CVR ENERGY INC - 10-Q - Management's Discussion and Analysis of Financial Condition and Results
of Operations
The following discussion and analysis of our financial condition and results of operations should be read in conjunction with the unaudited condensed consolidated financial statements and related notes and with the statistical information and financial data appearing in this Report, as well as our Annual Report on Form 10-K for the year ended December 31, 2015 filed with the Securities and Exchange Commission ("SEC") on February 19, 2016 (the "2015 Form 10-K"). Results of operations and cash flows for the three months ended March 31, 2016 are not necessarily indicative of results to be attained for any other period.
Forward-Looking Statements
This Report, including this Management's Discussion and Analysis of Financial Condition and Results of Operations, contains "forward-looking statements" as defined by the SEC, including statements concerning contemplated transactions and strategic plans, expectations and objectives for future operations. Forward-looking statements include, without limitation:
• statements, other than statements of historical fact, that address
activities, events or developments that we expect, believe or anticipate
will or may occur in the future;
• statements relating to future financial or operational performance, future
dividends, future capital sources and capital expenditures; and
• any other statements preceded by, followed by or that include the words
"anticipates," "believes," "expects," "plans," "intends," "estimates,"
"projects," "could," "should," "may" or similar expressions.
Although we believe that our plans, intentions and expectations reflected in or suggested by the forward-looking statements we make in this Report, including this Management's Discussion and Analysis of Financial Condition and Results of Operations, are reasonable, we can give no assurance that such plans, intentions or expectations will be achieved. These statements are based on assumptions made by us based on our experience and perception of historical trends, current conditions, expected future developments and other factors that we believe are appropriate in the circumstances. Such statements are subject to a number of risks and uncertainties, many of which are beyond our control. You are cautioned that any such statements are not guarantees of future performance and actual results or developments may differ materially from those projected in the forward-looking statements as a result of various factors, including but not limited to those set forth in the summary risks noted below:
• volatile margins in the refining industry and exposure to the risks
associated with volatile crude oil prices;
• the availability of adequate cash and other sources of liquidity for the
capital needs of our business;
• the ability to forecast our future financial condition or results of
operations and future revenues and expenses of our businesses;
• the effects of transactions involving forward and derivative instruments;
• disruption of our petroleum business' ability to obtain an adequate supply
of crude oil;
• changes in laws, regulations and policies with respect to the export of
crude oil or other hydrocarbons;
• interruption of the pipelines supplying feedstock and in the distribution of
the petroleum business' products;
• competition in the petroleum and nitrogen fertilizer businesses;
• capital expenditures and potential liabilities arising from environmental
laws and regulations;
• changes in ours or the Refining Partnership's or Nitrogen Fertilzer
Partnership's credit profile;
• the cyclical nature of the nitrogen fertilizer business;
• the seasonal nature of the petroleum business;
• the supply and price levels of essential raw materials of our businesses;
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• the risk of a material decline in production at our refineries and nitrogen
fertilizer plants;
• potential operating hazards from accidents, fire, severe weather, floods or
other natural disasters;
• the risk associated with governmental policies affecting the agricultural
industry;
• the volatile nature of ammonia, potential liability for accidents involving
ammonia that cause interruption to the nitrogen fertilizer business, severe
damage to property and/or injury to the environment and human health and
potential increased costs relating to the transport of ammonia;
• the dependence of the nitrogen fertilizer operations on a few third-party
suppliers, including providers of transportation services and equipment;
• new regulations concerning the transportation of hazardous chemicals, risks
of terrorism and the security of chemical manufacturing facilities;
• the risk of security breaches;
• the petroleum business' and the nitrogen fertilizer business' dependence on
significant customers;
• the potential loss of the nitrogen fertilizer business' transportation cost
advantage over its competitors;
• our nitrogen fertilizer business' partial dependence on customer and
distributor transportation of purchased goods;
• the potential inability to successfully implement our business strategies,
including the completion of significant capital programs;
• our ability to continue to license the technology used in the petroleum
business and nitrogen fertilizer business operations;
• our petroleum business' ability to purchase RINs on a timely and cost
effective basis;
• our petroleum business' continued ability to secure environmental and other
governmental permits necessary for the operation of its business;
• existing and proposed environmental laws and regulations, including those
relating to climate change, alternative energy or fuel sources, and existing
and future regulations related to the end-use and application of
fertilizers;
• refinery and nitrogen fertilizer facility operating hazards and
interruptions, including unscheduled maintenance or downtime, and the
availability of adequate insurance coverage;
• the risk of labor disputes and adverse employee relations;
• instability and volatility in the capital and credit markets; and
• potential exposure to underfunded pension obligations of affiliates as a
member of the controlled group of Mr. Icahn.
All forward-looking statements contained in this Report speak only as of the date of this Report. We undertake no obligation to publicly update or revise any forward-looking statements to reflect events or circumstances that occur after the date of this Report, or to reflect the occurrence of unanticipated events, except to the extent required by law.
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Company Overview
CVR Energy, Inc. ("CVR Energy," "CVR," "we," "us," "our" or the "Company") is a diversified holding company primarily engaged in the petroleum refining and nitrogen fertilizer manufacturing industries through our holdings in the Refining Partnership and the Nitrogen Fertilizer Partnership. The Refining Partnership is an independent petroleum refiner and marketer of high value transportation fuels. The Nitrogen Fertilizer Partnership produces nitrogen fertilizers in the form of UAN and ammonia. We own the general partner and approximately 66% and 34% respectively, of the outstanding common units representing limited partner interests in each of the Refining Partnership and the Nitrogen Fertilizer Partnership. As of March 31, 2016, Icahn Enterprises L.P. ("IEP") and its affiliates owned approximately 82% of our outstanding common stock.
We operate under two business segments: petroleum and nitrogen fertilizer, which are referred to in this document as our "petroleum business" and our "nitrogen fertilizer business," respectively.
Petroleum business. The petroleum business consists of our interest in the Refining Partnership. At March 31, 2016, we owned the general partner and approximately 66% of the common units of the Refining Partnership. The petroleum business consists of a 115,000 bpcd rated capacity complex full coking medium-sour crude oil refinery in Coffeyville, Kansas and a 70,000 bpcd rated capacity complex crude oil refinery in Wynnewood, Oklahoma capable of processing 20,000 bpcd of light sour crude oil (within its rated capacity of 70,000 bpcd). In addition, its supporting businesses include (i) a crude oil gathering system with a gathering capacity of over 65,000 bpd serving Kansas, Nebraska, Oklahoma, Missouri, Colorado and Texas, which serves the two refineries, (ii) a 170,000 bpd pipeline system (supported by approximately 336 miles of active owned and leased pipeline) that transports crude oil to the Coffeyville refinery from the Broome Station facility located near Caney, Kansas, (iii) approximately 6.4 million barrels of owned and leased crude oil storage, including 0.5 million barrels completed in October 2015, (iv) a rack marketing business supplying refined petroleum product through tanker trucks directly to customers located in close geographic proximity to Coffeyville, Kansas and Wynnewood, Oklahoma and at throughput terminals on Magellan and NuStar's refined petroleum products distribution systems and (v) over 4.5 million barrels of combined refined products and feedstocks storage capacity.
The Coffeyville refinery is situated approximately 100 miles northeast of Cushing, Oklahoma, one of the largest crude oil trading and storage hubs in the United States and the Wynnewood refinery is approximately 130 miles southwest of Cushing. Cushing is supplied by numerous pipelines from U.S. domestic locations and Canada. In addition to rack sales (sales which are made at terminals into third-party tanker trucks), Coffeyville makes bulk sales (sales through third-party pipelines) into the mid-continent markets and other destinations utilizing the product pipeline networks owned by Magellan, Enterprise, and NuStar.
Crude oil is supplied to the Coffeyville refinery through the gathering system and by a pipeline owned by Plains that runs from Cushing, Oklahoma to its Broome Station facility. The petroleum business maintains capacity on the Spearhead and Keystone pipelines from Canada to Cushing, Oklahoma. It also has contracted capacity on the Pony Express and White Cliffs pipelines, which originate in Colorado and extend to Cushing, Oklahoma. It also maintains leased and owned storage in Cushing to facilitate optimal crude oil purchasing and blending. Crude oil is supplied to the Wynnewood refinery through three third-party pipelines operated by Sunoco Pipeline, Excel Pipeline and Blueknight Pipeline and historically has mainly been sourced from Texas and Oklahoma. The access to a variety of crude oils coupled with the complexity of the refineries typically allows the petroleum business to purchase crude oil at a discount to WTI. The consumed crude oil cost discount to WTI for the first quarter of 2016 was $1.53 per barrel compared to a discount of $1.10 per barrel in the first quarter of 2015.
Nitrogen fertilizer business. The nitrogen fertilizer business consists of our interest in the Nitrogen Fertilizer Partnership. At March 31, 2016, we owned 100% of the general partner and approximately 53% of the common units of the Nitrogen Fertilizer Partnership. Following completion of the East Dubuque mergers on April 1, 2016, we now hold approximately 34% of the Nitrogen Fertilizer Partnership's outstanding common units and 100% of the Nitrogen Fertilizer Partnership's general partner. As of March 31, 2016, the nitrogen fertilizer business consisted of one nitrogen fertilizer manufacturing facility located in Coffeyville, Kansas ("Coffeyville Fertilizer Facility") that utilizes a petroleum coke, or pet coke, gasification process to produce nitrogen fertilizer. The Coffeyville Fertilizer Facility includes a 1,300 ton-per-day ammonia unit, a 3,000 ton-per-day UAN unit and a gasifier complex having a capacity of 89 million standard cubic feet per day of hydrogen. The gasifier is a dual-train facility, with each gasifier able to function independently of the other, thereby providing redundancy and improving reliability. With the completion of the UAN expansion in February 2013, the Coffeyville Fertilizer Facility now upgrades substantially all of the ammonia it produces to higher margin UAN fertilizer, an aqueous solution of urea and ammonium nitrate which has historically commanded a premium price over ammonia. For the three months ended March 31, 2016, the nitrogen fertilizer business produced 0.2 million tons of UAN and 0.1 million tons of ammonia, respectively. For the three months ended March 31, 2016, approximately 89% of the produced ammonia tons and the majority of purchased ammonia tons were upgraded into UAN, respectively.
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The primary raw material feedstock utilized in the nitrogen fertilizer production process at the Coffeyville Fertilizer Facility is pet coke, which is produced during the crude oil refining process. In contrast, substantially all of the nitrogen fertilizer businesses' competitors use natural gas as their primary raw material feedstock. Historically, pet coke has been less expensive than natural gas on a per ton of fertilizer produced basis. The Coffeyville Fertilizer facility's pet coke gasification process results in a significantly higher percentage of fixed costs than a natural gas-based fertilizer plant. The nitrogen fertilizer business currently purchases most of its pet coke used at the Coffeyville Fertilizer Facility from the Refining Partnership pursuant to a long-term agreement having an initial term that ends in 2027, subject to renewal. On average, during the past five years, over 70% of the pet coke utilized by the Coffeyville Fertilizer Facility was produced and supplied by the Refining Partnership's crude oil refinery in Coffeyville.
As a result of the East Dubuque mergers, we also now own a nitrogen fertilizer facility located in East Dubuque, Illinois ("East Dubuque Fertilizer Facility"), which produces primarily ammonia and UAN. For a discussion of the East Dubuque mergers, refer to "Recent Developments" below in Part I. Item 2 of this Report and Note 15 ("Subsequent Events") of Part I. Item 1 of this Report.
Recent Developments
On April 1, 2016, the Nitrogen Fertilizer Partnership completed the previously announced transactions (the "mergers") contemplated by the Agreement and Plan of Merger, dated as of August 9, 2015 (the "Merger Agreement"), with East Dubuque Nitrogen Partners, L.P. (formerly known as Rentech Nitrogen Partners, L.P.) ("East Dubuque") and East Dubuque Nitrogen GP, LLC (formerly known as Rentech Nitrogen GP, LLC) ("East Dubuque GP"). Refer to Part I, Item 1, Note 15 ("Subsequent Events") of this Report for further discussion of the mergers.
Major Influences on Results of Operations
Petroleum Business
The earnings and cash flows of the petroleum business are primarily affected by the relationship between refined product prices and the prices for crude oil and other feedstocks that are processed and blended into refined products. The cost to acquire crude oil and other feedstocks and the price for which refined products are ultimately sold depend on factors beyond the petroleum business' control, including the supply of and demand for crude oil, as well as gasoline and other refined products which, in turn, depend on, among other factors, changes in domestic and foreign economies, weather conditions, domestic and foreign political affairs, production levels, the availability of imports, the marketing of competitive fuels and the extent of government regulation. Because the petroleum business applies first-in, first-out ("FIFO") accounting to value its inventory, crude oil price movements may impact net income in the short term because of changes in the value of its unhedged on-hand inventory. The effect of changes in crude oil prices on our results of operations is influenced by the rate at which the prices of refined products adjust to reflect these changes.
The prices of crude oil and other feedstocks and refined product prices are also affected by other factors, such as product pipeline capacity, local market conditions and the operating levels of competing refineries. Crude oil costs and the prices of refined products have historically been subject to wide fluctuations. Widespread expansion or upgrades of competitors' facilities, price volatility, international political and economic developments and other factors are likely to continue to play an important role in refining industry economics. These factors can impact, among other things, the level of inventories in the market, resulting in price volatility and a reduction in product margins. Moreover, the refining industry typically experiences seasonal fluctuations in demand for refined products, such as increases in the demand for gasoline during the summer driving season and for home heating oil during the winter, primarily in the Northeast. In addition to current market conditions, there are long-term factors that may impact the demand for refined products. These factors include mandated renewable fuels standards, proposed climate change laws and regulations and increased mileage standards for vehicles. The petroleum business is also subject to the Renewable Fuel Standard ("RFS") of the United States Environmental Protection Agency (the "EPA"), which requires it to either blend "renewable fuels" in with its transportation fuels or purchase renewable fuel credits, known as renewable identification numbers ("RINs"), in lieu of blending.
On December 14, 2015, the EPA published in the Federal Register a final rule establishing the renewable fuel volume mandates for 2014, 2015 and 2016, and the biomass-based diesel mandate for 2017. The volumes included in the EPA's final rule increase each year, but are lower, with the exception of the volumes for biomass-based diesel, than the volumes required by the Clean Air Act. The EPA used its waiver authority to lower the volumes, but its decision to do so has been challenged in the U.S. Court of Appeals for the District of Columbia Circuit. In addition, in the final rule establishing the renewable volume obligations for 2014-2016 and bio-mass based diesel for 2017, the EPA articulated a policy to incentivize additional investments in renewable fuel blending and distribution infrastructure by increasing the price of RINs.
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The cost of RINs for the three months ended March 31, 2016 and 2015 was approximately $43.1 million and $36.6 million, respectively. The price of RINs has been extremely volatile and has increased over the last year. The future cost of RINs for the petroleum business is difficult to estimate. Additionally, the cost of RINs is dependent upon a variety of factors, which include EPA regulations, the availability of RINs for purchase, the price at which RINs can be purchased, transportation fuel production levels, the mix of the petroleum business' petroleum products, as well as the fuel blending performed at its refineries and downstream terminals, all of which can vary significantly from period to period. Based upon recent market prices of RINs and current estimates related to the other variable factors, the petroleum business currently estimates that the total cost of RINs will be approximately $160.0 million to $190.0 million for the year ending December 31, 2016.
If sufficient RINs are unavailable for purchase at times when the petroleum business seeks to purchase RINs, if the petroleum business has to pay a significantly higher price for RINs or if the petroleum business is otherwise unable to meet the EPA's RFS mandates, its business, financial condition and results of operations could be materially adversely affected.
In order to assess the operating performance of the petroleum business, we compare net sales, less cost of product sold (exclusive of depreciation and amortization), or the refining margin, against an industry refining margin benchmark. The industry refining margin benchmark is calculated by assuming that two barrels of benchmark light sweet crude oil are converted into one barrel of conventional gasoline and one barrel of distillate. This benchmark is referred to as the 2-1-1 crack spread. Because we calculate the benchmark margin using the market value of NYMEX gasoline and heating oil against the market value of NYMEX WTI, we refer to the benchmark as the NYMEX 2-1-1 crack spread, or simply, the 2-1-1 crack spread. The 2-1-1 crack spread is expressed in dollars per barrel and is a proxy for the per barrel margin that a sweet crude oil refinery would earn assuming it produced and sold the benchmark production of gasoline and distillate.
Although the 2-1-1 crack spread is a benchmark for refining margin, because the refineries have certain feedstock costs and logistical advantages as compared to a benchmark refinery and their product yield is less than total refinery throughput, the crack spread does not account for all the factors that affect refining margin. The Coffeyville refinery is able to process a blend of crude oil that includes quantities of heavy and medium sour crude oil that has historically cost less than WTI. The Wynnewood refinery has the capability to process blends of a variety of crude oil ranging from medium sour to light sweet crude oil, although isobutene, gasoline components and normal butane are also typically used. We measure the cost advantage of the crude oil slate by calculating the spread between the price of the delivered crude oil and the price of WTI. The spread is referred to as the consumed crude oil differential. Refining margin can be impacted significantly by the consumed crude oil differential. The consumed crude oil differential will move directionally with changes in the WTS differential to WTI and the WCS differential to WTI as both these differentials indicate the relative price of heavier, more sour, slate to WTI. The correlation between the consumed crude oil differential and published differentials will vary depending on the volume of light medium sour crude oil and heavy sour crude oil the petroleum business purchases as a percent of its total crude oil volume and will correlate more closely with such published differentials the heavier and more sour the crude oil slate.
The petroleum business produces a high volume of high value products, such as gasoline and distillates. The fact that the actual product specifications used to determine the NYMEX 2-1-1 crack spread are different from the actual production in its refineries is because the prices the petroleum business realizes are different than those used to determining the 2-1-1 crack spread. The difference between its price received and the price used to calculate the 2-1-1 crack spread is referred to as gasoline PADD II, Group 3 vs. NYMEX basis, or gasoline basis, and Ultra-Low Sulfur Diesel PADD II, Group 3 vs. NYMEX basis, or Ultra-Low Sulfur Diesel basis. If both gasoline and Ultra-Low Sulfur Diesel basis are greater than zero, this means that prices in its marketing area exceed those used in the 2-1-1 crack spread.
The petroleum business is significantly affected by developments in the markets in which it operates. For example, numerous pipeline projects expanded the connectivity of the Cushing and Permian Basin markets to the gulf coast, resulting in a decrease in the domestic crude advantage. The refining industry is directly impacted by these events and could see a downward movement in refining margins as a result.
The direct operating expense structure is also important to the petroleum business' profitability. Major direct operating expenses include energy, employee labor, maintenance, contract labor and environmental compliance. The predominant variable cost is energy, which is comprised primarily of electrical cost and natural gas. The petroleum business is therefore sensitive to the movements of natural gas prices. Assuming the same rate of consumption of natural gas for the three months ended March 31, 2016, a $1.00 change in natural gas prices would have increased or decreased the petroleum business' natural gas costs by approximately $2.8 million.
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Because crude oil and other feedstocks and refined products are commodities, the petroleum business has no control over the changing market. Therefore, the lower target inventory the petroleum business is able to maintain significantly reduces the impact of commodity price volatility on its earnings. Because most of its titled inventory is valued under the FIFO costing method, price fluctuations on its target level of titled inventory may have a major effect on the petroleum business' financial results from period to period.
Safe and reliable operations at our refineries are key to our financial performance and results of operations. Unscheduled downtime at our refineries may result in lost margin opportunity, increased maintenance expense and a temporary increase in working capital investment and related inventory position. We seek to mitigate the financial impact of scheduled downtime, such as major turnaround maintenance, through a diligent planning process that takes into account the margin environment, the availability of resources to perform the needed maintenance, feedstock logistics and other factors. Our refineries generally require a facility turnaround every four to five years. The length of the turnaround is contingent upon the scope of work to be completed. The first phase of the Coffeyville refinery's current turnaround was completed in November of 2015. The second phase of the Coffeyville turnaround was completed during the first quarter of 2016. During the three months ended March 31, 2016, we incurred $29.4 million of major scheduled turnaround expenses for the Coffeyville refinery turnaround. The total estimated cost of the second phase, including demobilization, breakdown and clean-up work is expected to be approximately $32.0 million. The next turnaround at our Wynnewood refinery is scheduled to occur in the second half of 2017.
Nitrogen Fertilizer Business
In the nitrogen fertilizer business, earnings and cash flows from operations are primarily affected by the relationship between nitrogen fertilizer product prices, on-stream factors and direct operating expenses. Natural gas is the most significant raw material required in its competitors' production of nitrogen fertilizer. Unlike its competitors, the nitrogen fertilizer business' Coffeyville Fertilizer Facility does not use natural gas as a feedstock and uses a minimal amount of natural gas as an energy source in its operations. Instead, the adjacent Coffeyville refinery supplies the Coffeyville Fertilizer Facility with most of the pet coke feedstock it needs pursuant to a 20-year pet coke supply agreement entered into in October 2007. The price at which nitrogen fertilizer products are ultimately sold depends on numerous factors, including the global supply and demand for nitrogen fertilizer products which, in turn, depends on, among other factors, world grain demand and production levels, changes in world population, the cost and availability of fertilizer transportation infrastructure, weather conditions, the availability of imports and the extent of government intervention in agriculture markets.
Nitrogen fertilizer prices are also affected by local factors, including local market conditions and the operating levels of competing facilities. An expansion or upgrade of competitors' facilities, political and economic developments and other factors are likely to continue to play an important role in nitrogen fertilizer industry economics. These factors can impact, among other things, the level of inventories in the market, resulting in price volatility and a reduction in product margins. Moreover, the industry typically experiences seasonal fluctuations in demand for nitrogen fertilizer products.
In order to assess the operating performance of the nitrogen fertilizer business, the nitrogen fertilizer business calculates the product pricing at gate as an input to determine operating margin. Product pricing at gate represents net sales less freight revenue divided by product sales volume in tons. The nitrogen fertilizer business believes product pricing at gate is a meaningful measure because it sells products at its plant gate and terminal locations' gates ("sold gate") and delivered to the customer's designated delivery site ("sold delivered"). The relative percentage of sold gate versus sold delivered can change period to period. The product pricing at gate provides a measure that is consistently comparable period to period.
The nitrogen fertilizer business and other competitors in the U.S. farm belt share a significant transportation cost advantage when compared to out-of-region competitors in serving the U.S. farm belt agricultural market; therefore, the nitrogen fertilizer business is able to cost-effectively sell substantially all of its products in the higher margin agricultural market. In contrast, a significant portion of its competitors' revenues is derived from the lower margin industrial market. The nitrogen fertilizer business' products leave the Coffeyville Fertilizer Facility either in railcars for destinations located principally on the Union Pacific Railroad or in trucks for direct shipment to customers. The nitrogen fertilizer business does not currently incur significant intermediate transfer, storage, barge freight or pipeline freight charges; however, it does incur costs to maintain and repair its railcar fleet for the Coffeyville Fertilizer Facility. Selling products to customers within economic rail transportation limits of the Coffeyville Fertilizer Facility and keeping transportation costs low are keys to maintaining profitability.
The Coffeyville Fertilizer Facility's largest raw material expense used in the production of ammonia is pet coke, which it purchases from the petroleum business and third parties. For the three months ended March 31, 2016 and 2015, the nitrogen fertilizer business incurred approximately $2.1 million and $3.6 million, respectively, for the cost of pet coke, which equaled an average cost per ton of $17 and $29, respectively.
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Safe and reliable operations at the nitrogen fertilizer plants are critical to its financial performance and results of operations. Unplanned downtime of the nitrogen fertilizer plants may result in lost margin opportunity, increased maintenance expense and a temporary increase in working capital investment and related inventory position. The financial impact of planned downtime, such as major turnaround maintenance, is mitigated through a diligent planning process that takes into account margin environment, the availability of resources to perform the needed maintenance, feedstock logistics and other factors. The nitrogen fertilizer plants generally undergo a full facility turnaround every two to three years. Turnarounds are expected to last 14-21 days. The Coffeyville Fertilizer Facility underwent a full facility turnaround in the third quarter of 2015 and is planning to undergo the next scheduled full facility turnaround in the second half of 2017. The East Dubuque Fertilizer Facility is planning to undergo the next scheduled full facility turnaround in the second quarter of 2016, which is expected to last between 25-30 days.
Agreements with the Refining Partnership and the Nitrogen Fertilizer Partnership
We are party to several agreements with the Nitrogen Fertilizer Partnership that govern the business relations among the nitrogen fertilizer business and us and our subsidiaries (including the Refining Partnership). In connection with the Refining Partnership IPO in January 2013, some of our subsidiaries party to these agreements became subsidiaries of the Refining Partnership.
These intercompany agreements include (i) the pet coke supply agreement mentioned above, under which the petroleum business sells pet coke to the nitrogen fertilizer business; (ii) a services agreement, pursuant to which our management operates the nitrogen fertilizer business; (iii) a feedstock and shared services agreement, which governs the provision of feedstocks, including hydrogen, high-pressure steam, nitrogen, instrument air, oxygen and natural gas; (iv) a raw water and facilities sharing agreement, which allocates raw water resources between the two businesses; (v) an easement agreement; (vi) an environmental agreement; and (vii) a lease agreement pursuant to which the petroleum business leases office space and laboratory space to the Nitrogen Fertilizer Partnership. These agreements were not the result of arm's-length negotiations and the terms of these agreements are not necessarily at least as favorable to the parties to these agreements as terms which could have been obtained from unaffiliated third parties.
In connection with the Refining Partnership IPO, we entered into a number of agreements with the Refining Partnership, including (i) a $250.0 million intercompany credit facility between CRLLC and the Refining Partnership and (ii) a services agreement, pursuant to which our management operates the petroleum business.
On April 1, 2016, in connection with the closing of the mergers with East Dubuque GP and East Dubuque, we entered into a $300.0 million senior term loan credit facility with the Nitrogen Fertilizer Partnership, with CRLLC as the lender. Refer to Part I, Item 2, "Liquidity and Capital Resources" for further discussion of the credit facility.
Crude Oil Supply Agreement
On August 31, 2012, Coffeyville Resources Refining and Marketing, LLC ("CRRM") and Vitol Inc. ("Vitol") entered into an Amended and Restated Crude Oil Supply Agreement (as amended, the "Vitol Agreement"). Under the agreement, Vitol supplies the petroleum business with crude oil and intermediation logistics, which helps the petroleum business to reduce its inventory position and mitigate crude oil pricing risk. The Vitol Agreement will automatically renew for successive one-year terms (each such term, a "Renewal Term") unless either party provides the other with notice of nonrenewal at least 180 days prior to the expiration of any Renewal Term. The Vitol Agreement currently extends through December 31, 2016.
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Factors Affecting Comparability
Our historical results of operations for the periods presented may not be comparable with prior periods or to our results of operations in the future for the reasons presented and discussed below.
Three Months Ended
March 31,
2016 2015
(in millions)
Loss on derivatives, net 1.2 51.4
Major scheduled turnaround expenses(1) 29.4 -
_______________________________________
(1) Represents expense associated with major scheduled turnaround activities
performed at the Coffeyville refinery.
Noncontrolling Interest
Prior to the Refining Partnership IPO on January 23, 2013, the noncontrolling interest reflected in our consolidated financial statements represented the approximately 30% interest in the Nitrogen Fertilizer Partnership held by public common unitholders, which was adjusted each reporting period for the noncontrolling ownership percentage of the Nitrogen Fertilizer Partnership's net income and related distributions. As a result of the Refining Partnership IPO, CVR Energy recorded an additional noncontrolling interest for the Refining Partnership common units sold to the public, which represented an approximately 19% interest of the Refining Partnership. Effective with the Refining Partnership's IPO, the noncontrolling interest reflected on the Consolidated Balance Sheets was impacted additionally by the noncontrolling ownership percentage of the net income of the Refining Partnership and related distributions for each future reporting period. As a result of the Refining Partnership's closing of the Underwritten Offering, the noncontrolling interest related to the Refining Partnership reflected in our consolidated financial statements subsequent to the completion of the offering in the second quarter of 2013 and prior to June 30, 2014 was approximately 29%. Upon completion of the Second Underwritten Offering on June 30, 2014 and through June 23, 2014, the noncontrolling interest reflected in our condensed consolidated financial statements was approximately 33%. On July 24, 2014, upon exercise of the underwriters' option associated with the Second Underwritten Offering, the noncontrolling interest reflected in our condensed consolidated financial statements from such date and for the three months ended March 31, 2016 was approximately 34%. Additionally, as a result of the Nitrogen Fertilizer Partnership's Secondary Offering, the noncontrolling interest related to the Nitrogen Fertilizer Partnership reflected in our condensed consolidated financial statements subsequent to the completion of the Secondary Offering on May 28, 2013 and for the three months ended March 31, 2016 was approximately 47%.
Distributions to CVR Partners Unitholders
The current policy of the board of directors of the Nitrogen Fertilizer Partnership's general partner is to distribute all of the available cash the Nitrogen Fertilizer Partnership generates each quarter. Available cash for distribution for each quarter will be determined by the board of directors of the Nitrogen Fertilizer Partnership's general partner following the end of such quarter, subject to the limitations discussed below. The board of directors of the Nitrogen Fertilizer Partnership's general partner calculates available cash for distribution starting with Adjusted Nitrogen Fertilizer EBITDA reduced for (i) cash needed for net cash interest expense (excluding capitalized interest) and debt service and other contractual obligations, (ii) maintenance capital expenditures, (iii) to the extent applicable, major scheduled turnaround expenses and reserves for future operating or capital needs that the board of directors of the Nitrogen Fertilizer Partnership's general partner deems necessary or appropriate, and (iv) expenses associated with the East Dubuque mergers, if any. Available cash for distribution may be increased by the release of previously established cash reserves, if any, at the discretion of the board of directors of the Nitrogen Fertilizer Partnership's general partner. Actual distributions are set by the board of directors of the Nitrogen Fertilizer Partnership's general partner, and, prior to April 1, 2016, were subject to the limitations in accordance with the Merger Agreement discussed below. The board of directors of the Nitrogen Fertilizer Partnership's general partner may modify the cash distribution policy at any time, and the partnership agreement does not require the Nitrogen Fertilizer Partnership to make distributions at all.
The Merger Agreement with East Dubuque and East Dubuque GP included customary restrictions on the conduct of the Nitrogen Fertilizer Partnership's business prior to the completion of the mergers, generally requiring the Nitrogen Fertilizer Partnership to conduct its business in the ordinary course and subjecting the Nitrogen Fertilizer Partnership to a variety of specified limitations. In accordance with the terms of the Merger Agreement, beginning with the distribution for the third quarter of 2015 and until the closing of the mergers, the Nitrogen Fertilizer Partnership could not make or declare distributions in excess of available cash for distribution in respect of any quarter. The mergers closed on April 1, 2016, and this restriction terminated.
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On March 7, 2016, the Nitrogen Fertilizer Partnership paid a cash distribution to the Nitrogen Fertilizer Partnership's unitholders of record at the close of business on February 29, 2016 for the fourth quarter of 2015 in the amount of $0.27 per common unit, or $19.7 million in aggregate. We received $10.5 million in respect of our common units.
On April 27, 2016, the board of directors of the Nitrogen Fertilizer Partnership's general partner declared a cash distribution for the first quarter of 2016 to the Nitrogen Fertilizer Partnership's unitholders of $0.27 per common unit or $30.6 million in aggregate. The cash distribution will be paid on May 16, 2016 to the unitholders of record at the close of business on May 9, 2016. We will receive $10.5 million in respect of our common units.
Distributions to CVR Refining Unitholders
The current policy of the board of directors of the Refining Partnership's general partner is to distribute all of the available cash the Refining Partnership generates each quarter. Available cash for distribution for each quarter will be determined by the board of directors of the Refining Partnership's general partner following the end of such quarter and will generally equal Adjusted Petroleum EBITDA reduced for (i) cash needed for debt service, (ii) reserves for environmental and maintenance capital expenditures, (iii) reserves for major scheduled turnaround expenses and, (iv) to the extent applicable, reserves for future operating or capital needs that the board of directors of the Refining Partnership's general partner deems necessary or appropriate, if any. Available cash for distribution may be increased by the release of previously established cash reserves, if any, and other excess cash, at the discretion of the board of directors of the Refining Partnership's general partner. Actual distributions are set by the board of directors of the Refining Partnership's general partner. The board of directors of the Refining Partnership's general partner may modify the cash distribution policy at any time, and the partnership agreement does not require the Refining Partnership to make distributions at all.
CVR Energy Dividends
On March 7, 2016, the Company paid a cash dividend to stockholders of record at the close of business on February 29, 2016 for the fourth quarter of 2015 in the amount of $0.50 per share, or $43.4 million in aggregate.
On April 27, 2016, our board of directors declared a dividend for the first quarter of 2016 of $0.50 per share, or $43.4 million in aggregate. The dividend will be paid on May 16, 2016 to stockholders of record at the close of business on May 9, 2016.
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