regulations and potential liabilities arising therefrom; impacts of planting season on CVR Partners; general economic and business conditions; and other risks. For additional discussion of risk factors which may affect our results, please see the risk factors and other disclosures included in our most recent Annual Report on Form 10-K, any subsequently filed Quarterly Reports on Form 10-Q and our other SEC filings. These and other risks may cause our actual results, performance or achievements to differ materially from any future results, performance or achievements expressed or implied by these forward-looking statements. Given these risks and uncertainties, you are cautioned not to place undue reliance on such forward-looking statements. The forward-looking statements included in this news release are made only as of the date hereof. CVR Energy disclaims any intention or obligation to update publicly or revise any forward-looking statements, whether as a result of new information, future events or otherwise, except to the extent required by law.

About CVR Energy, Inc.
Headquartered in Sugar Land, Texas, CVR Energy is a diversified holding company primarily engaged in the petroleum refining and marketing business through its interest in CVR Refining and the nitrogen fertilizer manufacturing business through its interest in CVR Partners, LP. CVR Energy subsidiaries serve as the general partner and own 34 percent of the common units of CVR Partners.

For further information, please contact:

Investor Contact:
Richard Roberts
CVR Energy, Inc.
(281) 207-3205
InvestorRelations@CVREnergy.com  

Media Relations:
Brandee Stephens
CVR Energy, Inc.
(281) 207-3516
MediaRelations@CVREnergy.com

Non-GAAP Measures

Our management uses certain non-GAAP performance measures to evaluate current and past performance and prospects for the future to supplement our GAAP financial information presented in accordance with U.S. GAAP. These non-GAAP financial measures are important factors in assessing our operating results and profitability and include the performance and liquidity measures defined below.

Effective January 1, 2019, the Company revised its accounting policy method for the costs of planned major maintenance activities (turnarounds) specific to the Petroleum Segment from being expensed as incurred (the direct expensing method) to the deferral method. Refer to the 10-K for a further discussion of the impacts of this change in accounting policy. As a result of this change in accounting policy, the non-GAAP measures of Adjusted EBITDA, Petroleum Adjusted EBITDA, Nitrogen Fertilizer Adjusted EBITDA, Adjusted Net Income (Loss), and Direct Operating Expenses per Total Throughput Barrel net of Turnaround Expense are no longer being presented.

The following are non-GAAP measures that continue to be presented for the year ended December 31, 2019:

EBITDA - Consolidated net income (loss) before (i) interest expense, net, (ii) income tax expense (benefit) and (iii) depreciation and amortization expense.

Petroleum EBITDA and Nitrogen Fertilizer EBITDA - Segment net income (loss) before segment (i) interest expense, net, (ii) income tax expense (benefit), and (iii) depreciation and amortization.

Refining Margin - The difference between our Petroleum Segment net sales and cost of materials and other.

Refining Margin adjusted for Inventory Valuation Impacts - Refining Margin adjusted to exclude the impact of current period market price and volume fluctuations on crude oil and refined product inventories recognized in prior periods. We record our commodity inventories on the first-in-first-out basis. As a result, significant current period fluctuations in market prices and the volumes we hold in inventory can have favorable or unfavorable impacts on our refining margins as compared to similar metrics used by other publicly-traded companies in the refining industry.

Refining Margin and Refining Margin adjusted for Inventory Valuation Impacts, per Throughput Barrel - Refining Margin divided by the total throughput barrels during period, which is calculated as total throughput barrels per day times the number of days in the period.

Direct Operating Expenses per Throughput Barrel - Direct operating expenses for our Petroleum Segment divided by total throughput barrels for the period, which is calculated as total throughput barrels per day times the number of days in the period.

We present these measures because we believe they may help investors, analysts, lenders and ratings agencies analyze our results of operations and liquidity in conjunction with our U.S. GAAP results, including but not limited to our operating performance as compared to other publicly-traded companies in the refining industry, without regard to historical cost basis or financing methods and our ability to incur and service debt and fund capital expenditures. Non-GAAP measures have important limitations as analytical tools, because they exclude some, but not all, items that affect net earnings and operating income. These measures should not be considered substitutes for their most directly comparable U.S. GAAP financial measures. See “Non-GAAP Reconciliations” section included herein for reconciliation of these amounts. Due to rounding, numbers presented within this section may not add or equal to numbers or totals presented elsewhere within this document.

Items or Events Impacting Comparability

Refer to the “Non-GAAP Measures” section above for discussion of the changes made to the Company’s definition of certain non-GAAP measures.

Petroleum Segment

Coffeyville Refinery - During the fourth quarter of 2019, our Coffeyville Refinery incurred costs of $15 million related to preparations for the planned turnaround scheduled to be completed in the spring of 2020. During the first quarter of 2018, our Coffeyville Refinery experienced an outage with its fluid catalytic cracking unit (“FCCU”) lasting 48 days. The FCCU outage had a significant negative impact on production and sales during that period.

Wynnewood Refinery - The second phase of our Wynnewood Refinery’s planned facility turnaround was completed in the first quarter of 2019 at a cost of  $24 million.

Nitrogen Fertilizer Segment

During the fourth quarter of 2018, the Partnership recognized a $6 million business interruption insurance recovery associated with an outage at its Coffeyville Fertilizer Facility during 2017. The recovery is recorded in Other income, net.

Coffeyville Fertilizer Facility - During 2018, the Coffeyville Fertilizer Facility had a planned, full facility turnaround lasting 15 days and incurred approximately $6 million in turnaround expense in the second quarter of 2018.

East Dubuque Fertilizer Facility - During 2019, the East Dubuque Fertilizer Facility had a planned, full facility turnaround lasting 32 days and cost approximately $10 million in the third and fourth quarters of 2019.


CVR Energy, Inc.
(unaudited)

  Three Months Ended
December 31,
  Year Ended
December 31,
(in millions, except per share amounts) 2019   2018   2019   2018
Consolidated Statement of Operations Data          
Net sales $ 1,569     $ 1,738     $ 6,364     $ 7,124  
Operating costs and expenses:              
Cost of materials and other 1,262     1,388     4,851     5,683  
Direct operating expenses (exclusive of depreciation and amortization as reflected below) 136     127     533     517  
Depreciation and amortization 70     69     278     263  
Cost of sales  1,468     1,584     5,662     6,463  
Selling, general and administrative expenses (exclusive of depreciation and amortization as reflected below) 30     28     117     112  
Depreciation and amortization 1     2     9     11  
Loss (gain) on asset disposal 1         (4 )   6  
Operating income 69     124     580     532  
Other income (expense):              
Interest expense, net (24 )   (22 )   (102 )   (102 )
Other income, net 2     7     13     15  
Income before income taxes 47     109     491     445  
Income tax expense 19     14     129     79  
Net income 28     95     362     366  
Less: Net (loss) income attributable to noncontrolling interest (16 )   22     (18 )   107  
Net income attributable to CVR Energy stockholders $ 44     $ 73     $ 380     $ 259  
               
Basic and diluted earnings per share $ 0.44     $ 0.73     $ 3.78     $ 2.80  
Dividends declared per share $ 0.80     $ 0.75     $ 3.05     $ 2.50  
               
EBITDA * $ 142     $ 202     $ 880     $ 821  
               
Weighted-average common shares outstanding - basic and diluted 100.5     100.5     100.5     92.5  


   

* See “Non-GAAP Reconciliations” section below.

Selected Balance Sheet Data:

(in millions) December 31, 2019   December 31, 2018
Cash and cash equivalents $ 652      $ 668   
Working capital 695      797   
Total assets 3,905      4,000   
Total debt and finance lease obligations 1,195      1,170   
Total liabilities 2,237      2,057   
Total CVR stockholders’ equity 1,393      1,286   
           

Selected Cash Flow Data:

  Three Months Ended
December 31,
  Year Ended
December 31,
(in millions) 2019   2018   2019   2018
Net cash flow provided by (used in):              
Operating activities $ 94     $ 102     $ 747     $ 628  
Investing activities (48 )   (34 )   (121 )   (108 )
Financing activities (86 )   (102 )   (642 )   (334 )
Net cash flow $ (40 )   $ (34 )   $ (16 )   $ 186  
                               

Selected Segment Data:

(in millions) Petroleum   Nitrogen Fertilizer   Consolidated
Three Months Ended December 31, 2019          
Net sales $ 1,485     $ 86     $ 1,569  
Operating income (loss) 82     (9 )   69  
Net income (loss) 81     (25 )   28  
EBITDA * 135     11     142  
           
Capital Expenditures (1)          
Maintenance $ 20     $ 7     $ 28  
Growth 3     1     4  
Total capital expenditures $ 23     $ 9     $ 33  
           
Year Ended December 31, 2019          
Net sales $ 5,968     $ 404     $ 6,364  
Operating income 574     27     580  
Net income (loss) 559     (35 )   362  
EBITDA * 788     107     880  
           
Capital Expenditures (1)          
Maintenance $ 79     $ 18     $ 102  
Growth 10     2     12  
Total capital expenditures $ 89     $ 20     $ 114  
                       


(in millions) Petroleum   Nitrogen Fertilizer   Consolidated
Three Months Ended December 31, 2018          
Net sales $ 1,641     $ 98     $ 1,738  
Operating income 122     8     124  
Net income (loss) 115     (1 )   95  
EBITDA * 172     33     202  
           
Capital Expenditures (1)          
Maintenance $ 29     $ 4     $ 34  
Growth 6         6  
Total capital expenditures $ 35     $ 4     $ 40  
           
Year Ended December 31, 2018          
Net sales $ 6,780     $ 351     $ 7,124  
Operating income 544     6     532  
Net income (loss) 511     (50 )   366  
EBITDA * 748     84     821  
           
Capital Expenditures (1)          
Maintenance $ 70     $ 16     $ 89  
Growth 19     3     22  
Total capital expenditures $ 89     $ 19     $ 111  


   

* See “Non-GAAP Reconciliations” section below.
(1) Capital expenditures are shown exclusive of capitalized turnaround expenditures.

           
(in millions) Petroleum   Nitrogen Fertilizer   Consolidated
December 31, 2019          
Cash and cash equivalents $ 583      $ 37      $ 652   
Total assets 3,187      1,138      3,905   
Total debt and finance lease obligations 563      632      1,195   
           
December 31, 2018          
Cash and cash equivalents $ 353      $ 62      $ 668   
Total assets 2,453      1,254      4,000   
Total debt and finance lease obligations 541      629      1,170   
                 

Petroleum Segment:

Key Operating Metrics per Total Throughput Barrel

  Three Months Ended
December 31,
  Year Ended
December 31,
(in millions) 2019   2018   2019   2018
Refining Margin * $ 12.47      $ 13.67      $ 15.26      $ 15.18   
Refining Margin, excluding Inventory Valuation Impacts * 11.86      17.47      14.71      15.60   
Direct Operating Expenses * 4.63      4.41      4.56      4.62   


   

∗ See “Non-GAAP Reconciliations” section below.

Throughput Data by Refinery

  Three Months Ended
December 31,
  Year Ended
December 31,
(in bpd) 2019   2018   2019   2018
Coffeyville              
Regional crude 63,501      35,855      49,093      31,350   
WTI 46,784      72,468      67,382      66,952   
WTL 1,875      —      473      —   
Midland WTI 709      18,506      3,888      15,893   
Condensate 6,534      672      4,331      4,992   
Heavy Canadian 3,264      7,629      4,711      5,302   
Other feedstocks and blendstocks 10,798      12,033      9,160      8,369   
Wynnewood              
Regional crude 57,107      51,959      53,848      54,746   
WTI —      —          2,354   
WTL 2,649      —      668      —   
Midland WTI 6,808      7,776      10,995      10,332   
Condensate 8,431      8,808      7,666      7,237   
Heavy Canadian —      —      —      —   
Other feedstocks and blendstocks 4,269      5,775      3,753      5,068   
Total throughput 212,729      221,481      215,971      212,595   
                       

Production Data by Refinery

  Three Months Ended
December 31,
  Year Ended
December 31,
(in bpd) 2019   2018   2019   2018
Coffeyville              
Gasoline 73,814      78,290      71,817      67,091   
Distillate 53,222      60,080      57,549      56,307   
Other liquid products 2,850      4,834      5,810      5,737   
Solids 3,643      5,682      4,573      5,190   
Wynnewood              
Gasoline 39,429      39,033      38,864      40,291   
Distillate 33,496      30,568      32,380      33,442   
Other liquid products 3,697      2,992      3,223      4,025   
Solids 27      27      30      41   
Total production 210,178      221,506      214,246      212,124   
               
Liquid volume yield (as % of total throughput) 97.1  %   97.0  %   97.1  %   97.3  %

Key Market Indicators

  Three Months Ended
December 31,
  Year Ended
December 31,
(dollars per barrel) 2019   2018   2019   2018
West Texas Intermediate (WTI) NYMEX $ 56.87     $ 59.34     $ 57.04     $ 64.90  
Crude Oil Differentials to WTI:              
Brent 5.55     9.26     7.12     6.79  
WCS (heavy sour) (18.98 )   (33.86 )   (13.72 )   (26.35 )
Condensate (0.10 )   (0.65 )   (0.76 )   (0.46 )
Midland Cushing 0.94     (5.96 )   (0.69 )   (7.20 )
NYMEX Crack Spreads:              
Gasoline 12.14     9.81     15.43     15.69  
Heating Oil 24.82     27.74     24.43     23.15  
NYMEX 2-1-1 Crack Spread 18.48     18.78     19.93     19.42  
PADD II Group 3 Product Basis:              
Gasoline (1.27 )   (0.35 )   (1.74 )   (1.58 )
Ultra Low Sulfur Diesel (2.41 )   (0.25 )   (1.68 )   0.01  
PADD II Group 3 Product Crack Spread:              
Gasoline 10.88     9.46     13.69     14.11  
Ultra Low Sulfur Diesel 22.41     27.49     22.75     23.16  
PADD II Group 3 2-1-1 16.65     18.48     18.22     18.63  
                       

Q1 2020 Petroleum Segment Outlook

The table below summarizes our outlook for certain refining statistics and financial information for the first quarter of 2020. See “Forward-Looking Statements” above.

  Q1 2020
  Low   High
Total throughput (bpd) 155,000      165,000   
Direct operating expenses (1) (in millions) $ 85      $ 95   
Total capital expenditures (in millions) $ 45      $ 55   
Total turnaround expenditures (in millions) $ 115      $ 125   


   

(1) Direct operating expenses are shown exclusive of depreciation and amortization.

Nitrogen Fertilizer Segment

Ammonia Utilization Rates (2)

  Two Years Ended December 31,
(percent of capacity utilization) 2019   2018
Consolidated 93  %   95  %
Coffeyville 94  %   95  %
East Dubuque 91  %   95  %


   


(2) Reflects ammonia utilization rates on a consolidated basis and at each of the Nitrogen Fertilizer facilities. Utilization is an important measure used by management to assess operational output at each of the facilities. Utilization is calculated as actual tons produced divided by capacity. The Nitrogen Fertilizer Segment presents utilization on a two-year rolling average to take into account the impact of  current turnaround cycles on any specific period. The two-year rolling average is a more useful presentation of the long-term utilization performance of our plants. Additionally, we present utilization solely on ammonia production rather than each nitrogen product as it provides a comparative baseline against industry peers and eliminates the disparity of plant configurations for upgrade of ammonia into other nitrogen products. With the Nitrogen Fertilizer Segments’ efforts being primarily focused on ammonia upgrade capabilities, this measure provides a meaningful view of how well the facilities operate.
   

Sales and Production Data

  Three Months Ended
December 31,
  Year Ended
December 31,
  2019   2018   2019   2018
Consolidated sales (thousand tons):              
Ammonia 62      46      241      202   
UAN 293      364      1,261      1,289   
               
Consolidated product pricing at gate (dollars per ton) (1):              
Ammonia $ 324      $ 324      $ 392      $ 328   
UAN $ 176      $ 180      $ 199      $ 173   
               
Consolidated production volume (thousand tons):              
Ammonia (gross produced) (2) 180      209      766      794   
Ammonia (net available for sale) (2) 55      59      223      246   
UAN 286      357      1,255      1,276   
               
Feedstock:              
Petroleum coke used in production (thousand tons) 131      139      535      463   
Petroleum coke used in production (dollars per ton) $ 39.90      $ 41.34      $ 37.47      $ 28.41   
Natural gas used in production (thousands of MMBtus) (3) 1,646      2,000      6,856      7,933   
Natural gas used in production (dollars per MMBtu) (3) $ 2.87      $ 4.06      $ 2.88      $ 3.28   
Natural gas in cost of materials and other (thousands of MMBtus) (3) 1,474      1,854      6,961      7,122   
Natural gas in cost of materials and other (dollars per MMBtu) (3) $ 2.58      $ 3.50      $ 3.08      $ 3.15   


   


(1) Product pricing at gate represents sales less freight revenue divided by product sales volume in tons and is shown in order to provide a pricing measure that is comparable across the fertilizer industry.
(2) Gross tons produced for ammonia represent total ammonia produced, including ammonia produced that was upgraded into other fertilizer products. Net tons available for sale represent ammonia available for sale that was not upgraded into other fertilizer products.
(3) The feedstock natural gas shown above does not include natural gas used for fuel. The cost of fuel natural gas is included in direct operating expense.
   

Key Market Indicators

  Three Months Ended
December 31,
  Year Ended
December 31,
  2019   2018   2019   2018
Ammonia — Southern plains (dollars per ton) $ 288      $ 423      $ 348      $ 370   
Ammonia — Corn belt (dollars per ton) 385      479      435      424   
UAN — Corn belt (dollars per ton) 189      255      210      219   
               
Natural gas NYMEX (dollars per MMBtu) $ 2.40      $ 3.75      $ 2.54      $ 3.08   
                               

Q1 2020 Nitrogen Fertilizer Segment Outlook

The table below summarizes our outlook for certain operational statistics and financial information for the first quarter of 2020. See “Forward-Looking Statements” above.

  Q1 2020
  Low   High
Ammonia utilization rates (1)      
Consolidated 95  %   100  %
Coffeyville 95  %   100  %
East Dubuque 95  %   100  %
       
Direct operating expenses (2) (in millions) $ 35      $ 40   
       
Total capital expenditures (in millions) $     $  


   


(1) Ammonia utilization rates exclude the impact of Turnarounds.
(2) Direct operating expenses are shown exclusive of depreciation and amortization, turnaround expenses, and impacts of inventory adjustments.
   

Non-GAAP Reconciliations

Reconciliation of Consolidated Net Income to EBITDA

  Three Months Ended
December 31,
  Year Ended
December 31,
(in millions) 2019   2018   2019   2018
Net income $ 28      $ 95      $ 362      $ 366   
Add:              
Interest expense, net 24      22      102      102   
Income tax expense 19      14      129      79   
Depreciation and amortization 71      71      287      274   
EBITDA 142      202      880      821   
                       

Reconciliation of Petroleum Segment Net Income to EBITDA

  Three Months Ended
December 31,
  Year Ended
December 31,
(in millions) 2019   2018   2019   2018
Net income (loss) $ 81      $ 115      $ 559      $ 511   
Add:              
Interest expense, net         27      41   
Depreciation and amortization 50      48      202      196   
Petroleum EBITDA 135      172      788      748   
                       

Reconciliation of Petroleum Segment Gross Profit to Refining Margin and Refining Margin Adjusted for Inventory Valuation Impact

  Three Months Ended
December 31,
  Year Ended
December 31,
(in millions) 2019   2018   2019   2018
Net sales $ 1,485     $ 1,641     $ 5,968     $ 6,780  
Cost of materials and other 1,241     1,362     4,765     5,602  
Direct operating expenses (exclusive of depreciation and amortization and turnaround expenses as reflected below) 91     90     359     356  
Depreciation and amortization 48     47     199     192  
Gross profit 105     142     645     630  
Add:              
Direct operating expenses (exclusive of depreciation and amortization and turnaround expenses as reflected below) 91     90     359     356  
Depreciation and amortization 48     47     199     192  
Refining margin 244     279     1,203     1,178  
Inventory valuation impact, (favorable) unfavorable (1) (12 )   77     (43 )   33  
Refining margin, excluding inventory valuation impacts $ 232     $ 356     $ 1,160     $ 1,211  


   


(1) The Petroleum Segment’s basis for determining inventory value under GAAP is First-In, First-Out (“FIFO”). Changes in crude oil prices can cause fluctuations in the inventory valuation of crude oil, work in process and finished goods, thereby resulting in a favorable inventory valuation impact when crude oil prices increase and an unfavorable inventory valuation impact when crude oil prices decrease. The inventory valuation impact is calculated based upon inventory values at the beginning of the accounting period and at the end of the accounting period. In order to derive the inventory valuation impact per total throughput barrel, we utilize the total dollar figures for the inventory valuation impact and divide by the number of total throughput barrels for the period.
   

Reconciliation of Petroleum Segment Total Throughput Barrels

  Three Months Ended
December 31,
  Year Ended
December 31,
  2019   2018   2019   2018
Total throughput barrels per day 212,729      221,481      215,971      212,595   
Days in the period 92      92      365      365   
Total throughput barrels 19,571,068      20,376,252      78,829,441      77,597,175   
                       

Reconciliation of Petroleum Segment Refining Margin per Total Throughput Barrel

  Three Months Ended
December 31,
  Year Ended
December 31,
(in millions, except per total throughput barrel) 2019   2018   2019   2018
Refining margin $ 244      $ 279      $ 1,203      $ 1,178   
Divided by: total throughput barrels 20      20      79      78   
Refining margin per total throughput barrel $ 12.47      $ 13.67      $ 15.26      $ 15.18   
                               

Reconciliation of Petroleum Segment Refining Margin Adjusted for Inventory Valuation Impact per Total Throughput Barrel

  Three Months Ended
December 31,
  Year Ended
December 31,
(in millions, except per total throughput barrel) 2019   2018   2019   2018
Refining margin, excluding inventory valuation impacts $ 232      $ 356      $ 1,160      $ 1,211   
Divided by: total throughput barrels 20      20      79      78   
Refining margin, excluding inventory valuation impacts, per total throughput barrel $ 11.86      $ 17.47      $ 14.71      $ 15.60   
                               

Reconciliation of Petroleum Segment Direct Operating Expenses per Total Throughput Barrel

  Three Months Ended
December 31,
  Year Ended
December 31,
(in millions, except per total throughput barrel) 2019   2018   2019   2018
Direct operating expenses (exclusive of depreciation and amortization) $ 91      $ 90      $ 359      $ 356   
Divided by: total throughput barrels 20      20      79      78   
Direct operating expense per total throughput barrel $ 4.63      $ 4.41      $ 4.56      $ 4.62   
                               

Reconciliation of Nitrogen Fertilizer Segment Net Loss to EBITDA

  Three Months Ended
December 31,
  Year Ended
December 31,
(in millions) 2019   2018   2019   2018
Nitrogen fertilizer net loss $ (25 )   $ (1 )   $ (35 )   $ (50 )
Add:              
Interest expense, net 16     15     62     62  
Depreciation and amortization 20     19     80     72  
Nitrogen fertilizer EBITDA $ 11     $ 33     $ 107     $ 84  

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Source: CVR Energy, Inc.


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