Edgar Filing: CVR PARTNERS, LP

Large accelerated filer þ

Accelerated filer o

Non-accelerated filer o

Smaller reporting company o

(Do not check if smaller reporting company.)

UAN Q2 2015 FORM 10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q



(Mark One)
þ	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2015

OR

¨	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to .

Commission file number: 001-35120

CVR Partners, LP

(Exact name of registrant as specified in its charter)



Delaware	56-2677689
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
2277 Plaza Drive, Suite 500
Sugar Land, Texas (Address of principal executive offices)	77479 (Zip Code)

(281) 207-3200

(Registrant’s telephone number, including area code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes þ No o

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes þ No o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

Indicate by check mark whether the registrant is a shell company (as defined by Rule 12b-2 of the Exchange Act). Yes o No þ

There were 73,122,997 common units outstanding at July 28, 2015.

CVR PARTNERS, LP AND SUBSIDIARIES

INDEX TO QUARTERLY REPORT ON FORM 10-Q

For The Quarter Ended June 30, 2015



		Page No.
Part I. Financial Information
Item 1.	Financial Statements	5

	Condensed Consolidated Balance Sheets —June 30, 2015 (unaudited) and December 31, 2014	5

	Condensed Consolidated Statements of Operations — Three and Six Months Ended June 30, 2015 and 2014 (unaudited)	6

	Condensed Consolidated Statements of Comprehensive Income – Three and Six Months Ended June 30, 2015 and 2014 (unaudited)	7

	Condensed Consolidated Statement of Partners’ Capital — Six Months Ended June 30, 2015 (unaudited)	8

	Condensed Consolidated Statements of Cash Flows — Six Months Ended June 30, 2015 and 2014 (unaudited)	9

	Notes to the Condensed Consolidated Financial Statements — June 30, 2015 (unaudited)	10

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	24

Item 3.	Quantitative and Qualitative Disclosures About Market Risk	42

Item 4.	Controls and Procedures	42

Part II. Other Information

Item 1.	Legal Proceedings	43

Item 1A.	Risk Factors	43

Item 6.	Exhibits	43

Signatures		44

Table of Contents

GLOSSARY OF SELECTED TERMS

The following are definitions of certain terms used in this Quarterly Report on Form 10-Q for the quarter ended June 30, 2015 (this “Report”):



ammonia	Ammonia is a direct application fertilizer and is primarily used as a building block for other nitrogen products for industrial applications and finished fertilizer products.

capacity	Capacity is defined as the throughput a process unit is capable of sustaining, either on a calendar or stream day basis. The throughput may be expressed in terms of maximum sustainable, nameplate or economic capacity. The maximum sustainable or nameplate capacities may not be the most economical. The economic capacity is the throughput that generally provides the greatest economic benefit based on considerations such as feedstock costs, product values and downstream unit constraints.

catalyst	A substance that alters, accelerates, or instigates chemical changes, but is neither produced, consumed nor altered in the process.

Coffeyville Resources or CRLLC	Coffeyville Resources, LLC, the subsidiary of CVR Energy which directly owns our general partner and 38,920,000 common units, or approximately 53% of our common units.

common units	Common units representing limited partner interests of CVR Partners, LP.

corn belt	The primary corn producing region of the United States, which includes Illinois, Indiana, Iowa, Minnesota, Missouri, Nebraska, Ohio and Wisconsin.

CVR Energy	CVR Energy, Inc., a publicly traded company listed on the New York Stock Exchange under the ticker symbol “CVI,” which indirectly owns our general partner and the common units owned by CRLLC.

CVR Refining	CVR Refining, LP, a publicly traded limited partnership listed on the New York Stock Exchange under the ticker symbol “CVRR,” which currently owns and operates a complex full coking medium-sour crude oil refinery with a rated capacity of 115,000 barrels per calendar day (bpcd) in Coffeyville, Kansas, a complex crude oil refinery with a rated capacity of 70,000 bpcd in Wynnewood, Oklahoma and ancillary businesses.

farm belt	Refers to the states of Illinois, Indiana, Iowa, Kansas, Minnesota, Missouri, Nebraska, North Dakota, Ohio, Oklahoma, South Dakota, Texas and Wisconsin.

feedstocks	Petroleum coke and petroleum products (such as crude oil and natural gas liquids) that are processed and blended into refined products, such as gasoline, diesel fuel and jet fuel, which are produced by a refinery.

general partner	CVR GP, LLC, our general partner, which is a wholly-owned subsidiary of Coffeyville Resources, LLC.

Initial Public Offering	The initial public offering of CVR Partners, LP common units that closed on April 13, 2011.

MMbtu	One million British thermal units: a measure of energy. One Btu of heat is required to raise the temperature of one pound of water one degree Fahrenheit.

MSCF	One thousand standard cubic feet, a customary gas measurement.

netback	Netback represents net sales less freight revenue divided by product sales volume in tons. Netback is also referred to as product pricing at gate.

on-stream	Measurement of the reliability of the gasification, ammonia and UAN units, defined as the total number of hours operated by each unit divided by the total number of hours in the reporting period.

pet coke	Petroleum coke - a coal-like substance that is produced during the oil refining process.

product pricing at gate	Product pricing at gate represents net sales less freight revenue divided by product sales volume in tons. Product pricing at gate is also referred to as netback.

Table of Contents



Secondary Offering	The registered public offering of 12,000,000 common units of CVR Partners, LP, by CRLLC, which closed on May 28, 2013.

throughput	The volume processed through a unit.

ton	One ton is equal to 2,000 pounds.

turnaround	A periodically required standard procedure to refurbish and maintain a facility that involves the shutdown and inspection of major processing units.

UAN	UAN is an aqueous solution of urea and ammonium nitrate used as a fertilizer.

Table of Contents

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements

CVR PARTNERS, LP AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS



	June 30, 2015			December 31, 2014
	(unaudited)
	(in thousands, except unit data)
ASSETS
Current assets:
Cash and cash equivalents	$	66,981		$	79,914
Accounts receivable, net of allowance for doubtful accounts of $18 and $34, at June 30, 2015 and December 31, 2014, respectively	10,397			7,136
Inventories	35,721			35,614
Prepaid expenses and other current assets, including $876 and $1,848 from affiliates at June 30, 2015 and December 31, 2014, respectively	4,687			6,914
Total current assets	117,786			129,578
Property, plant, and equipment, net of accumulated depreciation	397,828			404,934
Goodwill	40,969			40,969
Deferred financing costs, net	—			272
Other long-term assets, including $882 and $957 with affiliates at June 30, 2015 and December 31, 2014, respectively	3,376			3,086
Total assets	$	559,959		$	578,839
LIABILITIES AND PARTNERS’ CAPITAL
Current liabilities:
Current portion of long-term debt	$	125,000		$	—
Accounts payable, including $1,843 and $2,279 due to affiliates at June 30, 2015 and December 31, 2014, respectively	14,637			12,747
Personnel accruals, including $1,710 and $1,129 with affiliates at June 30, 2015 and December 31, 2014, respectively	4,382			3,785
Deferred revenue	1,911			13,613
Accrued expenses and other current liabilities, including $1,295 and $2,094 with affiliates at June 30, 2015 and December 31, 2014, respectively	5,695			9,562
Total current liabilities	151,625			39,707
Long-term liabilities:
Long-term debt, net of current portion	—			125,000
Other long-term liabilities	16			201
Total long-term liabilities	16			125,201
Commitments and contingencies
Partners’ capital:
Common unitholders 73,122,997 units issued and outstanding at June 30, 2015 and December 31, 2014	408,932			414,968
General partner interest	1			1
Accumulated other comprehensive loss	(615		)	(1,038)
Total partners’ capital	408,318			413,931
Total liabilities and partners’ capital	$	559,959		$	578,839

See accompanying notes to the condensed consolidated financial statements.

Table of Contents

CVR PARTNERS, LP AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS



	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015			2014

	(unaudited)
	(in thousands, except per unit data)
Net sales	$	80,815		$	77,215		$	173,865		$	157,531
Operating costs and expenses:
Cost of product sold (exclusive of depreciation and amortization) — Affiliates	2,184			2,327			4,002			4,573
Cost of product sold (exclusive of depreciation and amortization) — Third parties	13,240			17,109			37,191			36,571
	15,424			19,436			41,193			41,144
Direct operating expenses (exclusive of depreciation and amortization) — Affiliates	1,195			817			2,222			1,570
Direct operating expenses (exclusive of depreciation and amortization) — Third parties	23,951			26,100			47,338			49,536
	25,146			26,917			49,560			51,106
Selling, general and administrative expenses (exclusive of depreciation and amortization) — Affiliates	3,361			3,973			6,628			7,509
Selling, general and administrative expenses (exclusive of depreciation and amortization) — Third parties	1,162			1,297			2,478			2,415
	4,523			5,270			9,106			9,924
Depreciation and amortization	7,010			6,792			13,829			13,459
Total operating costs and expenses	52,103			58,415			113,688			115,633
Operating income	28,712			18,800			60,177			41,898
Other income (expense):
Interest expense and other financing costs	(1,717		)	(1,669		)	(3,414		)	(3,328		)
Interest income	12			6			24			12
Other income, net	5			—			11			15
Total other income (expense)	(1,700		)	(1,663		)	(3,379		)	(3,301		)
Income before income tax expense	27,012			17,137			56,798			38,597
Income tax expense (benefit)	(4		)	7			8			14
Net income	$	27,016		$	17,130		$	56,790		$	38,583

Net income per common unit – basic	$	0.37		$	0.23		$	0.78		$	0.53
Net income per common unit – diluted	$	0.37		$	0.23		$	0.78		$	0.53
Weighted-average common units outstanding:
Basic	73,123			73,113			73,123			73,113
Diluted	73,131			73,146			73,131			73,145

See accompanying notes to the condensed consolidated financial statements.

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CVR PARTNERS, LP AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME



	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015			2014

	(unaudited)
	(in thousands)
Net income	$	27,016		$	17,130		$	56,790		$	38,583
Other comprehensive income (loss):
Change in fair value of interest rate swaps	(38		)	(98		)	(110		)	(193		)
Net loss reclassified into income on settlement of interest rate swaps	266			273			533			541
Other comprehensive income (loss)	228			175			423			348
Total comprehensive income	$	27,244		$	17,305		$	57,213		$	38,931

See accompanying notes to the condensed consolidated financial statements.

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CVR PARTNERS, LP AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENT OF PARTNERS’ CAPITAL



	Common Units				General Partner Interest		Accumulated Other Comprehensive Income/(Loss)			Total
	Issued	Amount			General Partner Interest		Accumulated Other Comprehensive Income/(Loss)			Total
					(unaudited)
	(in thousands, except unit data)
Balance at December 31, 2014	73,122,997	$	414,968		$	1	$	(1,038	)	$	413,931
Cash distributions to common unitholders – Affiliates	—	(33,471		)	—		—			(33,471		)
Cash distributions to common unitholders – Non-affiliates	—	(29,415		)	—		—			(29,415		)
Share-based compensation – Affiliates	—	60			—		—			60
Net income	—	56,790			—		—			56,790
Net gains (losses) on interest rate swaps	—	—			—		423			423
Balance at June 30, 2015	73,122,997	$	408,932		$	1	$	(615	)	$	408,318

See accompanying notes to the condensed consolidated financial statements.

Table of Contents

CVR PARTNERS, LP AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS



	Six Months Ended June 30,
	2015			2014

	(unaudited)
	(in thousands)
Cash flows from operating activities:
Net income	$	56,790		$	38,583
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	13,829			13,459
Allowance for doubtful accounts	(16		)	(20		)
Amortization of deferred financing costs	479			478
(Gain) loss on disposition of fixed assets	22			406
Share-based compensation – Affiliates	1,136			1,560
Share-based compensation	289			209
Change in assets and liabilities:
Accounts receivable	(3,245		)	(353		)
Inventories	(107		)	2,151
Prepaid expenses and other current assets	2,020			3,880
Other long-term assets	(52		)	(300		)
Accounts payable	908			(2,971		)
Deferred revenue	(11,702		)	(297		)
Accrued expenses and other current liabilities	(4,395		)	3,237
Other long-term liabilities	(2		)	(68		)
Net cash provided by operating activities	55,954			59,954
Cash flows from investing activities:
Capital expenditures	(6,033		)	(7,491		)
Proceeds from sale of assets	32			91
Net cash used in investing activities	(6,001		)	(7,400		)
Cash flows from financing activities:
Cash distributions to common unitholders – Affiliates	(33,471		)	(31,525		)
Cash distributions to common unitholders – Non-affiliates	(29,415		)	(27,696		)
Redemption of common units	—			(5		)
Net cash used in financing activities	(62,886		)	(59,226		)
Net increase (decrease) in cash and cash equivalents	(12,933		)	(6,672		)
Cash and cash equivalents, beginning of period	79,914			85,142
Cash and cash equivalents, end of period	$	66,981		$	78,470
Supplemental disclosures:
Cash paid for income taxes, net	$	35		$	33
Cash paid for interest, net of capitalized interest of $79 in 2014	$	2,934		$	2,849
Non-cash investing and financing activities:
Construction in progress additions included in accounts payable	$	2,048		$	2,571
Change in accounts payable related to construction in progress	$	982		$	705

See accompanying notes to the condensed consolidated financial statements.

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CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

June 30, 2015

(unaudited)

(1) Formation of the Partnership, Organization and Nature of Business

Organization

CVR Partners, LP (referred to as "CVR Partners" or the "Partnership") is a Delaware limited partnership, formed in June 2007 by CVR Energy, Inc. (together with its subsidiaries, but excluding the Partnership and its subsidiaries, "CVR Energy") to own Coffeyville Resources Nitrogen Fertilizers, LLC ("CRNF"). CRNF is an independent producer and marketer of upgraded nitrogen fertilizer products sold in North America. CRNF operates a dual-train coke gasifier plant that produces high-purity hydrogen, most of which is subsequently converted to ammonia and upgraded to urea ammonium nitrate ("UAN").

CRNF produces and distributes nitrogen fertilizer products, which are used primarily by farmers to improve the yield and quality of their crops. CRNF's principal products are UAN and ammonia. These products are manufactured at CRNF's facility in Coffeyville, Kansas. CRNF's product sales are heavily weighted toward UAN and all of its products are sold on a wholesale basis.

Operation of Partnership

Subsequent to the closing of the Partnership's initial public offering (the "Initial Public Offering"), in April 2011 and through May 27, 2013, public security holders held approximately 30% of the Partnership's common units and Coffeyville Resources, LLC ("CRLLC"), a wholly-owned subsidiary of CVR Energy, held approximately 70% of the Partnership's common units and the general partner interest. As of June 30, 2015, Icahn Enterprises L.P. ("IEP") and its affiliates owned approximately 82% of the shares of CVR Energy.

On May 28, 2013, CRLLC sold 12,000,000 of the Partnership's common units to the public in a registered public offering (the "Secondary Offering"). The Partnership did not receive any of the proceeds from the sale of common units by CRLLC. Subsequent to the closing of the Secondary Offering and as of June 30, 2015, public security holders held approximately 47% of the Partnership's common units and CRLLC held approximately 53% of the Partnership's common units and 100% of the general partner interest.

CVR GP, LLC (“CVR GP” or the “general partner”) manages and operates the Partnership. Common unitholders have only limited voting rights on matters affecting the Partnership. In addition, common unitholders have no right to elect the general partner's directors on an annual or continuing basis.

The Partnership is operated by a combination of the general partner's senior management team and CVR Energy's senior management team pursuant to a services agreement among CVR Energy, CVR GP and the Partnership. The various rights and responsibilities of the Partnership's partners are set forth in the limited partnership agreement. The Partnership also is party to a number of agreements with CVR Energy and CVR GP to regulate certain business relations between the Partnership and the other parties thereto. See Note 13 ("Related Party Transactions") for further discussion.

(2) Basis of Presentation

The accompanying Partnership condensed consolidated financial statements include the accounts of CVR Partners and CRNF, its wholly-owned subsidiary. All intercompany accounts and transactions have been eliminated in consolidation. The accompanying condensed consolidated financial statements were prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) and in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”). These condensed consolidated financial statements should be read in conjunction with the December 31, 2014 audited consolidated financial statements and notes thereto included in CVR Partners’ Annual Report on Form 10-K for the year ended December 31, 2014, which was filed with the SEC as of February 20, 2015 (the "2014 Form 10-K").

The condensed consolidated financial statements include certain selling, general and administrative expenses and direct operating expenses that CVR Energy and its subsidiaries incurred on behalf of the Partnership. These related party transactions are governed by the services agreement. See Note 13 ("Related Party Transactions") for additional discussion of the services agreement and billing and allocation of certain costs.

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CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

June 30, 2015

(unaudited)

In the opinion of the Partnership’s management, the accompanying condensed consolidated financial statements and related notes reflect all adjustments (consisting only of normal recurring adjustments) that are necessary to fairly present the financial position of the Partnership as of June 30, 2015 and December 31, 2014, the results of operations and comprehensive income of the Partnership for the three and six months ended June 30, 2015 and 2014, the cash flows of the Partnership for the six months ended June 30, 2015 and 2014 and the changes in partners’ capital for the Partnership for the six months ended June 30, 2015.

The preparation of condensed consolidated financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, expenses and the disclosure of contingent assets and liabilities. Actual results could differ from those estimates. Results of operations and cash flows for the interim periods presented are not necessarily indicative of the results that will be realized for the year ending December 31, 2015 or any other interim or annual period.

(3) Recent Accounting Pronouncements

In May 2014, the Financial Accounting Standards Board ("FASB") issued Accounting Standard Update ("ASU") No. 2014-09, "Revenue from Contracts with Customers" ("ASU 2014-09"), which requires an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. ASU 2014-09 will replace most existing revenue recognition guidance in U.S. GAAP when it becomes effective. The standard is effective for interim and annual periods beginning after December 15, 2016 and permits the use of either the retrospective or cumulative effect transition method. Early adoption is not permitted. On July 9, 2015, the FASB approved a one-year deferral of the effective date making the standard effective for interim and annual periods beginning after December 15, 2017. The FASB will continue to permit entities to adopt the standard on the original effective date if they choose. The Partnership has not yet selected a transition method and is currently evaluating the standard and the impact on its consolidated financial statements and footnote disclosures.

In April 2015, the FASB issued ASU 2015-03, "Simplifying the Presentation of Debt Issuance Costs" ("ASU 2015-03"). The new standard requires that all costs incurred to issue debt be presented in the balance sheet as a direct deduction from the carrying value of the debt. The standard is effective for interim and annual periods beginning after December 31, 2015 and is required to be applied on a retrospective basis. Early adoption is permitted. The Partnership expects that the adoption of ASU 2015-03 will result in a reclassification of certain debt issuance costs on the Condensed Consolidated Balance Sheets.

(4) Share‑Based Compensation

Certain employees of CVR Partners and employees of CVR Energy who perform services for the Partnership under the services agreement with CVR Energy participate in equity compensation plans of CVR Partners' affiliates. Accordingly, CVR Partners has recorded compensation expense for these plans. All compensation expense related to these plans for full-time employees of CVR Partners has been allocated 100% to the Partnership. For employees of CVR Energy, the Partnership records share-based compensation relative to the percentage of time spent by each employee providing services to the Partnership as compared to the total calculated share-based compensation by CVR Energy. The Partnership is not responsible for payment of the allocated share-based compensation for certain plans as discussed below. Allocated expense amounts related to plans for which the Partnership is not responsible for payment are reflected as an increase or decrease to partners' capital.

Long-Term Incentive Plan – CVR Energy

CVR Energy has a Long-Term Incentive Plan (“CVR Energy LTIP”) that permits the grant of options, stock appreciation rights, restricted shares, restricted stock units, dividend equivalent rights, share awards and performance awards (including performance share units, performance units and performance based restricted stock). As of June 30, 2015, only grants of restricted stock units under the CVR Energy LTIP remain outstanding. Individuals who are eligible to receive awards and grants under the CVR Energy LTIP include CVR Energy’s or its subsidiaries’ (including the Partnership) employees, officers, consultants and directors.

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CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

June 30, 2015

(unaudited)

Restricted Stock Units

Through the CVR Energy LTIP, shares of restricted common stock were previously granted to employees of CVR Energy. These restricted shares are generally graded-vesting awards, which vest over a three-year period. Compensation expense is recognized on a straight-line basis over the vesting period of the respective tranche of the award. The IEP acquisition of CVR Energy and related Transaction Agreement, dated April 18, 2012, between CVR Energy and an affiliate of IEP (the “Transaction Agreement”) triggered a modification to outstanding awards under the CVR Energy LTIP. Pursuant to the Transaction Agreement, restricted shares scheduled to vest in 2013, 2014 and 2015 were converted to restricted stock units whereby the awards would be settled in cash upon vesting in an amount equal to the lesser of the offer price of $30.00 per share or the fair market value as determined at the most recent valuation date of December 31 of each year. The awards are remeasured at each subsequent reporting date until they vest.

In 2012 and 2013, restricted stock units and dividend equivalent rights were granted to certain employees of CVR Energy and its subsidiaries. The awards are expected to vest over three years, with one-third of the award vesting each year. Each restricted stock unit and dividend equivalent right represents the right to receive, upon vesting, a cash payment equal to (a) the fair market value of one share of CVR Energy's common stock, plus (b) the cash value of all dividends declared and paid per share of CVR Energy's common stock from the grant date to and including the vesting date. The awards will be remeasured at each subsequent reporting date until they vest.

Assuming the allocation of costs from CVR Energy remains consistent with the allocation percentages in place at June 30, 2015, the amount of total unrecognized compensation cost related to restricted stock units and associated dividend equivalent rights was nominal and will be recognized over a weighted-average period of approximately 0.5 years.

Inclusion of a vesting table would not be meaningful due to changes in allocation percentages that may occur from time to time. The unrecognized compensation expense has been determined by the number of restricted stock units and associated dividend equivalent rights and respective allocation percentage for individuals for whom, as of June 30, 2015, compensation expense has been allocated to the Partnership. Compensation expense recorded for the three months ended June 30, 2015 and 2014, related to the awards, was approximately $2,000 and $0.1 million, respectively. Compensation expense recorded for the six months ended June 30, 2015 and 2014, related to the awards, was approximately $28,000 and $0.1 million, respectively. The Partnership is not responsible for the payment of CVR Energy restricted stock units and associated dividend equivalent rights, and accordingly, the expenses recorded have been reflected as increases to partners' capital.

Performance Unit Awards

Mr. Lipinski, CVR Energy's Chief Executive Officer and President, had performance unit awards that were fully vested as of December 31, 2014 and reimbursed as of March 31, 2015 with no remaining performance units outstanding. Total compensation expense recorded for the three and six months ended June 30, 2014 related to the performance unit awards was $0.3 million and $0.7 million, respectively.

Incentive Unit Awards – CVR Energy

In 2013, 2014 and 2015, CVR Energy granted awards of incentive units and distribution equivalent rights to certain employees of CRLLC, CVR Energy and the Partnership's general partner who provide shared services to CVR Energy and its subsidiaries (including the Partnership). The awards are generally graded-vesting awards, which are expected to vest over three years, with one-third of the award vesting each year. Compensation expense is recognized on a straight-line basis over the vesting period of the respective tranche of the award. Each incentive unit and distribution equivalent right represents the right to receive, upon vesting, a cash payment equal to (a) the average fair market value of one common unit of CVR Refining, LP ("CVR Refining") in accordance with the award agreement, plus (b) the per unit cash value of all distributions declared and paid by CVR Refining from the grant date to and including the vesting date. The awards, which are liability-classified, are remeasured at each subsequent reporting date until they vest.

Assuming the allocation of costs from CVR Energy remains consistent with the allocation percentages in place at June 30, 2015, there was approximately $0.8 million of total unrecognized compensation cost related to the incentive units and associated distribution equivalent rights to be recognized over a weighted-average period of approximately 1.4 years.

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CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

June 30, 2015

(unaudited)

Inclusion of a vesting table would not be meaningful due to changes in allocation percentages that may occur from time to time. The unrecognized compensation expense has been determined by the number of incentive units and respective allocation percentage for individuals for whom, as of June 30, 2015, compensation expense has been allocated to the Partnership. Compensation expense recorded for the three months ended June 30, 2015 and 2014 related to the awards was approximately $0.2 million and $0.2 million, respectively. Compensation expense recorded for the six months ended June 30, 2015 and 2014 related to the awards was approximately $0.4 million and $0.3 million, respectively. The Partnership will be responsible for reimbursing CVR Energy for its allocated portion of the awards.

As of June 30, 2015 and December 31, 2014, the Partnership had a liability of $0.5 million and $0.2 million, respectively, for its allocated portion of non-vested incentive units and associated distribution equivalent rights, which is recorded in accrued expenses and other current liabilities on the Condensed Consolidated Balance Sheets.

Long-Term Incentive Plan – CVR Partners

The Partnership has a long-term incentive plan ("CVR Partners LTIP") that provides for the grant of options, unit appreciation rights, distribution equivalent rights, restricted units, phantom units and other unit-based awards. Individuals who are eligible to receive awards pursuant to the CVR Partners LTIP include (1) employees of the Partnership and its subsidiaries, (2) employees of the general partner, (3) members of the board of directors of the general partner, and (4) CVR Partners' parent's employees, consultants and directors.

Through the CVR Partners LTIP, phantom and common units have been awarded to employees of the Partnership and the general partner and to members of the board of directors of the general partner. Phantom unit awards made to employees of the general partner are considered a non-employee equity based award and are required to be marked-to-market each reporting period until they vest. Awards to employees of the Partnership and employees of the general partner vest over a three year period. The maximum number of common units issuable under the CVR Partners LTIP is 5,000,000. As of June 30, 2015, there were 4,820,215 common units available for issuance under the CVR Partners LTIP. As substantially all phantom unit awards discussed below are cash settled awards, they do not reduce the number of common units outstanding.

Certain Units and Phantom Units

In 2013 and during 2014, awards of phantom units and distribution equivalent rights were granted to certain employees of the Partnership and its subsidiaries' employees and the employees of the general partner. The awards are generally graded-vesting awards, which are expected to vest over three years with one-third of the award vesting each year. Compensation expense is recognized on a straight-line basis over the vesting period of the respective tranche of the award. Each phantom unit and distribution equivalent right represents the right to receive, upon vesting, a cash payment equal to (a) the average fair market value of one unit of the Partnership's common units in accordance with the award agreement, plus (b) the per unit cash value of all distributions declared and paid by the Partnership from the grant date to and including the vesting date. The awards, which are liability-classified, are remeasured at each subsequent reporting date until they vest.

A summary of the phantom unit activity during the six months ended June 30, 2015 is presented below:



	Phantom Units		Weighted-Average Grant Date Fair Value
Non-vested at January 1, 2015	243,946		$	11.07
Granted	—		—
Vested	—		—
Forfeited	(2,388	)	10.99
Non-vested at June 30, 2015	241,558		$	11.08

Unrecognized compensation expense associated with the unvested phantom units at June 30, 2015 was approximately $2.1 million and is expected to be recognized over a weighted average period of 1.4 years. Compensation expense recorded for the three months

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ended June 30, 2015 and 2014 related to the awards under the CVR Partners LTIP was approximately $0.4 million and $0.2 million, respectively. Compensation expense recorded for the six months ended June 30, 2015 and 2014 related to the awards under the CVR Partners LTIP was approximately $1.0 million and $0.6 million, respectively. As of June 30, 2015 and December 31, 2014 the Partnership had a liability of $1.2 million and $0.2 million, respectively, for cash settled non-vested phantom unit awards and associated distribution equivalent rights, which is recorded in personnel accruals on the Condensed Consolidated Balance Sheets.

Performance-Based Phantom Unit Award

In May 2014, the Partnership entered into a Phantom Unit Agreement with Mr. Pytosh, the Chief Executive Officer and President of the general partner, that included performance-based phantom units and distribution equivalent rights. Compensation cost for these awards is being recognized over the performance cycles of May 1, 2014 to December 31, 2014, January 1, 2015 to December 31, 2015 and January 1, 2016 to December 31, 2016, as the services are provided. Each phantom unit and distribution equivalent right represents the right to receive, upon vesting, a cash payment equal to (a) the average closing price of the Partnership's common units in accordance with the agreement, multiplied by a performance factor that is based upon the level of the Partnership’s production of UAN, and (b) the per unit cash value of all distributions declared and paid by the Partnership from the grant date to and including the vesting date. Assuming the allocation of costs from CVR Energy remains consistent with the allocation percentages in place at June 30, 2015, unrecognized compensation expense associated with the unvested units at June 30, 2015 was approximately $0.1 million and is expected to be recognized over a weighted average period of 1.0 years. Compensation expense recorded for the three months ended June 30, 2015 and 2014 related to the awards was approximately $10,000 and $46,000, respectively. Compensation expense recorded for the six months ended June 30, 2015 and 2014 related to the awards was approximately $39,000 and $46,000, respectively. The Partnership will be reimbursed by CVR Energy and CVR Refining for the portion of the award attributable to time Mr. Pytosh spends working on matters for those companies. As of June 30, 2015 and December 31, 2014, the Partnership had a nominal liability for the non-vested phantom unit award and associated distribution equivalent rights, which is recorded in personnel accruals on the Condensed Consolidated Balance Sheets.

(5) Inventories

Inventories consisted of the following:



	June 30, 2015		December 31, 2014

	(in thousands)
Finished goods	$	8,569	$	12,393
Raw materials and precious metals	10,041		9,333
Parts and supplies	17,111		13,888
	$	35,721	$	35,614

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(6) Property, Plant and Equipment

A summary of costs and accumulated depreciation for property, plant and equipment is as follows:



	June 30, 2015		December 31, 2014

	(in thousands)
Land and improvements	$	5,441	$	5,263
Buildings and improvements	2,830		2,266
Machinery and equipment	560,599		559,210
Automotive equipment	448		497
Furniture and fixtures	913		882
Railcars	14,850		14,524
Construction in progress	10,678		6,515
	$	595,759	$	589,157
Less: Accumulated depreciation	197,931		184,223
Total property, plant and equipment, net	$	397,828	$	404,934

Capitalized interest recognized as a reduction of interest expense for the three and six months ended June 30, 2014 totaled approximately $44,000 and $79,000, respectively, and was $0 for the three and six months ended June 30, 2015.

Direct operating expenses exclude depreciation and amortization of approximately $6.9 million and $6.7 million for the three months ended June 30, 2015 and 2014, respectively, and approximately $13.5 million and $13.3 million for the six months ended June 30, 2015 and 2014, respectively.

Cost of product sold expenses exclude depreciation and amortization of approximately $0.1 million and $0.1 million for the three months ended June 30, 2015 and 2014, respectively, and approximately $0.3 million and $0.2 million for the six months ended June 30, 2015 and 2014, respectively.

Depreciation and amortization excluded from selling, general and administrative expenses was nominal for the three and six months ended June 30, 2015 and 2014.

(7) Partners’ Capital and Partnership Distributions

The Partnership has two types of partnership interests outstanding:


•	common units; and


•	a general partner interest, which is not entitled to any distributions, and which is held by the general partner.

At June 30, 2015, the Partnership had a total of 73,122,997 common units issued and outstanding, of which 38,920,000 common units were owned by CRLLC, representing approximately 53% of the total Partnership units outstanding.

The board of directors of the Partnership's general partner has a policy for the Partnership to distribute all available cash generated on a quarterly basis. Cash distributions will be made to the common unitholders of record on the applicable record date, generally within 60 days after the end of each quarter. Available cash for each quarter will be determined by the board of directors of the general partner following the end of such quarter.

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Available cash for each quarter begins with Adjusted EBITDA reduced for cash needed for: (i) net cash interest expense (excluding capitalized interest) and debt service and other contractual obligations; (ii) maintenance capital expenditures; and (iii) to the extent applicable, major scheduled turnaround expenses and reserves for future operating or capital needs that the board of directors of the general partner deems necessary or appropriate, if any. Adjusted EBITDA is defined as EBITDA (net income before interest expense, net, income tax expense, depreciation and amortization) further adjusted for the impact of non-cash share-based compensation, and, where applicable, major scheduled turnaround expenses, loss on extinguishment of debt and loss on disposition of assets. 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 general partner. The board of directors of the general partner may modify the cash distribution policy at any time, and the partnership agreement does not require the board of directors of the general partner to make distributions at all.

The following is a summary of cash distributions paid to the Partnership’s unitholders during 2015 for the respective quarters to which the distributions relate:



	December 31, 2014		March 31, 2015		Total Cash Distributions Paid in 2015

	($ in millions, expect per common unit amounts)
Amount paid to CRLLC	$	16.0	$	17.5	$	33.5
Amounts paid to public unitholders	14.0		15.4		29.4
Total amount paid	$	30.0	$	32.9	$	62.9
Per common unit	$	0.41	$	0.45	$	0.86
Common units outstanding (in thousands)	73,123		73,123

On July 29, 2015, the Board of Directors of the general partner of the Partnership declared a cash distribution for the second quarter of 2015 in the amount of $0.39 per common unit, or approximately $28.5 million in aggregate. The cash distribution will be paid on August 17, 2015 to the Partnership's unitholders of record at the close of business on August 10, 2015.

(8) Net Income per Common Unit

The Partnership's net income is allocated wholly to the common units, as the general partner does not have an economic interest. Basic and diluted net income per common unit is calculated by dividing net income by the weighted-average number of common units outstanding during the period and, when applicable, gives effect to certain units granted under the CVR Partners LTIP. The common units issued during the period are included on a weighted-average basis for the days in which they were outstanding.

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(9) Accrued Expenses and Other Current Liabilities

Accrued expenses and other current liabilities were as follows:



	June 30, 2015		December 31, 2014

	(in thousands)
Property taxes	$	1,364	$	1,376
Current interest rate swap liabilities	615		855
Accrued interest	458		458
Railcar maintenance accruals	384		2,827
Other accrued expenses and liabilities (1)	2,874		4,046
	$	5,695	$	9,562

____________


(1)	Other accrued expenses and liabilities include amounts owed by the Partnership to Coffeyville Resources Refining & Marketing, LLC (“CRRM”), a related party, under the feedstock and shared services agreement and the services agreement. Refer to Note 13 ("Related Party Transactions") for additional discussion.

(10) Credit Facility

The Partnership's credit facility includes a term loan facility of $125.0 million and a revolving credit facility of $25.0 million with an uncommitted incremental facility of up to $50.0 million. No amounts were outstanding under the revolving credit facility at June 30, 2015 and December 31, 2014. There is no scheduled amortization. The credit facility matures in April 2016; therefore, the principal portion of the term loan is presented in current portion of long-term debt on the Condensed Consolidated Balance Sheet as of June 30, 2015. The Partnership is considering capital structure and refinancing options associated with the credit facility maturity.

Borrowings under the credit facility bear interest at either a Eurodollar rate or a base rate plus in either case a margin based on a pricing grid determined by the trailing four quarter leverage ratio. The margin for borrowings under the credit facility ranges from 3.50% to 4.25% for Eurodollar loans and 2.50% to 3.25% for base rate loans. Currently, the interest rate is either the Eurodollar rate plus a margin of 3.50% or, for base rate loans, the prime rate plus 2.50%. Under its terms, the lenders under the credit facility were granted a first priority security interest (subject to certain customary exceptions) in substantially all of the assets of CVR Partners and CRNF.

The credit facility requires CVR Partners to maintain a minimum interest coverage ratio and a maximum leverage ratio and contains customary covenants for a financing of this type that limit, subject to certain exceptions, the incurrence of additional indebtedness or guarantees, incurrence of liens, disposal of assets, making restricted payments, making investments or acquisitions, entry into sale-leaseback transactions and entry into affiliate transactions. The credit facility provides that the Partnership can make distributions to holders of the Partnership's common units provided the Partnership is in compliance with its leverage ratio and interest coverage ratio covenants on a pro forma basis after giving effect to such distribution and there is no default or event of default under the facility. As of June 30, 2015, CVR Partners was in compliance with the covenants contained in the credit facility.

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(11) Interest Rate Swap Agreements

CRNF has two floating-to-fixed interest rate swap agreements for the purpose of hedging the interest rate risk associated with a portion of its $125.0 million floating rate term debt which matures in April 2016, as discussed further in Note 10 ("Credit Facility"). The aggregate notional amount covered under these agreements, which commenced on August 12, 2011 and expire on February 12, 2016, totals $62.5 million (split evenly between the two agreements). Under the terms of the interest rate swap agreement entered into on June 30, 2011, CRNF receives a floating rate based on three month LIBOR and pays a fixed rate of 1.94%. Under the terms of the interest rate swap agreement entered into on July 1, 2011, CRNF receives a floating rate based on three month LIBOR and pays a fixed rate of 1.975%. Both swap agreements are settled every 90 days. The effect of these swap agreements is to lock in a fixed rate of interest of approximately 1.96% plus the applicable margin paid to lenders over three month LIBOR governed by the credit facility. At June 30, 2015, the effective rate of the term loan facility, net of impact of the interest rate swap agreements, was approximately 4.57%. The agreements were designated as cash flow hedges at inception, and accordingly, the effective portion of the gain or loss on the swap is reported as a component of accumulated other comprehensive income (loss) (“AOCI”) and will be reclassified into interest expense when the interest rate swap transaction affects earnings. Any ineffective portion of the gain or loss will be recognized immediately in interest expense. The realized loss on the interest rate swap reclassified from AOCI into interest expense and other financing costs on the Condensed Consolidated Statements of Operations was $0.3 million and $0.3 million for the three months ended June 30, 2015 and 2014, respectively, and $0.5 million and $0.5 million for the six months ended June 30, 2015 and 2014, respectively.

The interest rate swap agreements held by the Partnership also provide for the right to offset. However, as the interest rate swaps are in a liability position, there are no amounts offset in the Condensed Consolidated Balance Sheets as of June 30, 2015 and December 31, 2014. See Note 14 ("Fair Value Measurements") for discussion of the fair value of the interest rate swap agreements.

(12) Commitments and Contingencies

Leases and Unconditional Purchase Obligations

The minimum required payments for the Partnership’s operating leases and unconditional purchase obligations are as follows:



	Operating Leases		Unconditional Purchase Obligations⁽¹⁾

	(in thousands)
Six months ending December 31, 2015	$	2,780	$	10,605
Year Ending December 31,
2016	4,943		14,848
2017	3,308		14,885
2018	2,496		13,386
2019	1,897		12,113
Thereafter	3,661		65,774
	$	19,085	$	131,611

_____________


(1)	This includes the Partnership’s purchase obligation for pet coke from CVR Refining and has been derived from a calculation of the average pet coke price paid to CVR Refining over the preceding two year period. See Note 13 ("Related Party Transactions") for further discussion of the coke supply agreement.

CRNF leases railcars and facilities under long-term operating leases. Lease expense is included in cost of product sold (exclusive of depreciation and amortization) and for the three months ended June 30, 2015 and 2014 totaled approximately $1.2 million and $1.1 million, respectively. Lease expense for the six months ended June 30, 2015 and 2014 totaled approximately $2.3 million and $2.3 million, respectively. The lease agreements have various remaining terms. Some agreements are renewable, at

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CRNF’s option, for additional periods. It is expected, in the ordinary course of business, that leases will be renewed or replaced as they expire.

During 2005, CRNF entered into the Amended and Restated On-Site Product Supply Agreement with The BOC Group, Inc. (as predecessor in interest to Linde LLC). Pursuant to the agreement, which expires in 2020, CRNF is required to take as available and pay for the supply of oxygen and nitrogen to the fertilizer operation. Expenses associated with this agreement are included in direct operating expenses (exclusive of depreciation and amortization), and, for the three months ended June 30, 2015 and 2014, totaled approximately $0.8 million and $1.0 million, respectively. For the six months ended June 30, 2015 and 2014, the expense totaled approximately $1.6 million and $2.0 million, respectively.

The Partnership is a party to a pet coke supply agreement with HollyFrontier Corporation. The term of this agreement ends in December 2015 and may be renewed. The delivered cost of this pet coke is included in cost of product sold (exclusive of depreciation and amortization) and totaled approximately $1.0 million and $1.0 million, respectively, for the three months ended June 30, 2015 and 2014. For the six months ended June 30, 2015 and 2014, these expenses totaled approximately $2.3 million and $2.3 million, respectively.

Litigation

From time to time, the Partnership is involved in various lawsuits arising in the normal course of business, including matters such as those described below under "Environmental, Health and Safety ("EHS") Matters." Liabilities, if any, related to such litigation are recognized when the related costs are probable and can be reasonably estimated. These provisions are reviewed at least quarterly and adjusted to reflect the impacts of negotiations, settlements, rulings, advice of legal counsel and other information and events pertaining to a particular case. It is possible that management’s estimates of the outcomes will change within the next year due to uncertainties inherent in litigation and settlement negotiations. Except as described below, there were no new proceedings or material developments in proceedings from those provided in the 2014 Form 10-K or in the quarterly report on Form 10-Q for the quarter ended March 31, 2015, which was filed with the SEC on May 1, 2015 (the "2015 Q1 Form 10-Q"). In the opinion of management, the ultimate resolution of any other litigation matters is not expected to have a material adverse effect on the accompanying condensed consolidated financial statements. There can be no assurance that management’s beliefs or opinions with respect to liability for potential litigation matters are accurate.

Environmental, Health and Safety (“EHS”) Matters

CRNF is subject to various stringent federal, state and local EHS rules and regulations. Liabilities related to EHS matters are recognized when the related costs are probable and can be reasonably estimated. Estimates of these costs are based upon currently available facts, existing technology, site-specific costs and currently enacted laws and regulations. In reporting EHS liabilities, no offset is made for potential recoveries. All liabilities are monitored and adjusted regularly as new facts emerge or changes in laws or technology occur.

There have been no new developments or material changes to the environmental accruals or expected capital expenditures related to compliance with the foregoing environmental matters from those provided in the 2014 Form 10-K or the 2015 Q1 Form 10-Q. CRNF believes it is in substantial compliance with existing EHS rules and regulations. There can be no assurance that the EHS matters which may develop in the future will not have a material adverse effect on the Partnership's business, financial condition or results of operations.

(13) Related Party Transactions

Related Party Agreements

CVR Partners is party to, or otherwise subject to certain agreements with CVR Energy and its subsidiaries (including CVR Refining and its subsidiaries) that govern the business relations among each party including: the (i) Feedstock and Shared Services Agreement; (ii) Coke Supply Agreement; (iii) Environmental Agreement; (iv) Services Agreement; (v) GP Services Agreement and (vi) Limited Partnership Agreement. Except as otherwise described below, there have been no new developments or material changes to these agreements from those provided in the 2014 Form 10-K.

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Amounts owed to CVR Partners and CRNF from CVR Energy and its subsidiaries with respect to these agreements are included in prepaid expenses and other current assets and other long-term assets on the Condensed Consolidated Balance Sheets. Conversely, amounts owed to CVR Energy and its subsidiaries by CVR Partners and CRNF with respect to these agreements are included in accounts payable, personnel accruals and accrued expenses and other current liabilities on the Partnership's Condensed Consolidated Balance Sheets.

Feedstock and Shared Services Agreement

CRNF is party to a feedstock and shared services agreement with CRRM under which the two parties provide feedstock and other services to one another. These feedstocks and services are utilized in the respective production processes of CRRM's Coffeyville, Kansas refinery and CRNF's nitrogen fertilizer plant.

Pursuant to the feedstock and shared services agreement, CRNF and CRRM have agreed to transfer hydrogen to one another; provided, CRNF is not required to sell hydrogen to CRRM if such hydrogen is required for operation of CRNF's nitrogen fertilizer plant, if such sale would adversely affect the Partnership's classification as a partnership for federal income tax purposes, or if such sale would not be in CRNF's best interest. Net monthly sales of hydrogen to CRRM have been reflected as net sales for CVR Partners. Net monthly receipts of hydrogen from CRRM have been reflected in cost of product sold (exclusive of depreciation and amortization) for CVR Partners, when applicable. For the three months ended June 30, 2015 and 2014, the net sales generated from the sale of hydrogen to CRRM were approximately $2.0 million and $0.9 million, respectively. For the six months ended June 30, 2015 and 2014, the net sales generated from the sale of hydrogen to CRRM were approximately $8.5 million and $6.8 million, respectively. At June 30, 2015 and December 31, 2014, there were approximately $0.3 million and $1.3 million, respectively, of receivables included in prepaid expenses and other current assets on the Condensed Consolidated Balance Sheets associated with unpaid balances related to hydrogen sales.

CRNF is also obligated to make available to CRRM any nitrogen produced by the Linde air separation plant that is not required for the operation of the nitrogen fertilizer plant, as determined by CRNF in a commercially reasonable manner. Reimbursed direct operating expenses (exclusive of depreciation and amortization) associated with nitrogen for the three months ended June 30, 2015 and 2014, were approximately $0 and $0.3 million, respectively. Reimbursed direct operating expenses (exclusive of depreciation and amortization) associated with nitrogen for the six months ended June 30, 2015 and 2014, were approximately $0 and $0.5 million, respectively.

The agreement also provides a mechanism pursuant to which CRNF transfers a tail gas stream to CRRM. CRNF receives the benefit of eliminating a waste gas stream and recovers the fuel value of the tail gas system. For the three and six months ended June 30, 2015 and 2014, the net sales generated from the sale of tail gas to CRRM were nominal. In April 2011, in connection with the tail gas stream transfers to CRRM, CRRM installed a pipe between the Coffeyville, Kansas refinery and the nitrogen fertilizer plant to transfer the tail gas. CRNF agreed to pay CRRM the cost of installing the pipe and provide an additional 15% to cover the cost of capital, which is due from CRNF to CRRM over four years. At June 30, 2015 and December 31, 2014, there were assets of approximately $0.2 million and $0.2 million, respectively, included in prepaid expenses and other current assets and approximately $0.9 million and $1.0 million, respectively, included in other long-term assets. Additionally, at December 31, 2014, there was a liability of approximately $0.1 million in accrued expenses and other current liabilities in the Condensed Consolidated Balance Sheets.

At June 30, 2015 and December 31, 2014, receivables of approximately $0.1 million and $0.2 million, respectively, were included in prepaid expenses and other current assets on the Condensed Consolidated Balance Sheets for amounts yet to be received related to components of the feedstock and shared services agreement, other than amounts related to hydrogen transfers and tail gas discussed above. At June 30, 2015 and December 31, 2014, current obligations of approximately $0.8 million and $1.1 million, respectively, were included in accounts payable on the Condensed Consolidated Balance Sheets associated with unpaid balances related to components of the feedstock and shared services agreement, other than amounts related to hydrogen transfers and tail gas discussed above.

Coke Supply Agreement

CRNF is party to a coke supply agreement with CRRM pursuant to which CRRM supplies CRNF with pet coke. This agreement provides that CRRM must deliver to CRNF during each calendar year an annual required amount of pet coke equal to the lesser of

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(i) 100 percent of the pet coke produced at CRRM's Coffeyville, Kansas petroleum refinery or (ii) 500,000 tons of pet coke. CRNF is also obligated to purchase this annual required amount. If during a calendar month CRRM produces more than 41,667 tons of pet coke, then CRNF will have the option to purchase the excess at the purchase price provided for in the agreement. If CRNF declines to exercise this option, CRRM may sell the excess to a third party.

CRNF obtains most (over 70% on average during the last five years) of the pet coke it needs from CRRM's adjacent crude oil refinery pursuant to the pet coke supply agreement, and procures the remainder through a contract with HollyFrontier Corporation and on the open market. The price CRNF pays pursuant to the pet coke supply agreement is based on the lesser of a pet coke price derived from the price received for UAN, or the UAN-based price, and a pet coke price index. The UAN-based price begins with a pet coke price of $25 per ton based on a price per ton for UAN (exclusive of transportation cost), or netback price, of $205 per ton, and adjusts up or down $0.50 per ton for every $1.00 change in the netback price. The UAN-based price has a ceiling of $40 per ton and a floor of $5 per ton.

CRNF will pay any taxes associated with the sale, purchase, transportation, delivery, storage or consumption of the pet coke. CRNF is entitled to offset any amount payable for the pet coke against any amount due from CRRM under the feedstock and shared services agreement between the parties.

The cost of pet coke associated with the transfer of pet coke from CRRM to CRNF were approximately $2.1 million and $2.2 million for the three months ended June 30, 2015 and 2014, respectively, which was recorded in cost of product sold (exclusive of depreciation and amortization). For the six months ended June 30, 2015 and 2014, cost of pet coke associated with the transfer of pet coke from CRRM to CRNF was approximately $3.9 million and $4.5 million, respectively. Payables of $0.3 million and $0.5 million related to the coke supply agreement were included in accounts payable on the Condensed Consolidated Balance Sheets at June 30, 2015 and December 31, 2014, respectively.

Services Agreement

CVR Partners obtains certain management and other services from CVR Energy pursuant to a services agreement between the Partnership, CVR GP and CVR Energy.

Net amounts incurred under the services agreement for the three and six months ended June 30, 2015 and 2014 were as follows:



	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014

	(in millions)
Direct operating expenses (exclusive of depreciation and amortization) — Affiliates	$	1.0	$	0.9	$	1.9	$	1.8
Selling, general and administrative expenses (exclusive of depreciation and amortization) — Affiliates	2.5		2.7		4.9		5.3
Total	$	3.5	$	3.6	$	6.8	$	7.1

For services performed in connection with the services agreement, the Partnership recognized personnel costs, excluding amounts related to share-based compensation that are disclosed in Note 4 ("Share‑Based Compensation"), of $1.5 million and $1.5 million, respectively, for the three months ended June 30, 2015 and 2014. For services performed in connection with the services agreement, the Partnership recognized personnel costs of $2.6 million and $2.8 million, respectively, for the six months ended June 30, 2015 and 2014. At June 30, 2015 and December 31, 2014, current obligations of $2.0 million and $2.6 million, respectively, were included in accounts payable and accrued expenses and other current liabilities on the Condensed Consolidated Balance Sheets with respect to amounts billed in accordance with the services agreement. At June 30, 2015 and December 31, 2014, receivables of $0.2 million and $0.1 million, respectively, were included in prepaid expenses and other current assets on the Consolidated Balance Sheets associated for amounts yet to be received related to components of the services agreement.

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Limited Partnership Agreement

The partnership agreement provides that the Partnership will reimburse its general partner for all direct and indirect expenses it incurs or payments it makes on behalf of the Partnership (including salary, bonus, incentive compensation and other amounts paid to any person to perform services for the Partnership or for its general partner in connection with operating the Partnership). The Partnership reimbursed its general partner for the three months ended June 30, 2015 and 2014 approximately $1.0 million and $0.6 million, respectively, pursuant to the partnership agreement primarily for personnel costs related to the compensation of executives at the general partner, who manage the Partnership's business. For the six months ended June 30, 2015 and 2014, approximately $2.1 million and $0.9 million were incurred related to amounts due for reimbursement, respectively. At June 30, 2015 and December 31, 2014, current obligations of $1.7 million and $1.1 million, respectively, were included in personnel accruals on the Condensed Consolidated Balance Sheets related to amounts outstanding in accordance with the limited partnership agreement.

Insight Portfolio Group

Insight Portfolio Group LLC ("Insight Portfolio Group") is an entity formed by Mr. Icahn in order to maximize the potential buying power of a group of entities with which Mr. Icahn has a relationship in negotiating with a wide range of suppliers of goods, services and tangible and intangible property at negotiated rates. In January 2013, CVR Energy acquired a minority equity interest in Insight Portfolio Group. The Partnership participates in Insight Portfolio Group’s buying group through its relationship with CVR Energy. The Partnership may purchase a variety of goods and services as members of the buying group at prices and on terms that management believes would be more favorable than those which would be achieved on a stand-alone basis. Transactions with Insight Portfolio Group for each of the reporting periods were nominal.

(14) Fair Value Measurements

In accordance with ASC Topic 820 — Fair Value Measurements and Disclosures (“ASC 820”), the Partnership utilizes the market approach to measure fair value for its financial assets and liabilities. The market approach uses prices and other relevant information generated by market transactions involving identical or comparable assets, liabilities or a group of assets or liabilities, such as a business.

ASC 820 utilizes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three broad levels. The following is a brief description of those three levels:


•	Level 1 — Quoted prices in active markets for identical assets and liabilities


•	Level 2 — Other significant observable inputs (including quoted prices in active markets for similar assets or liabilities)


•	Level 3 — Significant unobservable inputs (including the Partnership’s own assumptions in determining the fair value).

The following table sets forth the assets and liabilities measured at fair value on a recurring basis, by input level, as of June 30, 2015 and December 31, 2014, respectively.



	June 30, 2015
	Level 1		Level 2		Level 3		Total

	(in thousands)
Financial Statement Caption and Description
Cash equivalents (money market account)	$	45,344	$	—	$	—	$	45,344
Other current liabilities (interest rate swaps)	—		615		—		615

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CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

June 30, 2015

(unaudited)



	December 31, 2014
	Level 1		Level 2		Level 3		Total

	(in thousands)
Financial Statement Caption and Description
Cash equivalents (money market account)	$	53,323	$	—	$	—	$	53,323
Other current liabilities (interest rate swaps)	—		855		—		855
Other long-term liabilities (interest rate swaps)	—		183		—		183
Total Liabilities	$	—	$	1,038	$	—	$	1,038

As of June 30, 2015 and December 31, 2014, the only financial assets and liabilities that are measured at fair value on a recurring basis are the Partnership’s money market accounts and derivative instruments. The carrying value of the Partnership’s debt approximates fair value. The Partnership has interest rate swaps that are measured at fair value on a recurring basis using Level 2 inputs. See further discussion in Note 11 (“Interest Rate Swap Agreements”). The fair values of these interest rate swap instruments are based on discounted cash flow models that incorporate the cash flows of the derivatives, as well as the current LIBOR rate and a forward LIBOR curve, along with other observable market inputs. The Partnership had no transfers of assets or liabilities between any of the above levels during the six months ended June 30, 2015.

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

The following discussion and analysis of our financial condition, results of operations and cash flows 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 the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2014 and filed with the Securities and Exchange Commission (“SEC”) as of February 20, 2015 (the "2014 Form 10-K"). Results of operations and cash flows for the three and six months ended June 30, 2015 and 2014 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 distributions, 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 under “Risk Factors” in the 2014 Form 10-K. Such factors include, among others:


•	our ability to make cash distributions on the common units;


•	the volatile nature of our business and the variable nature of our distributions;


•	the ability of our general partner to modify or revoke our distribution policy at any time;


•	the cyclical nature of our business;


•	the seasonal nature of our business;


•	the dependence of our operations on a few third-party suppliers, including providers of transportation services and equipment;


•	our reliance on pet coke that we purchase from CVR Refining;


•	the supply and price levels of essential raw materials;


•	the risk of a material decline in production at our nitrogen fertilizer plant;


•	potential operating hazards from accidents, fire, severe weather, floods or other natural disasters;

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•	competition in the nitrogen fertilizer businesses;


•	capital expenditures and potential liabilities arising from environmental laws and regulations;


•	existing and proposed environmental laws and regulations, including those relating to climate change, alternative energy or fuel sources, and the end-use and application of fertilizers;


•	new regulations concerning the transportation of hazardous chemicals, risks of terrorism and the security of chemical manufacturing facilities;


•	the risk of security breaches;


•	our lack of asset diversification;


•	our dependence on significant customers;


•	the potential loss of our transportation cost advantage over our competitors;


•	our potential inability to successfully implement our business strategies, including the completion of significant capital programs;


•	our reliance on CVR Energy’s senior management team and conflicts of interest they face operating each of CVR Partners, CVR Refining and CVR Energy;


•	risks relating to our relationships with CVR Energy and CVR Refining;


•	control of our general partner by CVR Energy;


•	our ability to continue to license the technology used in our operations;


•	restrictions in our debt agreements;


•	changes in our treatment as a partnership for U.S. federal income or state tax purposes; and


•	instability and volatility in the capital and credit markets.

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.

Partnership Overview

We are a Delaware limited partnership formed by CVR Energy to own, operate and grow our nitrogen fertilizer business. Strategically located adjacent to CVR Refining’s refinery in Coffeyville, Kansas, our nitrogen fertilizer manufacturing facility is the only operation in North America that utilizes a petroleum coke, or pet coke, gasification process to produce nitrogen fertilizer.

We produce and distribute nitrogen fertilizer products, which are used primarily by farmers to improve the yield and quality of their crops. Our principal products are UAN and ammonia. These products are manufactured at our facility in Coffeyville, Kansas. Our product sales are heavily weighted toward UAN and all of our products are sold on a wholesale basis.

Our facility includes a 1,225 ton-per-day ammonia unit, a 3,000 ton-per-day UAN unit, and a gasifier complex having a capacity of 84 million standard cubic feet per day of hydrogen. Our gasifier is a dual-train facility, with each gasifier able to function independently of the other, thereby providing redundancy and improving our reliability. With the completion of the UAN expansion in February 2013, we now upgrade substantially all of the ammonia we produce to higher margin UAN fertilizer, an aqueous solution of urea and ammonium nitrate which has historically commanded a premium price over ammonia. In 2014, we produced 963.7 thousand tons of UAN and 388.9 thousand tons of ammonia. Approximately 97% of our produced ammonia tons and the majority of the

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purchased ammonia tons were upgraded into UAN in 2014. For the three months ended June 30, 2015 and 2014, we produced 253.5 thousand tons and 223.4 thousand tons of UAN and 107.1 thousand tons and 92.2 thousand tons of ammonia, respectively. For the six months ended June 30, 2015 and 2014, we produced 505.6 thousand tons and 480.6 thousand tons of UAN and 203.0 thousand tons and 183.3 thousand tons of ammonia, respectively. For the three months ended June 30, 2015 and 2014, approximately 96% and 97%, respectively, of our produced ammonia tons and the majority of purchased ammonia tons were upgraded into UAN. For the six months ended June 30, 2015 and 2014, approximately 97% and 94%, respectively, of our produced ammonia tons and the majority of purchased ammonia tons were upgraded into UAN.

CVR Energy, which indirectly owns our general partner and approximately 53% of our outstanding common units, also indirectly owns the general partner and approximately 66% of the common units of CVR Refining at June 30, 2015. CVR Refining owns and operates a complex full coking medium-sour crude oil refinery with a rated capacity of 115,000 barrels per calendar day (bpcd) in Coffeyville, Kansas, a complex crude oil refinery with a rated capacity of 70,000 bpcd in Wynnewood, Oklahoma and ancillary businesses.

We intend to continue to expand our existing asset base and utilize the experience of our and CVR Energy’s management teams to execute our growth strategy, which includes expanded production of UAN and acquiring and building additional infrastructure and production assets.

The primary raw material feedstock utilized in our nitrogen fertilizer production process is pet coke, which is produced during the crude oil refining process. In contrast, substantially all of our nitrogen fertilizer 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 and pet coke prices have been more stable when compared to natural gas prices. By using pet coke as the primary raw material feedstock instead of natural gas, we believe our nitrogen fertilizer business has historically been one of the lower cost producers and marketers of UAN and ammonia fertilizers in North America. We currently purchase most of our pet coke from CVR Refining pursuant to a long-term agreement having an initial term that ends in 2027, subject to renewal. During the past five years, over 70% of the pet coke consumed by our plant was produced and supplied by CVR Refining’s Coffeyville, Kansas crude oil refinery.

Major Influences on Results of Operations

Our earnings and cash flows from operations are primarily affected by the relationship between nitrogen fertilizer product prices, on-stream factors and direct operating expenses. Unlike our competitors, we do not use natural gas as a feedstock and use a minimal amount of natural gas as an energy source in our operations. As a result, volatile swings in natural gas prices have a minimal impact on our results of operations. Instead, CVR Refining’s adjacent refinery supplies us with most of the pet coke feedstock we need pursuant to a 20 year pet coke supply agreement entered into in October 2007. The price at which our 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 addition, the demand for fertilizers is affected by the aggregate crop planting decisions and fertilizer application rate decisions of individual farmers. Individual farmers make planting decisions based largely on the prospective profitability of a harvest, while the specific varieties and amounts of fertilizer they apply depend on factors like crop prices, their current liquidity, soil conditions, weather patterns and the types of crops planted.

Natural gas is the most significant raw material required in our competitors’ production of nitrogen fertilizers. Over the past several years, natural gas prices have experienced high levels of price volatility. This pricing and volatility has a direct impact on our competitors' cost of producing nitrogen fertilizer.

In order to assess our operating performance, we calculate the product pricing at gate as an input to determine our operating margin. Product pricing at gate represents net sales less freight revenue divided by product sales volume in tons. We believe product pricing at gate is a meaningful measure because we sell products at our plant gate and terminal locations' gates ("sold gate") and delivered to the

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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.

We and other competitors in the U.S. farm belt share a significant transportation cost advantage when compared to our out-of-region competitors in serving the U.S. farm belt agricultural market. In 2014, approximately 49% of the corn planted in the United States was grown within an estimated $45 per UAN ton freight train rate of our nitrogen fertilizer plant. We are therefore able to cost-effectively sell substantially all of our products in the higher margin agricultural market, whereas a significant portion of our competitors’ revenues is derived from the lower margin industrial market. Our products leave the plant either in railcars for destinations located principally on the Union Pacific Railroad or in trucks for direct shipment to customers. We do not currently incur significant intermediate transfer, storage, barge freight or pipeline freight charges; however, we do incur costs to maintain and repair our railcar fleet. Selling products to customers within economic rail transportation limits of the nitrogen fertilizer plant and keeping transportation costs low are keys to maintaining profitability.

The high fixed cost of our direct operating expense structure also directly affects our profitability. Our facility’s pet coke gasification process results in a significantly higher percentage of fixed costs than a natural gas-based fertilizer plant. Major fixed operating expenses include electrical energy, employee labor, maintenance, including contract labor and outside services. We estimate these fixed costs averaged approximately 80% of direct operating expenses over the 24 months ended June 30, 2015.

Our largest raw material expense used in the production of ammonia is pet coke, which we purchase from CVR Refining and third parties. For the three months ended June 30, 2015 and 2014, we incurred approximately $3.1 million and $3.2 million, respectively, for the cost of pet coke, which equaled an average cost per ton of $25 and $27. For the six months ended June 30, 2015 and 2014, we incurred approximately $6.7 million and $6.8 million, respectively, for the cost of pet coke, which equaled an average cost per ton of $27 and $28.

Consistent, safe and reliable operations at our nitrogen fertilizer plant are critical to our financial performance and results of operations. Unplanned downtime of the plant 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. Historically, the nitrogen fertilizer plant has undergone a full facility turnaround every two to three years. Turnarounds are expected to last 14-21 days. A less involved facility shutdown was performed during the second quarter of 2014 and included both the installation of a waste heat boiler and the completion of several key tasks in order to upgrade the pressure swing adsorption unit. The Partnership is planning to undergo the next full facility turnaround in the third quarter of 2015 and we currently anticipate the cost will be approximately $7.0 million.

Agreements with CVR Energy and CVR Refining

We are party to several agreements with CVR Energy and its affiliates that govern the business relations among us, CVR Energy and its subsidiaries (including CVR Refining), and our general partner. These include the pet coke supply agreement under which we buy the pet coke we use in our nitrogen fertilizer plant; a services agreement, under which CVR Energy and its subsidiaries provide us with management services including the services of its senior management team; a feedstock and shared services agreement, which governs the provision of feedstocks, including, but not limited to, hydrogen, high-pressure steam, nitrogen, instrument air, oxygen and natural gas; a raw water and facilities sharing agreement, which allocates raw water resources between the two businesses; an easement agreement; an environmental agreement; and a lease agreement pursuant to which we lease office space and laboratory space. These agreements were not the result of arm's-length negotiations and the terms of these agreements are not necessarily as favorable to the parties to these agreements as terms which could have been obtained from unaffiliated third parties. See Note 13 ("Related Party Transactions") to Part I, Item 1 of this Report for additional discussion of the agreements.

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Factors Affecting Comparability of Our Financial Results

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 reason discussed below.

May 2014 Downtime

During the three months ended June 30, 2014, the gasification, ammonia and UAN units were taken down for between 5 to 7 days each for a planned installation of a waste heat boiler and our completion of several key tasks in order to upgrade to the pressure swing adsorption unit. Overall results were negatively impacted due to the lost production during the downtime and the resulting reduced sales and associated cost of product sold. The Partnership incurred costs related to the repairs and maintenance and other associated costs of approximately $0.5 million, which were recognized in direct operating expenses (exclusive of depreciation and amortization) in the Condensed Consolidated Statements of Operation during the three months ended June 30, 2014.

Results of Operations

The period to period comparisons of our results of operations have been prepared using the historical periods included in our consolidated financial statements. In order to effectively review and assess our historical financial information below, we have also included supplemental operating measures and industry measures that we believe are material to understanding our business.

To supplement our actual results calculated in accordance with GAAP for the applicable periods, the Partnership also uses certain non-GAAP financial measures, which are reconciled to our GAAP-based results below. These non-GAAP financial measures should not be considered as an alternative to GAAP results.

The following tables summarize the financial data and key operating statistics for CVR Partners and our operating subsidiary for the three and six months ended June 30, 2015 and 2014. The following data should be read in conjunction with our condensed consolidated financial statements and the notes thereto included elsewhere in this Report. All information in “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” except for the balance sheet data as of December 31, 2014, is unaudited.

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	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015			2014

	(in millions)
Consolidated Statements of Operations Data:
Net sales	$	80.8		$	77.2		$	173.9		$	157.5
Cost of product sold – Affiliates (1)	2.2			2.3			4.0			4.5
Cost of product sold – Third parties (1)	13.2			17.1			37.2			36.6
	15.4			19.4			41.2			41.1
Direct operating expenses – Affiliates (1) (2)	1.2			0.8			2.2			1.6
Direct operating expenses – Third parties (1) (3)	23.5			26.1			47.0			49.5
Major scheduled turnaround expenses	0.4			—			0.4			—
	25.1			26.9			49.6			51.1
Selling, general and administrative expenses – Affiliates (1) (2)	3.4			4.0			6.6			7.5
Selling, general and administrative expenses – Third parties (1)	1.2			1.3			2.5			2.4
	4.6			5.3			9.1			9.9
Depreciation and amortization	7.0			6.8			13.8			13.5
Operating income	28.7			18.8			60.2			41.9
Interest expense and other financing costs	(1.7		)	(1.7)			(3.4		)	(3.3)
Interest income	—			—			—			—
Other income, net	—			—			—			—
Total other income (expense)	(1.7		)	(1.7		)	(3.4		)	(3.3		)
Income before income tax expense	27.0			17.1			56.8			38.6
Income tax expense (benefit)	—			—			—			—
Net income	$	27.0		$	17.1		$	56.8		$	38.6
EBITDA (4)	$	35.7		$	25.6		$	74.0		$	55.4
Adjusted EBITDA (4)	$	36.1		$	25.7		$	74.5		$	55.7
Available cash for distribution (5)	$	28.4		$	24.0		$	61.0		$	51.8

Reconciliation to net sales:
Sales net at gate	$	70.5		$	69.2		$	149.7		$	136.2
Freight in revenue	7.8			6.7			14.8			13.5
Hydrogen revenue	2.0			0.9			8.5			6.8
Other	0.5			0.4			0.9			1.0
Total net sales	$	80.8		$	77.2		$	173.9		$	157.5



	As of June 30, 2015			As of December 31, 2014
				(audited)
	(in millions)
Balance Sheet Data:
Cash and cash equivalents	$	67.0		$	79.9
Working capital (deficiency) (6)	(33.8		)	89.9
Total assets	560.0			578.8
Total debt, including current portion	125.0			125.0
Total long-term liabilities	—			125.2
Total partners’ capital	408.3			413.9

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	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015			2014

	(in millions)
Cash Flow Data:
Net cash flow provided by (used in):
Operating activities	$	30.6		$	24.4		$	56.0		$	59.9
Investing activities	(3.4		)	(4.0		)	(6.0		)	(7.4		)
Financing activities	(32.9		)	(27.8		)	(62.9		)	(59.2		)
Net increase (decrease) in cash and cash equivalents	$	(5.7	)	$	(7.4	)	$	(12.9	)	$	(6.7	)

Capital expenditures for property, plant and equipment	$	3.4		$	4.1		$	6.0		$	7.5

______________


(1)	Amounts are shown exclusive of depreciation and amortization. Amounts excluded from selling, general and administrative expenses are nominal. Depreciation and amortization is primarily comprised of the following components:



	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014

	(in millions)
Depreciation and amortization excluded from direct operating expenses	$	6.9	$	6.7	$	13.5	$	13.3
Depreciation and amortization excluded from cost of product sold	0.1		0.1		0.3		0.2
	$	7.0	$	6.8	$	13.8	$	13.5

(2)

Our selling, general and administrative expenses and direct operating expenses include amounts for share-based compensation charges, which include amounts related to CVR Energy's share-based compensation expense allocated to us by CVR Energy for financial reporting purposes. See Note 4 ("Share‑Based Compensation") to Part I, Item 1 of this Report for further discussion of allocated share-based compensation. The charges for allocated share-based compensation was approximately $0.1 million and $0.6 million, respectively, for the three months ended June 30, 2015 and 2014, which was included in selling, general and administrative expenses (exclusive of depreciation and amortization) on the Condensed Consolidated Statement of Operations. The charges for share-based compensation in selling, general and administrative expenses (exclusive of depreciation and amortization) were $0.4 million and $1.1 million for the six months ended June 30, 2015 and 2014, respectively. The amounts included in direct operating expenses (exclusive of depreciation and amortization) were nominal for the three and six months ended June 30, 2015 and 2014.


(3)	Amounts are shown exclusive of major scheduled turnaround expenses that are separately disclosed.


(4)	EBITDA is defined as net income before (i) interest (income) expense, (ii) income tax expense and (iii) depreciation and amortization expense.

Adjusted EBITDA is defined as EBITDA further adjusted for the impact of non-cash share-based compensation, and, when applicable, major scheduled turnaround expenses, loss on extinguishment of debt and loss on disposition of assets.

We present EBITDA because we believe it allows users of our financial statements, such as investors and analysts, to assess our financial performance without regard to financing methods, capital structure or historical cost basis. We present Adjusted EBITDA because we have found it helpful to consider an operating measure that excludes expenses, such as major scheduled turnaround expenses, loss on extinguishment of debt and loss on disposition of assets, relating to transactions not reflective of our core operations. When applicable, each of these expenses is discussed in the Management’s Discussion and Analysis of Financial Condition and Results of Operations section of our SEC reports, so that investors have complete information about expenses. In addition, we believe that it is useful to exclude from Adjusted EBITDA non-cash share-based compensation, although it is a recurring cost incurred in the ordinary course of business. In our view, non-cash share-based compensation, which also is presented in our financial statements and discussed herein, reflects a non-cash cost which may obscure, for a given period, trends in the underlying business, due to the timing and nature of the equity awards. We also present Adjusted

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EBITDA because it is the starting point used by the board of directors of our general partner when calculating our available cash for distribution.

EBITDA and Adjusted EBITDA are not recognized terms under GAAP and should not be substituted for net income or cash flows from operations. Management believes that EBITDA and Adjusted EBITDA enable investors and analysts to better understand our ability to make distributions to common unitholders, help investors and analysts evaluate our ongoing operating results and allow for greater transparency in reviewing our overall financial, operational and economic performance by allowing investors to evaluate the same information used by management. EBITDA and Adjusted EBITDA presented by other companies may not be comparable to our presentation, since each company may define these terms differently.

A reconciliation of our Net Income to EBITDA and Adjusted EBITDA is as follows:



	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014

	(in millions)
Net income	$	27.0	$	17.1	$	56.8	$	38.6
Add:
Interest expense and other financing costs, net	1.7		1.7		3.4		3.3
Depreciation and amortization	7.0		6.8		13.8		13.5
EBITDA	$	35.7	$	25.6	$	74.0	$	55.4
Add:
Major scheduled turnaround expenses	0.4		—		0.4		—
Share-based compensation, non-cash	—		0.1		0.1		0.3
Adjusted EBITDA	$	36.1	$	25.7	$	74.5	$	55.7

(5)

The board of directors of our general partner has a policy to calculate available cash for distribution starting with Adjusted EBITDA. For the three and six months ended June 30, 2015 and 2014, available cash for distribution equaled our Adjusted EBITDA reduced for cash needed for (i) net cash interest expense (excluding capitalized interest) and debt service and other contractual obligations; (ii) maintenance capital expenditures; and (iii) to the extent applicable, major scheduled turnaround expenses and reserves for future operating or capital needs that the board of directors of the general partner deemed necessary or appropriate, 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 our general partner. Actual distributions are set by the board of directors of our general partner. The board of directors of our general partner may modify our cash distribution policy at any time, and our partnership agreement does not require us to make distributions at all.

Available cash for distribution is not a recognized term under GAAP. Available cash for distribution should not be considered in isolation or as an alternative to net income or operating income, or any other measure of financial performance or operating performance. In addition, available cash for distribution is not presented as, and should not be considered, an alternative to cash flows from operations or as a measure of liquidity. Available cash for distribution as reported by the Partnership may not be comparable to similarly titled measures of other entities, thereby limiting its usefulness as a comparative measure.

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A reconciliation of the available cash for distribution is as follows:



	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015			2014

	(in millions, except units and per unit data)

Adjusted EBITDA	$	36.1		$	25.7		$	74.5		$	55.7
Adjustments:
Less:
Net cash interest expense (excluding capitalized interest) and debt service	(1.5		)	(1.4		)	(2.9		)	(2.9		)
Maintenance capital expenditures	(2.2		)	(1.0		)	(3.6		)	(2.0		)
Major scheduled turnaround expenses	(0.4		)	—			(0.4		)	—
Cash reserves for future turnaround expenses	(4.0		)	—			(7.0		)	—
Plus:
Release of cash reserves established for turnaround expenses	0.4			—			0.4			—
Release of previously established cash reserves, net	—			0.7			—			1.0
Available cash for distribution	$	28.4		$	24.0		$	61.0		$	51.8
Available cash for distribution, per common unit	$	0.39		$	0.33		$	0.84		$	0.71
Common units outstanding (in thousands)	73,123			73,114			73,123			73,114


(6)	Working capital (deficiency) includes $125.0 million for the current portion of long-term debt as of June 30, 2015. Working capital excluding the current portion of long-term debt was $91.2 million as of June 30, 2015.

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The following tables show selected information about key operating statistics and market indicators for our business:



	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015			2014
Key Operating Statistics:
Production volume (thousand tons):
Ammonia (gross produced) (1)	107.1			92.2			203.0			183.3
Ammonia (net available for sale) (1)(2)	4.4			3.2			19.1			12.1
UAN	253.5			223.4			505.6			480.6
Pet coke consumed (thousand tons)	128.2			117.3			253.1			242.1
Pet coke consumed (cost per ton) (3)	$	25		$	27		$	27		$	28
Sales (thousand tons):
Ammonia	6.3			2.9			19.1			8.3
UAN	249.8			239.2			524.3			493.9
Product pricing at gate (dollars per ton) (4):
Ammonia	$	546		$	521		$	551		$	493
UAN	$	269		$	283		$	265		$	267
On-stream factors (5):
Gasification	100.0		%	94.2		%	99.7		%	96.5		%
Ammonia	99.3		%	88.1		%	96.9		%	90.1		%
UAN	96.6		%	85.9		%	97.2		%	91.4		%



	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
Market Indicators:
Natural gas NYMEX (dollars per MMbtu)	$	2.74	$	4.58	$	2.77	$	4.65
Ammonia – Southern Plains (dollars per ton)	$	546	$	561	$	550	$	501
UAN – Corn belt (dollars per ton)	$	305	$	333	$	309	$	332

____________


(1)	Gross tons produced for ammonia represent total ammonia produced, including ammonia produced that was upgraded into UAN. Net tons available for sale represent ammonia available for sale that was not upgraded into UAN.


(2)	In addition to the produced ammonia, the Partnership acquired approximately 0.6 thousand tons and 2.7 thousand tons of ammonia during the three months ended June 30, 2015 and 2014, respectively. The Partnership acquired approximately 21.8 thousand tons and 25.6 thousand tons of ammonia during the six months ended June 30, 2015 and 2014, respectively.

(3)

Our pet coke cost per ton purchased from CVR Refining averaged $21 and $24 for the three months ended June 30, 2015 and 2014, respectively. Third-party pet coke prices averaged $39 and $41 for the three months ended June 30, 2015 and 2014, respectively. For the six months ended June 30, 2015 and 2014, our pet coke cost per ton purchased from CVR Refining averaged $21 and $24, respectively. For the six months ended June 30, 2015 and 2014, third-party pet coke prices averaged $42 and $40, respectively.


(4)	Product pricing at gate represents net 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.


(5)	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. Excluding the impact of the shutdown for installation of the waste heat boiler, pressure swing adsorption unit upgrade and the Linde air separation unit maintenance, the on-stream factors for the three months ended

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June 30, 2014 would have been 100.0% for gasifier, 94.9% for ammonia and 92.9% for UAN and the on-stream factors for the six months ended June 30, 2014 would have been 99.4% for gasifier, 93.5% for ammonia and 95.0% for UAN.

Three Months Ended June 30, 2015 Compared to the Three Months Ended June 30, 2014

Net Sales. Net sales were $80.8 million for the three months ended June 30, 2015 compared to $77.2 million for the three months ended June 30, 2014. The increase of $3.6 million was primarily the result of higher UAN sales volumes ($3.3 million), higher ammonia sales volumes ($1.9 million), and higher hydrogen sales volumes ($1.1 million), partially offset by lower UAN sales prices ($2.9 million). For the three months ended June 30, 2015, UAN and ammonia made up $74.8 million and $3.5 million of our net sales, respectively. This compared to UAN and ammonia net sales of $74.4 million and $1.5 million, respectively, for the three months ended June 30, 2014. The following table demonstrates the impact of changes in sales volumes and pricing for UAN, ammonia and hydrogen for the three months ended June 30, 2015 as compared to the three months ended June 30, 2014:



	Three Months Ended June 30, 2015					Three Months Ended June 30, 2014					Total Variance
	Volume(1)	$ per ton(2)		Sales $(3)		Volume(1)	$ per ton(2)		Sales $(3)		Volume(1)	Sales $(3)		Price Variance			Volume Variance

UAN	249,790	$	299	$	74.8	239,216	$	311	$	74.4	10,574	$	0.4	$	(2.9	)	$	3.3
Ammonia	6,307	$	560	$	3.5	2,854	$	542	$	1.5	3,453	$	2.0	$	0.1		$	1.9
Hydrogen	207,543	$	10	$	2.0	92,967	$	10	$	0.9	114,576	$	1.1	$	—		$	1.1

____________

(1) UAN and ammonia sales volumes are in tons. Hydrogen sales volumes are in MSCF.

(2) Includes freight charges. Hydrogen is based on $ per MSCF.

(3) Sales dollars in millions.

The increase in UAN and ammonia sales volume for the three months ended June 30, 2015 compared to the three months ended June 30, 2014 was primarily attributable to increased production due to the May 2014 downtime. On-stream factors (total number of hours operated divided by total hours in the reporting period) for the gasification, ammonia and UAN units were 100.0%, 99.3% and 96.6%, respectively, for the three months ended June 30, 2015. Product pricing at gate for the three months ended June 30, 2015 compared to the three months ended June 30, 2014 decreased 4.9% for UAN and increased 4.8% for ammonia.

Cost of Product Sold (Exclusive of Depreciation and Amortization). Cost of product sold (exclusive of depreciation and amortization) includes cost of freight and distribution expenses, pet coke expense and purchased ammonia costs. Cost of product sold (exclusive of depreciation and amortization) for the three months ended June 30, 2015 was $15.4 million, compared to $19.4 million for the three months ended June 30, 2014. The $4.0 million decrease resulted from $3.9 million in lower costs from transactions with third parties and lower costs from transactions with affiliates of $0.1 million. The lower third-party costs incurred during the three months ended June 30, 2015 were primarily the result of lower distribution costs ($2.0 million) mostly due to the decrease in railcar regulatory inspections and repairs, ammonia purchases ($1.1 million) and other less significant changes. The decrease in railcar regulatory inspections and repairs is related to a smaller portion of our fleet due for regulatory inspections and related repairs during the three months ended June 30, 2015 as compared to three months ended June 30, 2014.

Direct Operating Expenses (Exclusive of Depreciation and Amortization). Direct operating expenses (exclusive of depreciation and amortization) consist primarily of energy and utility costs, direct costs of labor, property taxes, plant-related maintenance services, including turnaround and environmental and safety compliance costs as well as catalyst and chemical costs. Direct operating expenses (exclusive of depreciation and amortization) for the three months ended June 30, 2015 were $25.1 million as compared to $26.9 million for the three months ended June 30, 2014. The $1.8 million decrease resulted primarily from lower outside services ($0.7 million), refractory brick amortization ($0.7 million), utilities, net ($0.6 million) and repairs and maintenance ($0.5 million), partially offset by turnaround expenses ($0.4 million) and chemicals ($0.3 million).

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affiliates. Selling, general and administrative expenses (exclusive of depreciation and amortization) were $4.6 million for the three months ended June 30, 2015 and $5.3 million for the three months ended June 30, 2014. The $0.7 million decrease resulted primarily from a $0.6 million decrease in costs of transactions with affiliates and a $0.1 million decrease in costs of transactions with third parties. The overall variance was primarily the result of a decrease in share-based compensation ($0.3 million) and expenses related to the services agreement, exclusive of share-based compensation ($0.3 million).

Operating Income. Operating income was $28.7 million for the three months ended June 30, 2015, as compared to operating income of $18.8 million for the three months ended June 30, 2014. The increase of $9.9 million for the three months ended June 30, 2015 as compared to the three months ended June 30, 2014 was the result of the increase in net sales ($3.6 million) and decreases in cost of product sold ($4.0 million), direct operating expenses ($1.8 million), selling general and administrative expenses ($0.7 million), partially offset by an increase in depreciation and amortization ($0.2 million).

Six Months Ended June 30, 2015 Compared to the Six Months Ended June 30, 2014

Net Sales. Net sales were $173.9 million for the six months ended June 30, 2015 compared to $157.5 million for the six months ended June 30, 2014. The increase of $16.4 million was primarily the result of higher UAN sales volumes ($9.0 million), higher ammonia sales volumes ($5.6 million), higher hydrogen sales volumes ($1.4 million) and higher ammonia sales prices ($1.0 million), partially offset by lower UAN sales prices ($0.8 million). For the six months ended June 30, 2015, UAN and ammonia made up $153.7 million and $10.8 million of our net sales, respectively. This compared to UAN and ammonia net sales of $145.5 million and $4.2 million, respectively, for the six months ended June 30, 2014. The following table demonstrates the impact of changes in sales volumes and pricing for UAN, ammonia and hydrogen for the six months ended June 30, 2015 as compared to the six months ended June 30, 2014:



	Six Months Ended June 30, 2015					Six Months Ended June 30, 2014					Total Variance
	Volume(1)	$ per ton(2)		Sales $(3)		Volume(1)	$ per ton(2)		Sales $(3)		Volume(1)	Sales $(3)		Price Variance			Volume Variance

UAN	524,330	$	293	$	153.7	493,886	$	295	$	145.5	30,444	$	8.2	$	(0.8	)	$	9.0
Ammonia	19,128	$	562	$	10.8	8,301	$	511	$	4.2	10,827	$	6.6	$	1.0		$	5.6
Hydrogen	807,821	$	11	$	8.5	671,431	$	10	$	6.8	136,390	$	1.7	$	0.3		$	1.4

____________

(1) UAN and ammonia sales volumes are in tons. Hydrogen sales volumes are in MSCF.

(2) Includes freight charges. Hydrogen is based on $ per MSCF.

(3) Sales dollars in millions.

The increase in UAN and ammonia sales volume for the six months ended June 30, 2015 compared to the six months ended June 30, 2014 was primarily attributable to increased production. On-stream factors (total number of hours operated divided by total hours in the reporting period) for the gasification, ammonia and UAN units were 99.7%, 96.9% and 97.2%, respectively, for the six months ended June 30, 2015. Product pricing at gate for the six months ended June 30, 2015 compared to the six months ended June 30, 2014 slightly decreased 0.7% for UAN and increased 11.8% for ammonia.

Cost of Product Sold (Exclusive of Depreciation and Amortization). Cost of product sold (exclusive of depreciation and amortization) includes cost of freight and distribution expenses, pet coke expense and purchased ammonia costs. Cost of product sold (exclusive of depreciation and amortization) for the six months ended June 30, 2015 was $41.2 million, compared to $41.1 million for the six months ended June 30, 2014. The $0.1 million increase resulted from $0.6 million in higher costs from transactions with third parties, partially offset by lower costs from transactions with affiliates of $0.5 million. The higher third-party costs incurred during the six months ended June 30, 2015 were primarily the result of increased UAN and ammonia sales volumes, including associated freight expenses ($0.9 million), as discussed above, and higher third-party pet coke costs ($0.5 million), partially offset by lower distribution costs ($3.5 million) mostly due to the decrease in railcar regulatory inspections and repairs. The decrease in railcar regulatory inspections and repairs is related to a smaller portion of our fleet due for regulatory inspections and related repairs during the six months ended June 30, 2015 as compared to six months ended June 30, 2014. The decrease in affiliate costs during the six months ended June 30, 2015 was primarily the result of lower pet coke pricing from CVR Refining.

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Direct Operating Expenses (Exclusive of Depreciation and Amortization). Direct operating expenses (exclusive of depreciation and amortization) consist primarily of energy and utility costs, direct costs of labor, property taxes, plant-related maintenance services, including turnaround and environmental and safety compliance costs as well as catalyst and chemical costs. Direct operating expenses (exclusive of depreciation and amortization) for the six months ended June 30, 2015 were $49.6 million as compared to $51.1 million for the six months ended June 30, 2014. The $1.5 million decrease resulted primarily from lower outside services ($1.6 million), utilities, net ($1.1 million) and refractory brick amortization ($1.1 million), partially offset by higher labor ($0.8 million), repairs and maintenance ($0.6 million) and turnaround expenses ($0.4 million).

Selling, General and Administrative Expenses (Exclusive of Depreciation and Amortization). Selling, general and administrative expenses include the direct selling, general and administrative expenses of our business as well as certain expenses incurred by our affiliates, CVR Energy and Coffeyville Resources, on our behalf and billed or allocated to us in accordance with the applicable agreements. We also reimburse our general partner in accordance with the partnership agreement for expenses it incurs on our behalf. Reimbursed expenses to our general partner are included as selling, general and administrative expenses from affiliates. Selling, general and administrative expenses (exclusive of depreciation and amortization) were $9.1 million for the six months ended June 30, 2015 and $9.9 million for the six months ended June 30, 2014. The $0.8 million decrease resulted primarily from a $0.9 million decrease in costs of transactions with affiliates, partially offset by a $0.1 million increase in costs of transactions with third parties. The overall variance was primarily the result of an increase in expenses related to the services agreement, exclusive of share-based compensation ($0.8 million) and share-based compensation ($0.4 million), partially offset an increase in reimbursements of our general partner, exclusive of share-based compensation ($0.3 million) and expenses related to personnel costs, exclusive of share-based compensation ($0.2 million).

Operating Income. Operating income was $60.2 million for the six months ended June 30, 2015, as compared to operating income of $41.9 million for the six months ended June 30, 2014. The increase of $18.3 million for the six months ended June 30, 2015 as compared to the six months ended June 30, 2014 was the result of the increase in net sales ($16.4 million) and decreases in direct operating expenses ($1.5 million) and selling general and administrative expenses ($0.8 million), partially offset by an increase in depreciation and amortization ($0.3 million) and cost of product sold ($0.1 million).

Liquidity and Capital Resources

Our principal source of liquidity has historically been cash from operations, which can include cash advances from customers resulting from forward sales. Our principal uses of cash are funding our operations, distributions to common unitholders, capital expenditures and funding our debt service obligations.

As discussed in Note 10 ("Credit Facility") to Part I, Item I of this Report, the Partnership's credit facility matures in April 2016 and the $125.0 million principal portion of the term loan is presented as a current liability as of June 30, 2015. We are considering various capital structure and refinancing options in association with the credit facility maturity. We anticipate these options will be adequate to fund the cash requirements of the maturing credit facility.

We believe that our cash from operations, remaining proceeds from the Initial Public Offering and available borrowings under our revolving credit facility, together with the options management is considering as discussed above, will be adequate to satisfy anticipated commitments and planned capital expenditures for the next twelve months. However, our future capital expenditures and other cash requirements could be higher than we currently expect as a result of various factors. Additionally, our ability to generate sufficient cash from our operating activities and secure additional financing depends on our future performance, which is subject to general economic, political, financial, competitive and other factors outside of our control.

Depending on the needs of our business, contractual limitations and market conditions, we may from time to time seek to issue equity securities, incur additional debt, issue debt securities, or otherwise refinance our existing debt. There can be no assurance that we will seek to do any of the foregoing or that we will be able to do any of the foregoing on terms acceptable to us or at all. Further discussion of declared cash distributions is included below under "Distributions to Unitholders."

Cash Balance and Other Liquidity

As of June 30, 2015, we had cash and cash equivalents of $67.0 million, including $1.9 million of customer advances. Working capital deficiency at June 30, 2015 was $33.8 million, consisting of $117.8 million in current assets and approximately $151.6 million in current liabilities, which includes the current portion of long-term debt of $125.0 million. Working capital at December 31, 2014 was $89.9 million, consisting of $129.6 million in current assets and $39.7 million in current liabilities. As of July 28, 2015, we had cash and cash equivalents of $77.2 million.

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Credit Facility

On April 13, 2011 in conjunction with the completion of our Initial Public Offering, we entered into a credit facility with a group of lenders including Goldman Sachs Lending Partners LLC, as administrative and collateral agent. The credit facility includes a term loan facility of $125.0 million and a revolving credit facility of $25.0 million with an uncommitted incremental facility of up to $50.0 million. There is no scheduled amortization and the credit facility matures in April 2016, as discussed above. The credit facility is available to finance on-going working capital, capital projects, letter of credit issuances and general needs of the Partnership.

Borrowings under the credit facility bear interest based on a pricing grid determined by a trailing four quarter leverage ratio. Pricing for borrowings under the credit facility is currently based on the Eurodollar rate plus a margin of 3.50%, or, for base rate loans, the prime rate plus 2.50%. Under its terms, the lenders under the credit facility were granted a perfected, first priority security interest (subject to certain customary exceptions) in substantially all of the assets of CVR Partners and CRNF and all of the capital stock of CRNF and each domestic subsidiary owned by CVR Partners or CRNF. CRNF is the borrower under the credit facility. All obligations under the credit facility are unconditionally guaranteed by CVR Partners and substantially all of our future, direct and indirect, domestic subsidiaries.

As of June 30, 2015 and December 31, 2014, no amounts were drawn under the $25.0 million revolving credit facility.

Mandatory Prepayments

We are required to prepay outstanding amounts under our term facility in an amount equal to the net proceeds from the sale of assets or from insurance or condemnation awards related to collateral, in each case subject to certain reinvestment rights. In addition, we are required to prepay outstanding amounts under our term facility with the net proceeds from certain issuances of debt (other than debt permitted to be incurred under our credit facility).

Voluntary Prepayments/Commitment Reductions

At any time, we may voluntarily reduce the unutilized portion of the revolving commitment amount, or prepay, in whole or in part, outstanding amounts under our credit facility without premium or penalty other than customary "breakage" costs with respect to Eurodollar rate loans.

Amortization and Final Maturity

There is no scheduled amortization under our credit facility. All outstanding amounts under our credit facility are due and payable in full in April 2016.

Restrictive Covenants and Other Matters

Our credit facility requires us to maintain (i) a minimum interest coverage ratio (as defined in the credit agreement) as of the end of any fiscal quarter of 3.0 to 1.0 and (ii) a maximum leverage ratio (as defined in the credit agreement) as of the end of any fiscal quarter of 3.0 to 1.0, in both cases calculated on a trailing four quarter basis. In addition, the credit facility includes negative covenants that, subject to significant exceptions, limit our ability and the ability of certain of our subsidiaries to, among other things:


•	incur, assume or permit to exist additional indebtedness, guarantees and other contingent obligations;


•	incur liens;


•	make negative pledges;


•	pay dividends or make other distributions;


•	make payments to our subsidiary;


•	make certain loans and investments;


•	consolidate, merge or sell all or substantially all of our assets;

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•	enter into sale-leaseback transactions; and


•	enter into transactions with affiliates.

The credit facility provides that we can make distributions to holders of our common units, but only if we are in compliance with our leverage ratio and interest coverage ratio covenants on a pro forma basis after giving effect to any distribution and there is no default or event of default under the facility.

The credit facility contains certain customary representations and warranties, affirmative covenants and events of default, including, among other things, payment defaults, breach of representations and warranties, covenant defaults, cross-defaults to certain indebtedness, certain events of bankruptcy, certain events under ERISA, material judgments, actual or asserted failure of any guaranty or security document supporting the credit facility to be in force and effect, and change of control. An event of default will also be triggered if CVR Energy, CVR Refining or any of their subsidiaries (other than us and CRNF) terminates or violates any of its covenants in any of the intercompany agreements between us and CVR Energy, CVR Refining and their subsidiaries (other than us and CRNF) and such action has resulted or could reasonably be expected to result in a material adverse effect on us. If an event of default occurs, the administrative agent under the credit facility would be entitled to take various actions, including the acceleration of amounts due under the credit facility and all actions permitted to be taken by a secured creditor.

As of June 30, 2015, we were in compliance with the covenants under the credit facility.

Interest Rate Swaps

Our profitability and cash flows are affected by changes in interest rates on our credit facility borrowings, specifically LIBOR and prime rates. The primary purpose of our interest rate risk management activities is to hedge our exposure to changes in interest rates by using interest rate derivatives to convert some or all of the interest rates we pay on our borrowings from a floating rate to a fixed interest rate.

We have determined that the two Interest Rate Swaps agreements entered into in 2011 qualify for hedge accounting treatment. The impact recorded for the three months ended June 30, 2015 and 2014 was $0.3 million and $0.3 million, respectively, in interest expense. For the three months ended June 30, 2015 and 2014, the Partnership recorded a loss of approximately $0 and a loss of $0.1 million, respectively, in the fair market value on the interest rate swaps. The impact recorded for the six months ended June 30, 2015 and 2014 was $0.5 million and $0.5 million, respectively, in interest expense. For the six months ended June 30, 2015 and 2014, the Partnership recorded a loss of $0.1 million and a loss of $0.2 million, respectively, in the fair market value on the interest rate swaps. The fair market value of the interest rate swaps recorded in accrued expenses and other current liabilities on the Partnership's Condensed Consolidated Balance Sheets as of June 30, 2015 is $0.6 million. This amount is unrealized and, therefore, included in accumulated other comprehensive income (loss).

Capital Spending

Our total capital expenditures for the six months ended June 30, 2015 were approximately $6.0 million. We divide our capital spending needs into two categories: maintenance and growth. Maintenance capital spending includes only non-discretionary maintenance projects and projects required to comply with environmental, health and safety regulations. We also treat maintenance capital spending as a reduction of cash available for distribution to unitholders. Growth capital projects generally involve an expansion of existing capacity, improvement in product yields and/or a reduction in direct operating expenses. Of the $6.0 million spent for the six months ended June 30, 2015, approximately $3.6 million was related to maintenance capital projects and the remainder was related to growth capital projects. Major scheduled turnaround expenses as discussed in "Major Influences on Results of Operations" are expensed when incurred.

Capital spending for our business has been and will be determined by the Board of Directors of our general partner. Future capital spending estimates may change as a result of unforeseen circumstances and a change in our plans and may be revised from time to time or amounts may not be spent in the manner discussed herein. Our maintenance capital expenditures are expected to be approximately $10.0 million to $12.0 million for the year ending December 31, 2015.

Planned capital expenditures for 2015 are subject to change due to unanticipated increases in the cost, scope and completion time for our capital projects. For example, we may experience increases in labor or equipment costs necessary to comply with government regulations or to complete projects that sustain or improve the profitability of our nitrogen fertilizer plant.

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Distributions to Unitholders

The board of directors of the Partnership's general partner has a policy for the Partnership to distribute all available cash generated on a quarterly basis. Our policy is disclosed in Note 7 ("Partners’ Capital and Partnership Distributions") to Part I, Item I of this Report.



	December 31, 2014		March 31, 2015		Total Cash Distributions Paid in 2015

	($ in millions, expect per common unit amounts)
Amount paid to CRLLC	$	16.0	$	17.5	$	33.5
Amounts paid to public unitholders	14.0		15.4		29.4
Total amount paid	$	30.0	$	32.9	$	62.9
Per common unit	$	0.41	$	0.45	$	0.86
Common units outstanding (in thousands)	73,123		73,123

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Cash Flows

The following table sets forth our cash flows for the periods indicated below:



	Six Months Ended June 30,
	2015			2014

	(in millions)
Net cash flow provided by (used in):
Operating activities	$	56.0		$	59.9
Investing activities	(6.0		)	(7.4		)
Financing activities	(62.9		)	(59.2		)
Net increase (decrease) in cash and cash equivalents	$	(12.9	)	$	(6.7	)

Cash Flows Provided by Operating Activities

For purposes of this cash flow discussion, we define trade working capital as accounts receivable, inventory and accounts payable. Other working capital is defined as all other current assets and liabilities except trade working capital.

Net cash flows provided by operating activities for the six months ended June 30, 2015 were approximately $56.0 million. Fluctuations in trade working capital decreased our operating cash flow by $2.4 million due to an increase in accounts receivable of $3.2 million and inventory of $0.1 million, partially offset by an increase in accounts payable of $0.9 million. The increase in accounts receivable was primarily attributable to an increase in sales and normal fluctuations in the timing of payments. Fluctuations in other working capital of $14.1 million decreased our operating cash flow and were due to a decrease in deferred revenue of $11.7 million, a decrease to accrued expenses and other current liabilities of $4.4 million, partially offset by a decrease to prepaid expenses and other current assets of $2.0 million for the six months ended June 30, 2015. The decrease in deferred revenue was primarily attributable to lower market demand for prepaid contracts and increased sales for the six months ended June 30, 2015. The decrease in accrued expenses and other current liabilities was primarily attributable to a decrease in balances related to accrued railcar regulatory inspections of $2.4 million due to a larger portion of our fleet due for regulatory inspections and repairs during 2014.

Net cash flows provided by operating activities for the six months ended June 30, 2014 were $59.9 million. Fluctuations in trade working capital decreased our operating cash flow by $1.2 million due to a decrease in accounts payable of $3.0 million and an increase in accounts receivable of $0.4 million, partially offset by a decrease in inventory of $2.2 million. The decrease in accounts payable is primarily attributable to a decrease in accrued intercompany charges of $3.3 million, partially offset by an increase due to normal changes in business operations. The decrease in inventory was due to a decrease in finished goods inventory as a result of the May 2014 downtime resulting in lower production and an increase use of parts and supplies. Fluctuations in other working capital of $6.8 million increased our operating cash flow and were due to a decrease in prepaid expenses and other current assets of $3.9 million and an increase to accrued expenses and other current liabilities of $3.2 million, partially offset by a decrease to deferred revenue of $0.3 million. The decrease to prepaid expenses and other current assets was primarily attributable to a decrease in intercompany amounts due from CRRM that included a decrease in the transfer of hydrogen and a decrease in prepaid insurance. The increase in accrued expenses and other current liabilities was primarily attributable to an increase in accrued railcar regulatory inspections and repairs due to a larger portion of our fleet due for regulatory inspections and repairs.

Cash Flows Used in Investing Activities

Net cash used in investing activities for the six months ended June 30, 2015 was $6.0 million compared to $7.4 million for the six months ended June 30, 2014. For the six months ended June 30, 2015 and 2014, net cash used in investing activities was primarily the result of capital expenditures.

Cash Flows Used in Financing Activities

Net cash flows used in financing activities for the six months ended June 30, 2015 were $62.9 million, compared to net cash flows used in financing activities for the six months ended June 30, 2014 of $59.2 million. The net cash used in financing activities for the six months ended June 30, 2015 and 2014 was attributable to quarterly cash distributions.

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Contractual Obligations

As of June 30, 2015, our contractual obligations included long-term debt, operating leases, unconditional purchase obligations, other specified capital and commercial commitments and interest payments. There were no material changes outside the ordinary course of our business with respect to our contractual obligations during the six months ended June 30, 2015, from those disclosed in our 2014 Form 10-K.

Off-Balance Sheet Arrangements

We do not have any "off-balance sheet arrangements" as such term is defined within the rules and regulations of the SEC.

Recent Accounting Pronouncements

Critical Accounting Policies

Our critical accounting policies are disclosed in the “Critical Accounting Policies” section of our 2014 Form 10-K. No modifications have been made to our critical accounting policies.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk

Interest Rate Risk

The Partnership has exposure to interest rate risk on 50% of its $125.0 million floating rate term debt. A 1% increase over the Eurodollar floor spread of 3.5%, as specified in the credit facility, would increase interest cost to the Partnership by approximately $625,000 on an annualized basis, thus decreasing net income by the same amount. We are party to two swap agreements for the purpose of hedging the interest rate risk associated with a portion of our credit facility. Our credit facility is disclosed in Note 10 ("Credit Facility") and our interest rate swap agreements are discussed in Note 11 ("Interest Rate Swap Agreements") to Part I, Item I of this Report.

Commodity Price, Foreign Currency Exchange and Non-Operating Risks

We do not currently use derivative financial instruments to manage risks related to changes in prices of commodities (e.g., UAN, ammonia or pet coke). Given that our business is currently based entirely in the United States, we are not directly exposed to foreign currency exchange rate risk. We do not engage in activities that expose us to speculative or non-operating risks, including derivative trading activities. In the opinion of our management, there is no derivative financial instrument that correlates effectively with, and has a trading volume sufficient to hedge, our firm commitments and forecasted commodity purchase or sales transactions. Our management will continue to monitor whether financial derivatives become available which could effectively hedge identified risks. Our management may, in the future, elect to use derivative financial instruments consistent with our overall business objectives to avoid unnecessary risk and to limit, to the extent practical, risks associated with our operating activities.

Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

As of June 30, 2015, we have evaluated, under the direction of our Executive Chairman, Chief Executive Officer and Chief Financial Officer, the effectiveness of our disclosure controls and procedures, as defined in Rule 13a-15(e) under the Securities Exchange Act of 1934, as amended (the "Exchange Act"). There are inherent limitations to the effectiveness of any system of disclosure controls and procedures, including the possibility of human error and the circumvention or overriding of the controls and procedures. Accordingly, even effective disclosure controls and procedures can only provide reasonable assurance of achieving their control objectives. Based upon and as of the date of that evaluation, our Executive Chairman, Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were effective to provide reasonable assurance that information required to be disclosed in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to the Partnership’s management, including our Executive Chairman, Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure. It should be noted that any system of disclosure controls and procedures, however well designed and operated, can provide only reasonable, and not absolute, assurance that the objectives of the system are met. In addition, the design of any system of disclosure controls and procedures is based in part upon assumptions about the likelihood of future events. Due to these and other inherent limitations of any such system, there can be no assurance that any design will always succeed in achieving its stated goals under all potential future conditions.

Changes in Internal Control Over Financial Reporting

There has been no material change in our internal control over financial reporting required by Rule 13a-15 of the Exchange Act that occurred during the fiscal quarter ended June 30, 2015 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

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Part II. Other Information

Item 1. Legal Proceedings

See Note 12 (“Commitments and Contingencies”) to Part I, Item I of this Report, which is incorporated by reference into this Part II, Item 1, for a description of certain litigation, legal and administrative proceedings and environmental matters.

Item 1A. Risk Factors

There have been no material changes from the risk factors previously disclosed in the “Risk Factors” section of our 2014 Form 10-K.

Item 6. Exhibits



Exhibit Number	Exhibit Title

31.1*	Rule 13a-14(a) or 15d-14(a) Certification of Executive Chairman.
31.2*	Rule 13a-14(a) or 15d-14(a) Certification of Chief Executive Officer and President.
31.3*	Rule 13a-14(a) or 15d-14(a) Certification of Chief Financial Officer and Treasurer.
32.1*	Section 1350 Certification of Executive Chairman.
32.2*	Section 1350 Certification of Chief Executive Officer and President.
32.3*	Section 1350 Certification of Chief Financial Officer and Treasurer.
101*	The following financial information for CVR Partners, LP’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2015, formatted in XBRL (“Extensible Business Reporting Language”) includes: (1) Condensed Consolidated Balance Sheets (unaudited), (2) Condensed Consolidated Statements of Operations (unaudited), (3) Condensed Consolidated Statements of Comprehensive Income (Loss) (unaudited), (4) Condensed Consolidated Statement of Partners’ Capital (unaudited), (5) Condensed Consolidated Statements of Cash Flows (unaudited) and (6) the Notes to Condensed Consolidated Financial Statements (unaudited), tagged in detail.
_________ *	Filed herewith.

PLEASE NOTE: Pursuant to the rules and regulations of the SEC, we may file or incorporate by reference agreements referenced as exhibits to the reports that we file with or furnish to the SEC. The agreements are filed to provide investors with information regarding their respective terms. The agreements are not intended to provide any other factual information about the Partnership or its business or operations. In particular, the assertions embodied in any representations, warranties and covenants contained in the agreements may be subject to qualifications with respect to knowledge and materiality different from those applicable to investors and may be qualified by information in confidential disclosure schedules not included with the exhibits. These disclosure schedules may contain information that modifies, qualifies and creates exceptions to the representations, warranties and covenants set forth in the agreements. Moreover, certain representations, warranties and covenants in the agreements may have been used for the purpose of allocating risk between the parties, rather than establishing matters as facts. In addition, information concerning the subject matter of the representations, warranties and covenants may have changed after the date of the respective agreement, which subsequent information may or may not be fully reflected in the Partnership’s public disclosures. Accordingly, investors should not rely on the representations, warranties and covenants in the agreements as characterizations of the actual state of facts about the Partnership or its business or operations on the date hereof.

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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 thereunto duly authorized.



	CVR Partners, LP

	By:	CVR GP, LLC, its general partner

July 30, 2015	By:	/s/ JOHN J. LIPINSKI
		Executive Chairman
		(Principal Executive Officer)

July 30, 2015	By:	/s/ MARK A. PYTOSH
		Chief Executive Officer and President
		(Principal Executive Officer)

July 30, 2015	By:	/s/ SUSAN M. BALL
		Chief Financial Officer and Treasurer
		(Principal Financial and Accounting Officer)