CVR PARTNERS, LP - Quarter Report: 2014 June (Form 10-Q)

Large accelerated filer þ

Accelerated filer o

Non-accelerated filer o

Smaller reporting company o

(Do not check if smaller reporting company.)

Table of Contents

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, 2014


¨	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 73,113,537 common units outstanding at July 28, 2014.

CVR PARTNERS, LP AND SUBSIDIARIES

INDEX TO QUARTERLY REPORT ON FORM 10-Q

For The Quarter Ended June 30, 2014



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

	Condensed Consolidated Balance Sheets — June 30, 2014 (unaudited) and December 31, 2013	5

	Condensed Consolidated Statements of Operations — Three and Six Months Ended June 30, 2014 and 2013 (unaudited)	6

	Condensed Consolidated Statements of Comprehensive Income – Three and Six Months Ended June 30, 2014 and 2013 (unaudited)	7

	Condensed Consolidated Statement of Partners’ Capital — Six Months Ended June 30, 2014 (unaudited)	8

	Condensed Consolidated Statements of Cash Flows — Six Months Ended June 30, 2014 and 2013 (unaudited)	9

	Notes to the Condensed Consolidated Financial Statements — June 30, 2014 (unaudited)	10

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	27

Item 3.	Quantitative and Qualitative Disclosures About Market Risk	45

Item 4.	Controls and Procedures	46

Part II. Other Information

Item 1.	Legal Proceedings	47

Item 1A.	Risk Factors	47

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	47

Item 6.	Exhibits	48

Signatures		49

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, 2014 (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 medium complexity 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 CRLLC.

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.

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.

prepaid sales	Represents customer payments under contracts to guarantee a price and supply of fertilizer in quantities expected to be delivered in the next twelve months. Revenue is not recorded for such sales until the product is considered delivered. Prepaid sales are also referred to as deferred revenue.

product pricing at gate	Product pricing at gate per ton represents net sales less freight revenue divided by product sales volume in tons.

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, 2014			December 31, 2013
	(unaudited)
	(in thousands, except unit data)
ASSETS
Current assets:
Cash and cash equivalents	$	78,470		$	85,142
Accounts receivable, net of allowance for doubtful accounts of $30 and $50, at June 30, 2014 and December 31, 2013, respectively	7,922			7,549
Inventories	30,913			33,064
Prepaid expenses and other current assets, including $436 and $3,104 from affiliates at June 30, 2014 and December 31, 2013, respectively	6,147			10,025
Total current assets	123,452			135,780
Property, plant, and equipment, net of accumulated depreciation	407,173			412,956
Goodwill	40,969			40,969
Deferred financing costs, net	758			1,236
Other long-term assets, including $1,046 and $1,136 with affiliates at June 30, 2014 and December 31, 2013, respectively	2,836			2,513
Total assets	$	575,188		$	593,454
LIABILITIES AND PARTNERS’ CAPITAL
Current liabilities:
Accounts payable, including $2,557 and $4,289 due to affiliates at June 30, 2014 and December 31, 2013, respectively	$	16,247		$	17,137
Personnel accruals, including $1,036 and $2,025 with affiliates at June 30, 2014 and December 31, 2013, respectively	2,948			4,494
Deferred revenue	399			696
Accrued expenses and other current liabilities, including $2,713 and $323 with affiliates at June 30, 2014 and December 31, 2013, respectively	9,970			5,059
Total current liabilities	29,564			27,386
Long-term liabilities:
Long-term debt, net of current portion	125,000			125,000
Other long-term liabilities, $67 with affiliates at December 31, 2013	693			1,147
Total long-term liabilities	125,693			126,147
Commitments and contingencies
Partners’ capital:
Common unitholders, 73,113,537 and 73,112,951 units issued and outstanding at June 30, 2014 and December 31, 2013, respectively	421,481			441,819
General partner interest	1			1
Accumulated other comprehensive loss	(1,551		)	(1,899)
Total partners’ capital	419,931			439,921
Total liabilities and partners’ capital	$	575,188		$	593,454

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,
	2014			2013			2014			2013
	(unaudited)
	(in thousands, except per unit data)
Net sales	$	77,215		$	88,834		$	157,531		$	170,245
Operating costs and expenses:
Cost of product sold — Affiliates	2,327			2,761			4,573			5,850
Cost of product sold (exclusive of depreciation and amortization) — Third parties	17,109			12,810			36,571			20,375
	19,436			15,571			41,144			26,225
Direct operating expenses (exclusive of depreciation and amortization) — Affiliates	817			1,205			1,570			2,208
Direct operating expenses (exclusive of depreciation and amortization) — Third parties	26,100			23,213			49,536			44,767
	26,917			24,418			51,106			46,975
Selling, general and administrative expenses (exclusive of depreciation and amortization) — Affiliates	3,973			4,153			7,509			8,372
Selling, general and administrative expenses (exclusive of depreciation and amortization) — Third parties	1,297			1,439			2,415			2,850
	5,270			5,592			9,924			11,222
Depreciation and amortization	6,792			6,193			13,459			11,960
Total operating costs and expenses	58,415			51,774			115,633			96,382
Operating income	18,800			37,060			41,898			73,863
Other income (expense):
Interest expense and other financing costs	(1,669		)	(1,675		)	(3,328		)	(2,955		)
Interest income	6			24			12			54
Other income, net	—			46			15			55
Total other expense	(1,663		)	(1,605		)	(3,301		)	(2,846		)
Income before income tax expense	17,137			35,455			38,597			71,017
Income tax expense	7			18			14			27
Net income	$	17,130		$	35,437		$	38,583		$	70,990
Net income per common unit – basic	$	0.23		$	0.48		$	0.53		$	0.97
Net income per common unit – diluted	$	0.23		$	0.48		$	0.53		$	0.97
Weighted-average common units outstanding:
Basic	73,113			73,068			73,113			73,067
Diluted	73,146			73,230			73,145			73,232

See accompanying notes to the condensed consolidated financial statements.

Table of Contents

CVR PARTNERS, LP AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME



	Three Months Ended June 30,					Six Months Ended June 30,
	2014			2013		2014			2013
	(unaudited)
	(in thousands)
Net income	$	17,130		$	35,437	$	38,583		$	70,990
Other comprehensive income (loss):
Change in fair value of interest rate swap	(98		)	201		(193		)	155
Net loss reclassified into income on settlement of interest rate swap	273			263		541			521
Other comprehensive income (loss)	175			464		348			676
Total comprehensive income	$	17,305		$	35,901	$	38,931		$	71,666

See accompanying notes to the condensed consolidated financial statements.

Table of Contents

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, 2013	73,112,951		$	441,819		$	1	$	(1,899	)	$	439,921
Cash distributions to common unitholders – Affiliates	—		(31,525		)	—		—			(31,525		)
Cash distributions to common unitholders – Non-affiliates	—		(27,696		)	—		—			(27,696		)
Share-based compensation – Affiliates	—		305			—		—			305
Issuance of units under LTIP – Affiliates	814		—			—		—			—
Redemption of common units	(228	)	(5		)	—		—			(5		)
Net income	—		38,583			—		—			38,583
Net gains (losses) on interest rate swaps	—		—			—		348			348
Balance at June 30, 2014	73,113,537		$	421,481		$	1	$	(1,551	)	$	419,931

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,
	2014			2013
	(unaudited)
	(in thousands)
Cash flows from operating activities:
Net income	$	38,583		$	70,990
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	13,459			11,960
Allowance for doubtful accounts	(20		)	(10		)
Amortization of deferred financing costs	478			478
(Gain) loss on disposition of fixed assets	406			(33		)
Share-based compensation – Affiliates	1,560			2,007
Share-based compensation	209			158
Change in assets and liabilities:
Accounts receivable	(353		)	1,853
Inventories	2,151			(3,886		)
Prepaid expenses and other current assets	3,880			(2,626		)
Other long-term assets	(300		)	(102		)
Accounts payable	(2,971		)	(373		)
Deferred revenue	(297		)	540
Accrued expenses and other current liabilities	3,237			(6,228		)
Other long-term liabilities	(68		)	(106		)
Net cash provided by operating activities	59,954			74,622
Cash flows from investing activities:
Capital expenditures	(7,491		)	(31,852		)
Proceeds from sale of assets	91			33
Net cash used in investing activities	(7,400		)	(31,819		)
Cash flows from financing activities:
Cash distributions to common unitholders – Affiliates	(31,525		)	(40,838		)
Cash distributions to common unitholders – Non-affiliates	(27,696		)	(17,760		)
Redemption of common units	(5		)	(171		)
Net cash used in financing activities	(59,226		)	(58,769		)
Net increase (decrease) in cash and cash equivalents	(6,672		)	(15,966		)
Cash and cash equivalents, beginning of period	85,142			127,848
Cash and cash equivalents, end of period	$	78,470		$	111,882
Supplemental disclosures:
Cash paid for income taxes	$	33		$	28
Cash paid for interest, net of capitalized interest of $79 and $467 in 2014 and 2013, respectively	$	2,849		$	2,508
Non-cash investing and financing activities:
Construction in progress additions included in accounts payable	$	2,571		$	6,701
Change in accounts payable related to construction in progress	$	705		$	(11,970	)

See accompanying notes to the condensed consolidated financial statements.

Table of Contents

CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

June 30, 2014

(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, 2014, IEP Energy LLC and certain affiliates (collectively "IEP") owned approximately 82% of the shares of CVR Energy.

On May 28, 2013, CRLLC sold 12,000,000 of our common units to the public at a price of $25.15 per unit in a registered public offering (the "Secondary Offering"). The net proceeds to CRLLC from the Secondary Offering were approximately $292.6 million, after deducting approximately $9.2 million in underwriting discounts and commissions. We 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, 2014, public security holders held approximately 47% of the Partnership's common units and CRLLC held approximately 53% of the Partnership's common units and 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. In October 2007, the Partnership's partners at that time entered into an amended and restated limited partnership agreement setting forth their various rights and responsibilities. The Partnership also entered into 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”), including Article 3 of Regulation S-X, “General Instructions as to Consolidated Financial Statements.” These condensed consolidated financial statements should be read in conjunction with the December 31, 2013 audited consolidated financial statements and notes thereto included in CVR Partners’ Annual Report on Form 10-K for the year ended December 31, 2013, which was filed with the SEC on February 26, 2014 (the "2013 Form 10-K").

Table of Contents

CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

June 30, 2014

(unaudited)

The condensed consolidated financial statements include certain selling, general and administrative expenses (exclusive of depreciation and amortization) and direct operating expenses that CVR Energy 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. The amounts charged or allocated to the Partnership are not necessarily indicative of the costs that the Partnership would have incurred had it operated as an independent entity.

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, 2014 and December 31, 2013, the results of operations and comprehensive income of the Partnership for the three and six months ended June 30, 2014 and 2013, the cash flows of the Partnership for the six months ended June 30, 2014 and 2013 and the changes in partners’ capital for the Partnership for the six months ended June 30, 2014.

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 and expenses. Actual results could differ from those estimates. Results of operations and cash flows are not necessarily indicative of the results that will be realized for the year ending December 31, 2014, 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. 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.

(4) Share‑Based Compensation

Certain employees of CVR Partners and employees of CVR Energy who perform services for the Partnership participate in equity compensation plans of CVR Partners' affiliates. Accordingly, CVR Partners has recorded compensation expense for these plans in accordance with Staff Accounting Bulletin ("SAB") Topic 1-B (“Allocations of Expenses and Related Disclosures in Financial Statements of Subsidiaries, Divisions or Lesser Business Components of Another Entity”) and in accordance with guidance regarding the accounting for share-based compensation granted to employees of an equity method investee. 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, 2014, only grants of restricted stock units and performance 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.

Table of Contents

CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

June 30, 2014

(unaudited)

Restricted Stock Units

Through the CVR Energy LTIP, restricted shares have been granted to employees of CVR Energy and the Partnership. The IEP acquisition of CVR Energy and related Transaction Agreement dated April 18, 2012 between CVR Energy and IEP (“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 will 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, which generally vest over a three-year period, will be remeasured at each subsequent reporting date until they vest.

In December 2012 and during 2013, restricted stock units and dividend equivalent rights were granted to certain employees of CVR Energy and its subsidiaries (including the Partnership). The awards are scheduled to vest over three years, with one-third of the award vesting each year with the exception of awards granted to certain executive officers scheduled to vest over one year. Awards granted in December 2012 to Mr. Lipinski, CVR Energy's Chief Executive Officer and President, were canceled in connection with the issuance of certain performance unit awards as discussed further below. 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, 2014, there was approximately $0.3 million of total unrecognized compensation cost related to restricted stock units and associated dividend equivalent rights to be recognized over a weighted-average period of approximately 0.8 years. Inclusion of a vesting table would not be meaningful due to changes in allocation percentages that 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, 2014, compensation expense has been allocated to the Partnership. Compensation expense recorded for the three months ended June 30, 2014 and 2013, related to the awards, was approximately $0.1 million and $0.5 million, respectively. Compensation expense recorded for the six months ended June 30, 2014 and 2013, related to the awards, was approximately $0.1 million and $1.2 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 for the six months ended June 30, 2014 and 2013 have been reflected as an increase to partners' capital.

Performance Unit Awards

In December 2013, CVR Energy entered into Performance Unit Award Agreements with Mr. Lipinski. Certain of the Performance Unit Awards were entered into in connection with the cancellation of Mr. Lipinski's December 2012 restricted stock unit award, as discussed above. In accordance with accounting guidance related to the modification of share-based and other compensatory award arrangements, CVR Energy concluded that the cancellation and concurrent issuance of the performance awards created a substantive service period from the original grant date of the December 2012 restricted stock unit award through the end of the performance period for the related performance awards. Compensation cost for the related awards is being recognized over the substantive service period. 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. The Partnership will be responsible for reimbursing CVR Energy for its allocated portion of the performance unit awards. As of June 30, 2014 this obligation of $1.1 million is recorded in accrued expenses and other current liabilities on the Condensed Consolidated Balance Sheet.

Table of Contents

CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

June 30, 2014

(unaudited)

Incentive Unit Awards

In December 2013 and during 2014, CVR Energy granted awards of incentive units and distribution equivalent rights to certain employees of CRLLC and CVR Energy who provide shared services to CVR Energy and its subsidiaries (including the Partnership). The awards generally vest over three years, with one-third of the award vesting each year. 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") for the first ten trading days in the month of vesting, 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, 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, 2014, 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 1.5 years. Inclusion of a vesting table would not be meaningful due to changes in allocation percentages that occur from time to time. The unrecognized compensation expense has been determined by the number of incentive units and associated distribution equivalent rights and respective allocation percentage for individuals for whom, as of June 30, 2014, compensation expense has been allocated to the Partnership. Compensation expense recorded for the three and six months ended June 30, 2014 related to the awards was $0.2 million and $0.3 million. The Partnership will be responsible for reimbursing CVR Energy for its allocated portion of the awards. As of June 30, 2014 this obligation of $0.3 million is recorded in accrued expenses and other current liabilities on the Condensed Consolidated Balance Sheet.

Long-Term Incentive Plan – CVR Partners

In connection with the Initial Public Offering, the board of directors of the general partner adopted the CVR Partners, LP Long-Term Incentive Plan ("CVR Partners LTIP"). Individuals who are eligible to receive awards under 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. The CVR Partners LTIP provides for the grant of options, unit appreciation rights, distribution equivalent rights, restricted units, phantom units and other unit-based awards. 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 and members of the board of directors 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 the general partner generally vest over three years with one-third of the award vesting each year. Awards to members of the board of directors of the general partner generally vest immediately on the grant date. The maximum number of common units issuable under the CVR Partners LTIP is 5,000,000. As of June 30, 2014, there were 4,809,048 common units available for issuance under the CVR Partners LTIP.

Common Units and Certain Phantom Units Awards

In December 2012, the board of directors of the general partner approved an amendment to modify the terms of certain phantom unit awards granted to employees of the Partnership and its subsidiaries. Prior to the amendment, the phantom units, when granted, were valued at the closing market price of the Partnership's common units on the date of issuance and amortized to compensation expense on a straight-line basis over the vesting period of the units. These phantom units generally vest over a three-year period. The amendment triggered a modification to the awards by providing that the phantom units would be settled in cash rather than in common units of the Partnership. For awards vesting subsequent to the amendment, the awards will be remeasured at each subsequent reporting date until they vest. As a result of the modification of the awards, the classification changed from equity-classified awards to liability-classified awards.

In December 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 generally vest over three years on the basis of one-third of the award each year. 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 for the first ten trading days in the month of vesting, 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, will be remeasured at each subsequent reporting date until they vest.

Table of Contents

CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

June 30, 2014

(unaudited)

A summary of the common units and phantom units (collectively “Units”) activity during the six months ended June 30, 2014 is presented below:



	Units		Weighted-Average Grant Date Fair Value
Non-vested at January 1, 2014	171,119		$	21.34
Granted	5,093		18.86
Vested	(814	)	21.05
Forfeited	(64,629	)	23.36
Non-vested at June 30, 2014	110,769		$	20.06

Unrecognized compensation expense associated with the unvested common and phantom units at June 30, 2014 was approximately $1.1 million and is expected to be recognized over a weighted average period of 1.2 years. In conjunction with Mr. Kelley's resignation that was effective January 1, 2014, all awards granted to him that were non-vested at the resignation date were forfeited. Due to the timing of this event, the Partnership had reflected the impact of this event in determining the unrecognized compensation expense as the resignation was expected at December 31, 2013. The associated change to the non-vested units forfeited was reflected at the resignation date and is included in the summary presented above. Compensation expense recorded for the three months ended June 30, 2014 and 2013 related to the awards under the CVR Partners LTIP was approximately $0.2 million and $0.4 million, respectively. Compensation expense recorded for the six months ended June 30, 2014 and 2013 related to the awards under the CVR Partners LTIP was approximately $0.6 million and $1.0 million, respectively. As of June 30, 2014 and December 31, 2013 the Partnership had a liability of $0.6 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 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 for the first ten business days of the last month of the performance cycle, 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, 2014, unrecognized compensation expense associated with the unvested units at June 30, 2014 was approximately $0.3 million and is expected to be recognized over a weighted average period of 1.5 years. Compensation expense recorded for the three months ended June 30, 2014 related to the award was nominal. 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, 2014, the Partnership had a 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.

Table of Contents

CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

June 30, 2014

(unaudited)

(5) Inventories

Inventories consisted of the following:



	June 30, 2014		December 31, 2013
	(in thousands)
Finished goods	$	7,933	$	8,849
Raw materials and precious metals	8,091		8,546
Parts and supplies	14,889		15,669
	$	30,913	$	33,064

(6) Property, Plant, and Equipment

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



	June 30, 2014		December 31, 2013
	(in thousands)
Land and improvements	$	5,161	$	5,032
Buildings and improvements	2,213		2,191
Machinery and equipment	553,788		548,282
Automotive equipment	450		450
Furniture and fixtures	890		893
Railcars	7,875		7,902
Construction in progress	7,315		5,294
	$	577,692	$	570,044
Less: Accumulated depreciation	170,519		157,088
Total property, plant and equipment, net	$	407,173	$	412,956

Capitalized interest recognized as a reduction of interest expense for the three months ended June 30, 2014 and 2013 totaled approximately $44,000 and $0.1 million, respectively. For the six months ended June 30, 2014 and 2013, capitalized interest recognized as a reduction of interest expense totaled approximately $79,000 and $0.5 million, respectively.

Direct operating expenses exclude depreciation and amortization of approximately $6.7 million and $6.1 million for the three months ended June 30, 2014 and 2013, respectively. Direct operating expenses exclude depreciation and amortization of approximately $13.3 million and $11.9 million for the six months ended June 30, 2014 and 2013, respectively.

Cost of products sold expenses exclude depreciation and amortization of approximately $0.1 million and $0.1 million for the three months ended June 30, 2014 and 2013, respectively, and approximately $0.2 million and $0.1 million for the six months ended June 30, 2014 and 2013, respectively.

Table of Contents

CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

June 30, 2014

(unaudited)

(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, 2014, the Partnership had a total of 73,113,537 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 adopted 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.

Available cash for each quarter will generally begin with Adjusted EBITDA reduced for cash needed for: (i) net 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 expense incurred 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 expense and loss on disposition of assets. Available cash for distributions may be increased by previously established cash reserves, if any, at the discretion of the board of directors of our general partner.

The following is a summary of cash distributions paid to the Partnership’s unitholders during 2014 for the respective quarters to which the distributions relate:



	December 31, 2013		March 31, 2014		Total Cash Distributions Paid in 2014
	($ in millions, expect per common unit amounts)
Amount paid to CRLLC	$	16.7	$	14.8	$	31.5
Amounts paid to public unitholders	14.7		13.0		27.7
Total amount paid	$	31.4	$	27.8	$	59.2
Per common unit	$	0.43	$	0.38	$	0.81
Common units outstanding (in thousands)	73,113		73,113

On July 30, 2014, the Board of Directors of the general partner of the Partnership declared a cash distribution for the second quarter of 2014 in the amount of $0.33 per common unit, or approximately $24.1 million in aggregate. The cash distribution will be paid on August 18, 2014 to the Partnership's unitholders of record at the close of business on August 11, 2014.

(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.

Table of Contents

CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

June 30, 2014

(unaudited)

(9) Accrued Expenses and Other Current Liabilities

Accrued expenses and other current liabilities were as follows:



	June 30, 2014		December 31, 2013
	(in thousands)
Property taxes	$	1,382	$	1,373
Current interest rate swap	922		883
Accrued interest	458		458
Other accrued expenses and liabilities (1)	7,208		2,345
	$	9,970	$	5,059

____________


(1)	Other accrued expenses and liabilities include amounts owed by the Partnership to Coffeyville Resources Refining & Marketing, LLC (“CRRM”), a related party, under both 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, 2014 and December 31, 2013. There is no scheduled amortization and the credit facility matures in April 2016.

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. 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, 2014, CVR Partners was in compliance with the covenants contained in the credit facility.

Table of Contents

CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

June 30, 2014

(unaudited)

(11) Interest Rate Swap Agreements

CRNF is subject to 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. See 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 agreement dates). Under the terms of the interest rate swap agreement entered into on June 30, 2011, CRNF will receive a floating rate based on three month LIBOR and pay a fixed rate of 1.94%. Under the terms of the interest rate swap agreement entered into on July 1, 2011, CRNF will receive a floating rate based on three month LIBOR and pay 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 as calculated under the credit facility. At June 30, 2014, the effective rate was approximately 4.55%. 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, 2014 and 2013, respectively, and $0.5 million and $0.5 million for the six months ended June 30, 2014 and 2013, respectively.

The interest rate swap agreements held by the Partnership also provide for the right to setoff. 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, 2014 and December 31, 2013.

(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, 2014	$	2,707	$	16,849
Year ending December 31, 2015	5,191		14,001
Year ending December 31, 2016	4,466		14,253
Year ending December 31, 2017	2,827		14,547
Year ending December 31, 2018	2,014		14,505
Thereafter	4,917		94,227
	$	22,122	$	168,382

_____________


(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. Railcar purchase obligations, as disclosed in Note 13 ("Related Party Transactions"), have also been included.

CRNF leases railcars and facilities under long-term operating leases. Lease expense for the three months ended June 30, 2014 and 2013 totaled approximately $1.1 million and $1.0 million, respectively. Lease expense for the six months ended June 30, 2014 and 2013 totaled approximately $2.3 million and $2.4 million, respectively. The lease agreements have various remaining terms. Some agreements are renewable, at 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.

Table of Contents

CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

June 30, 2014

(unaudited)

CRNF has an agreement with the City of Coffeyville pursuant to which it must make a series of future payments for the supply, generation and transmission of electricity based upon agreed upon rates. This agreement expires on July 1, 2019.

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 approximately $0.3 million to $0.4 million per month, which amount is subject to annual inflation adjustments, 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 both the three months ended June 30, 2014 and 2013 totaled approximately $1.0 million, respectively. For the six months ended June 30, 2014 and 2013, the expense for both totaled approximately $2.0 million, respectively.

The Partnership entered into a pet coke supply agreement with HollyFrontier Corporation. The term of this agreement ends in December 2014 and may be renewed. Expenses related to the pet coke supply agreement totaled approximately $1.0 million and $0.8 million for the three months ended June 30, 2014 and 2013, respectively, which are recorded in cost of product sold (exclusive of depreciation and amortization). For the six months ended June 30, 2014 and 2013, these expenses totaled approximately $2.3 million and $2.2 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 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 due to uncertainties inherent in litigation and settlement negotiations. Except as described below, there were no new proceedings or material developments in proceedings that we previously reported in our 2013 Form 10-K. In the opinion of management, the ultimate resolution of any other litigation matters are 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.

CRNF owns and operates a facility utilized for the manufacture of nitrogen fertilizers. Therefore, CRNF has exposure to potential EHS liabilities related to past and present EHS conditions at this location. Under the Comprehensive Environmental Response, Compensation, and Liability Act ("CERCLA"), the Resource Conservation and Recovery Act, and related state laws, certain persons may be liable for the release or threatened release of hazardous substances. These persons can include the current owner or operator of property where a release or threatened release occurred, any persons who owned or operated the property when the release occurred, and any persons who disposed of, or arranged for the transportation or disposal of, hazardous substances at a contaminated property. Liability under CERCLA is strict, and under certain circumstances, joint and several, so that any responsible party may be held liable for the entire cost of investigating and remediating the release of hazardous substances.

CRNF is also subject to extensive and frequently changing federal, state and local, environmental and health and safety laws and regulations governing the emission and release of hazardous substances into the environment, the treatment and discharge of waste water, and the storage, handling, use and transportation of nitrogen products. The ultimate impact of complying with evolving laws and regulations is not always clearly known or determinable due in part to the fact that our operations may change over time and certain implementing regulations for laws, such as the federal Clean Air Act, have not yet been finalized, are under governmental or judicial review or are being revised. These laws and regulations could result in increased capital, operating and compliance costs.

Table of Contents

CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

June 30, 2014

(unaudited)

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 our 2013 Form 10-K. CRNF believes it is in substantial compliance with existing EHS rules and regulations. There can be no assurance that the EHS matters described or referenced herein or other 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.

EHS expenditures are capitalized when such expenditures are expected to result in future economic benefits. EHS capital expenditures for the three and six months ended June 30, 2014 were $0.1 million. EHS capital expenditures for the three and six months ended June 30, 2013 were nominal. These expenditures were incurred for environmental compliance and efficiency of the operations.

(13) Related Party Transactions

Related Party Agreements

In connection with the formation of CVR Partners and the initial public offering of CVR Energy in October 2007, CVR Partners and CRNF entered into several agreements with CVR Energy and its subsidiaries (including CRRM) that govern the business relations among CVR Partners, its general partner and CRNF on the one hand, and CVR Energy and its subsidiaries, on the other hand. Certain of the agreements described below were subsequently amended and restated. 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, accrued expenses and other current liabilities, and other long-term liabilities, on the Partnership's Condensed Consolidated Balance Sheets.

CVR Refining completed its initial public offering (the "Refining Partnership IPO") in January 2013. CVR Energy currently indirectly owns the general partner of CVR Refining and the majority of CVR Refining's outstanding common units. Although certain of CVR Energy's subsidiaries that are parties to the related party agreements discussed below were contributed to CVR Refining in connection with the Refining Partnership IPO and are now subsidiaries of CVR Refining, the Refining Partnership IPO had no impact on the Partnership's business relations with these subsidiaries.

Feedstock and Shared Services Agreement

CRNF entered into a feedstock and shared services agreement with CRRM which was most recently amended in December 2013, 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 for CVR Partners. For the three months ended June 30, 2014 and 2013, the net sales generated from the sale of hydrogen to CRRM were approximately $0.9 million and $4.0 million, respectively. For the six months ended June 30, 2014 and 2013, the net sales generated from the sale of hydrogen to CRRM were approximately $6.8 million and $4.0 million, respectively. For the three months ended June 30, 2014 and 2013, CVR Partners also recognized $0 and $0.1 million, respectively, of cost of product sold related to the transfer of excess hydrogen from the Coffeyville refinery. For the six months ended June 30, 2014 and 2013, CVR Partners also recognized $0 and $0.3 million, respectively, of cost of product sold related to the transfer of excess hydrogen from the Coffeyville refinery. At June 30, 2014 and December 31, 2013, there were approximately $0 and $2.6 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.

Table of Contents

CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

June 30, 2014

(unaudited)

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 associated with nitrogen for the three months ended June 30, 2014 and 2013, were approximately $0.3 million and $0.1 million, respectively. Reimbursed direct operating expenses associated with nitrogen for the six months ended June 30, 2014 and 2013, were approximately $0.5 million and $0.3 million, respectively. No amounts were paid by CRNF to CRRM for any of the periods presented.

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 months ended June 30, 2014 and 2013, the net sales generated from the sale of tail gas to CRRM were nominal. For the six months ended June 30, 2014 and 2013, 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 over the next three years and, in 2014, provide an additional 15% to cover the cost of capital. At June 30, 2014 and December 31, 2013, there were assets of approximately $0.2 million and $0.2 million included in other current assets, approximately $1.1 million and $1.1 million included in other non-current assets, an offset liability of approximately $0.2 million and $0.3 million in other current liabilities and approximately $0 and $0.1 million of other non-current liabilities in the Condensed Consolidated Balance Sheets.

When CRNF retains excess sulfur from its operations, CRRM agrees to handle such sulfur in exchange for a fee payable to transport, store and sell the excess sulfur when possible. CRRM reimburses CRNF for any excess in the sales price of the sulfur above its costs. Approximately $0 and $31,000 were reimbursed by CRRM for the sale of excess sulfur for the three months ended June 30, 2014 and 2013. For the six months ended June 30, 2014 and 2013, approximately $84,000 and $65,000 were reimbursed by CRRM for the sale of excess sulfur. These reimbursements were recorded as reductions to direct operating expenses.

The agreement has an initial term of 20 years, which will be automatically extended for successive five year renewal periods. Either party may terminate the agreement, effective upon the last day of a term, by giving notice no later than three years prior to a renewal date. The agreement will also be terminable by mutual consent of the parties or if one party breaches the agreement and does not cure within applicable cure periods and the breach materially and adversely affects the ability of the terminating party to operate its facility. Additionally, the agreement may be terminated in some circumstances if substantially all of the operations at the nitrogen fertilizer plant or the Coffeyville, Kansas refinery are permanently terminated, or if either party is subject to a bankruptcy proceeding or otherwise becomes insolvent.

At June 30, 2014 and December 31, 2013, receivables of $0.2 million and $0.3 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 sales and pet coke purchases. At June 30, 2014 and December 31, 2013, current obligations of $1.1 million and $1.0 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 sales and pet coke purchases.

Coke Supply Agreement

CRNF entered into 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 (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.

Table of Contents

CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

June 30, 2014

(unaudited)

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 agreement has an initial term of 20 years and will be automatically extended for successive five year renewal periods. Either party may terminate the agreement by giving notice no later than three years prior to a renewal date. The agreement is also terminable by mutual consent of the parties or if a party breaches the agreement and does not cure within applicable cure periods. Additionally, the agreement may be terminated in some circumstances if substantially all of the operations at the nitrogen fertilizer plant or the Coffeyville, Kansas refinery are permanently terminated, or if either party is subject to a bankruptcy proceeding or otherwise becomes insolvent.

The cost of pet coke associated with the transfer of pet coke from CRRM to CRNF was approximately $2.2 million and $2.5 million for the three months ended June 30, 2014 and 2013, respectively. For the six months ended June 30, 2014 and 2013, cost of pet coke associated with the transfer of pet coke from CRRM to CRNF was approximately $4.5 million and $5.1 million, respectively. Payables of $0.6 million and $0.6 million related to the coke supply agreement were included in accounts payable on the Condensed Consolidated Balance Sheets at June 30, 2014 and December 31, 2013, respectively.

Environmental Agreement

CRNF entered into an environmental agreement with CRRM which provides for certain indemnification and access rights in connection with environmental matters affecting the Coffeyville, Kansas refinery and the nitrogen fertilizer plant. Generally, both CRNF and CRRM have agreed to indemnify and defend each other and each other’s affiliates against liabilities associated with certain hazardous materials and violations of environmental laws that are a result of or caused by the indemnifying party’s actions or business operations. This obligation extends to indemnification for liabilities arising out of off-site disposal of certain hazardous materials. Indemnification obligations of the parties will be reduced by applicable amounts recovered by an indemnified party from third parties or from insurance coverage.

The agreement provides for indemnification in the case of contamination or releases of hazardous materials that were present but unknown at the time the agreement was entered into to the extent such contamination or releases were identified in reasonable detail through October 2012. The agreement further provides for indemnification in the case of contamination or releases which occur subsequent to the execution of the agreement.

The term of the agreement is for at least 20 years, or for so long as the feedstock and shared services agreement is in force, whichever is longer.

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. Under this agreement, the Partnership’s general partner has engaged CVR Energy to conduct a substantial portion of its day-to-day business operations. CVR Energy provides CVR Partners with the following services under the agreement, among others:


•	services from CVR Energy’s employees in capacities equivalent to the capacities of corporate executive officers, except that those who serve in such capacities under the agreement shall serve the Partnership on a shared, part-time basis only, unless the Partnership and CVR Energy agree otherwise;

Table of Contents

CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

June 30, 2014

(unaudited)


•	administrative and professional services, including legal, accounting services, human resources, insurance, tax, credit, finance, government affairs and regulatory affairs;


•	management of the Partnership’s property and the property of its operating subsidiary in the ordinary course of business;


•	recommendations on capital raising activities to the board of directors of the Partnership’s general partner, including the issuance of debt or equity interests, the entry into credit facilities and other capital market transactions;


•	managing or overseeing litigation and administrative or regulatory proceedings, establishing appropriate insurance policies for the Partnership and providing safety and environmental advice;


•	recommending the payment of distributions; and


•	managing or providing advice for other projects, including acquisitions, as may be agreed by CVR Energy and the Partnership’s general partner from time to time.

As payment for services provided under the agreement, the Partnership, its general partner or CRNF must pay CVR Energy (i) all costs incurred by CVR Energy or its affiliates in connection with the employment of its employees, other than administrative personnel, who provide the Partnership services under the agreement on a full-time basis, but excluding certain share-based compensation; (ii) a prorated share of costs incurred by CVR Energy or its affiliates in connection with the employment of its employees, including administrative personnel, who provide the Partnership services under the agreement on a part-time basis, but excluding certain share-based compensation, and such prorated share shall be determined by CVR Energy on a commercially reasonable basis, based on the percentage of total working time that such shared personnel are engaged in performing services for the Partnership; (iii) a prorated share of certain administrative costs, including office costs, services by outside vendors, other sales, general and administrative costs and depreciation and amortization; and (iv) various other administrative costs in accordance with the terms of the agreement, including travel, insurance, legal and audit services, government and public relations and bank charges.

Either CVR Energy or the Partnership's general partner may temporarily or permanently exclude any particular service from the scope of the agreement upon 180 days' notice and either CVR Energy or the Partnership's general partner may terminate the agreement upon at least 180 days' notice, but not more than one year's notice. Furthermore, the Partnership's general partner may terminate the agreement immediately if CVR Energy becomes bankrupt or dissolves or commences liquidation or winding-up procedures.

In order to facilitate the carrying out of services under the agreement, CVR Partners and CVR Energy have granted one another certain royalty-free, non-exclusive and non-transferable rights to use one another’s intellectual property under certain circumstances.

Net amounts incurred under the services agreement for the three months ended June 30, 2014 and 2013 were approximately $3.6 million and $3.6 million, respectively. Of these charges approximately $2.7 million and $2.5 million, respectively, are included in selling, general and administrative expenses (exclusive of depreciation and amortization). In addition, $0.9 million and $1.1 million, respectively, of these charges are included in direct operating expenses. Net amounts incurred under the services agreement for the six months ended June 30, 2014 and 2013 were approximately $7.1 million and $6.9 million, respectively. Of these charges approximately $5.3 million and $4.6 million, respectively, are included in selling, general and administrative expenses (exclusive of depreciation and amortization). In addition, $1.8 million and $2.3 million, respectively, of these charges are included in direct operating expenses. For services performed in connection with the services agreement, the Partnership recognized personnel costs of $1.5 million and $1.0 million, respectively, for the three months ended June 30, 2014 and 2013. For services performed in connection with the services agreement, the Partnership recognized personnel costs of $2.8 million and $2.0 million, respectively, for the six months ended June 30, 2014 and 2013. At each of June 30, 2014 and December 31, 2013, current obligations of $3.3 million and $2.7 million 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.

Table of Contents

CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

June 30, 2014

(unaudited)

GP Services Agreement

The Partnership is party to a GP Services Agreement dated November 29, 2011 and subsequently amended between the Partnership, CVR GP and CVR Energy. As payment for certain specific services provided under the agreement, CVR Energy must pay a prorated share of costs incurred by the Partnership or its general partner in connection with the employment of certain employees who provide CVR Energy services on a part-time basis, as determined by the Partnership's general partner on a commercially reasonable basis based on the percentage of total working time that such shared personnel are engaged in performing services for CVR Energy. CVR Energy is not required to directly pay any compensation, salaries, bonuses or benefits to any of the Partnership’s or general partner’s employees who provide other services to CVR Energy on a full-time or part-time basis, thus the Partnership has and will continue to pay their compensation.

Limited Partnership Agreement

The Partnership's general partner manages the Partnership's operations and activities as specified in the partnership agreement. The general partner of the Partnership is managed by its board of directors. CRLLC has the right to select the directors of the general partner. Actions by the general partner that are made in its individual capacity are made by CRLLC as the sole member of the general partner and not by its board of directors. The members of the board of directors of the general partner are not elected by the unitholders and are not subject to re-election on a regular basis in the future. The officers of the general partner manage the day-to-day affairs of the Partnership's business.

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, 2014 and 2013 approximately $0.6 million and $1.1 million, respectively, pursuant to the partnership agreement 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, 2014 and 2013, approximately $0.9 million and $2.1 million were incurred related to amounts due for reimbursement, respectively. At June 30, 2014 and December 31, 2013, current obligations of $1.1 million and $2.0 million, respectively, were included in personnel accruals and accounts payable on the Condensed Consolidated Balance Sheets related to amounts outstanding in accordance with the limited partnership agreement.

Railcar Lease Agreement

From March 2009 through June 2013, the Partnership leased 199 railcars from American Railcar Leasing, LLC (“ARL”), a company controlled by Mr. Carl C. Icahn, CVR Energy's majority stockholder. The agreement was scheduled to expire on March 30, 2014. On June 13, 2013, the Partnership purchased the railcars from ARL for approximately $5.0 million. Rent expense is included in cost of product sold (exclusive of depreciation and amortization) in the Condensed Consolidated Statement of Operations. For the three and six months ended June 30, 2013, $0.1 million and $0.4 million, respectively, of rent expense was recorded related to this agreement.

Railcar Purchases and Maintenance

In the second quarter of 2014, the Partnership entered into a contract to purchase approximately fifty new UAN railcars from American Railcar Industries, Inc. ("ARI"), a company controlled by Mr. Carl C. Icahn, CVR Energy's majority stockholder, for approximately $6.7 million. The Partnership expects the delivery of the new railcars from ARI will commence in the third quarter of 2014 and will be completed by December 2014. ARI performed railcar maintenance for the Partnership starting in the second quarter of 2014. The expenses associated with this maintenance were about $52,000 for both the three and six months ended June 30, 2014.

Registration Rights Agreement

For the three and six months ended June 30, 2013, the Partnership recognized approximately $0.2 million and $0.5 million, respectively, in expenses for the benefit of CRLLC in connection with CRLLC’s Secondary Offering in accordance with CVR Partners’ Registration Rights Agreement. These amounts included filing fees, printer fees and external accounting and external legal fees incurred in conjunction with the filing of the registration statement for the Secondary Offering.

Table of Contents

CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

June 30, 2014

(unaudited)

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.

Table of Contents

CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

June 30, 2014

(unaudited)

(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, 2014 and December 31, 2013.



	June 30, 2014
	Level 1		Level 2		Level 3		Total
	(in thousands)
Financial Statement Caption and Description
Cash equivalents (money market account)	$	65,309	$	—	$	—	$	65,309
Other current liabilities (interest rate swaps)	—		922		—		922
Other long-term liabilities (interest rate swaps)	—		629		—		629
Total Liabilities	—		1,551		—		1,551
Accumulated other comprehensive loss (interest rate swaps)	$	—	$	1,551	$	—	$	1,551



	December 31, 2013
	Level 1		Level 2		Level 3		Total
	(in thousands)
Financial Statement Caption and Description
Cash equivalents (money market account)	$	65,299	$	—	$	—	$	65,299
Other current liabilities (interest rate swaps)	—		883		—		883
Other long-term liabilities (interest rate swaps)	—		1,016		—		1,016
Total Liabilities	—		1,899		—		1,899
Accumulated other comprehensive loss (interest rate swaps)	$	—	$	1,899	$	—	$	1,899

As of June 30, 2014 and December 31, 2013, 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 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, 2014 and 2013.

Table of Contents

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

The following discussion and analysis 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, 2013 and filed with the Securities and Exchange Commission (“SEC”) on February 26, 2014 (the "2013 Form 10-K"). Results of operations and cash flows for the three months ended June 30, 2014 and 2013 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 performance, future capital sources and other matters; 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 Partnership’s 2013 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;


•	the risk associated with governmental policies affecting the agricultural industry;

Table of Contents


•	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;


•	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 document. 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.

Table of Contents

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 2013, we produced 930,643 tons of UAN and 401,971 tons of ammonia. Approximately 95% of our produced ammonia tons and substantially all of the purchased ammonia were upgraded into UAN in 2013. For the three months ended June 30, 2014 and 2013, we produced 223,407 tons and 225,166 tons of UAN and 92,249 tons and 91,318 tons of ammonia, respectively. For the six months ended June 30, 2014 and 2013, we produced 480,638 tons and 421,323 tons of UAN and 183,274 tons and 202,670 tons of ammonia, respectively. For the three and six months ended June 30, 2014, approximately 97% and 94%, respectively, of our produced and purchased ammonia tons were upgraded into UAN.

We will 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. A significant two-year plant expansion designed to increase our UAN production capacity by 400,000 tons per year, or approximately 50%, was completed in February 2013. Our expanded facility was operating at full rates at the end of the first quarter of 2013. CVR Energy, which indirectly owns our general partner and approximately 53% of our outstanding common units, also indirectly owns the general partner and approximately 67% of the common units of CVR Refining at June 30, 2014. CVR Refining 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 medium complexity crude oil refinery with a rated capacity of 70,000 bpcd in Wynnewood, Oklahoma and ancillary businesses.

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 ammonia and UAN 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.

Secondary Public Offering

On May 28, 2013, Coffeyville Resources, LLC (“CRLLC”), a wholly owned subsidiary of CVR Energy, sold 12,000,000 of our common units to the public at a price of $25.15 per unit in a registered public offering (the “Secondary Offering”). The net proceeds to CRLLC from the Secondary Offering were approximately $292.6 million, after deducting approximately $9.2 million in underwriting discounts and commissions. We did not receive any of the proceeds from the sale of common units by CRLLC. In connection with the Secondary Offering, the Partnership incurred approximately $0.2 million and $0.5 million in offering costs during the three and six months ended June 30, 2013, respectively. Following the closing of the Secondary Offering and as of June 30, 2014, public security holders held approximately 47% of all outstanding common units and CRLLC held approximately 53% of all outstanding common units and the general partner interest.

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.

Table of Contents

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, international 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. However, calendar year 2012 and 2013 were two of the lowest priced years for natural gas prices as compared to the last 10 years. 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 to determine our operating margin. Product pricing at gate per ton 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.

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 2013, approximately 53% of the corn planted in the United States was grown within a $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 trucks for direct shipment to customers or in railcars for destinations located principally on the Union Pacific Railroad. We do not currently incur significant intermediate transfer, storage, barge freight or pipeline freight charges. We estimate that our plant enjoys a transportation cost advantage of approximately $15 per UAN ton for transportation of UAN over competitors located in the U.S. Gulf Coast. Selling products to customers within economic rail transportation limits of our nitrogen fertilizer plant and keeping transportation costs low are keys to maintaining profitability. Going forward, as a result of the UAN expansion project completion, we expect to upgrade substantially all of our ammonia production into UAN for as long as it makes economic sense to do so. The value of nitrogen fertilizer products is also an important consideration in understanding our results.

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. These fixed costs averaged approximately 82% of direct operating expenses over the 24 months ended June 30, 2014.

Our largest raw material expense is pet coke, which we purchase from CRRM and third parties. For the three months ended June 30, 2014 and 2013, we spent approximately $3.2 million and $3.4 million, respectively, for pet coke, which equaled an average cost per ton of $27 and $29, respectively. For the six months ended June 30, 2014 and 2013, we spent approximately $6.8 million and $7.4 million, respectively, for pet coke, which equaled an average cost per ton of $28 and $30, respectively.

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 facility turnaround every two to three years. The turnaround typically lasts 13-15 days each turnaround year and costs approximately $5.0 million per turnaround. The nitrogen fertilizer plant underwent a turnaround in the fourth quarter of 2012, at a cost of approximately $4.8 million. The Partnership is planning to defer the next full facility turnaround to 2015. 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 ("PSA") unit, which is projected to increase hydrogen recovery enough to allow us to produce approximately 7,000 to 9,000 additional tons of ammonia annually.

Table of Contents

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 reasons 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, which is projected to increase hydrogen recovery sufficient to produce additional ammonia. As a result of the shutdown, production was reduced during the three and six months ended June 30, 2014. Additionally, we 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 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, 2014 and 2013. 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, 2013, is unaudited.

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.

Table of Contents



	Three Months Ended June 30,						Six Months Ended June 30,
	2014			2013			2014			2013
	(in millions)
Consolidated Statements of Operations Data:
Net sales	$	77.2		$	88.8		$	157.5		$	170.2
Cost of product sold – Affiliates	2.3			2.8			4.5			5.9
Cost of product sold – Third Parties(1)	17.1			12.8			36.6			20.3
	19.4			15.6			41.1			26.2
Direct operating expenses – Affiliates(2)	0.8			1.2			1.6			2.2
Direct operating expenses – Third Parties(1)	26.1			23.2			49.5			44.8
	26.9			24.4			51.1			47.0
Selling, general and administrative expenses - Affiliates(1)(2)	4.0			4.1			7.5			8.3
Selling, general and administrative expenses - Third Parties(1)	1.3			1.4			2.4			2.8
	5.3			5.5			9.9			11.1
Depreciation and amortization(1)	6.8			6.2			13.5			12.0
Operating income	18.8			37.1			41.9			73.9
Interest expense and other financing costs	(1.7		)	(1.7)			(3.3		)	(2.9)
Interest income	—			—			—			—
Other income (expense), net	—			—			—			—
Total other income (expense)	(1.7		)	(1.7		)	(3.3		)	(2.9		)
Income before income tax expense	17.1			35.4			38.6			71.0
Income tax expense	—			—			—			—
Net income	$	17.1		$	35.4		$	38.6		$	71.0
EBITDA(3)	$	25.6		$	43.3		$	55.4		$	85.9
Adjusted EBITDA(3)	$	25.7		$	44.1		$	55.7		$	87.9
Available cash for distribution(4)	$	24.0		$	42.6		$	51.8		$	87.2

Reconciliation of net sales:
Sales net at gate	$	69.2		$	76.8		$	136.2		$	152.5
Freight in revenue	6.7			8.0			13.5			13.7
Hydrogen revenue	0.9			4.0			6.8			4.0
Other	0.4			—			1.0			—
Total net sales	$	77.2		$	88.8		$	157.5		$	170.2



	As of June 30, 2014		As of December 31, 2013
			(audited)
	(in millions)
Balance Sheet Data:
Cash and cash equivalents	$	78.5	$	85.1
Working capital	93.9		108.4
Total assets	575.2		593.5
Total debt	125.0		125.0
Total partners’ capital	419.9		439.9

Table of Contents



	Three Months Ended June 30,						Six Months Ended June 30,
	2014			2013			2014			2013
	(in millions)
Cash Flow and Other Data:
Net cash flow provided by (used in):
Operating activities	$	24.4		$	17.1		$	59.9		$	74.6
Investing activities	(4.0		)	(13.7		)	(7.4		)	(31.8		)
Financing activities	(27.8		)	(44.8		)	(59.2		)	(58.8		)
Net increase (decrease) in cash and cash equivalents	$	(7.4	)	$	(41.4	)	$	(6.7	)	$	(16.0	)
Capital expenditures for property, plant and equipment	$	4.1		$	13.8		$	7.5		$	31.9

______________


(1)	Amounts are shown exclusive of depreciation and amortization. Depreciation and amortization is primarily comprised of the following components:



	Three Months Ended June 30,				Six Months Ended June 30,
	2014		2013		2014		2013
	(in millions)
Depreciation and amortization excluded from direct operating expenses	$	6.7	$	6.1	$	13.3	$	11.9
Depreciation and amortization excluded from cost of product sold	0.1		0.1		0.2		0.1
	$	6.8	$	6.2	$	13.5	$	12.0

(2)

Our selling, general and administrative expenses and direct operating expenses for the three and six months ended June 30, 2014 and 2013 include amounts for share-based compensation, including charges related to CVR Energy's share-based compensation expense allocated to us by CVR Energy for financial reporting purposes in accordance with ASC 718. See Note 4 ("Share‑Based Compensation") to the consolidated financial statements for further discussion of allocated share-based compensation. The charges for share-based compensation in selling, general and administrative expenses were $0.6 million and $0.5 million for the three months ended June 30, 2014 and 2013, respectively. The charges for share-based compensation in selling, general and administrative expenses were $1.1 million and $1.1 million for the six months ended June 30, 2014 and 2013, respectively. Only nominal charges were included in direct operating expenses.


(3)	EBITDA is defined as net income before (i) net interest (income) expense, (ii) income tax expense, and (iii) depreciation and amortization expense, which are items management believes affect the comparability of operating results.

Adjusted EBITDA is defined as EBITDA further adjusted for the impact of share-based compensation, non-cash, and, when applicable, major scheduled turnaround expenses and loss on disposition of assets. We present Adjusted EBITDA because it is a key measure used in material covenants in our credit facility and because it is the starting point for 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 our common unitholders and our compliance with the covenants contained in our credit facility. EBITDA and Adjusted EBITDA presented by other companies may not be comparable to our presentation, since each company may define these terms differently.

Table of Contents

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



	Three Months Ended June 30,				Six Months Ended June 30,
	2014		2013		2014		2013
	(in millions)
Net income	$	17.1	$	35.4	$	38.6	$	71.0
Add:
Interest expense, net	1.7		1.7		3.3		2.9
Depreciation and amortization	6.8		6.2		13.5		12.0
EBITDA	25.6		43.3		55.4		85.9
Share-based compensation, non-cash	0.1		0.8		0.3		2.0
Adjusted EBITDA	$	25.7	$	44.1	$	55.7	$	87.9

(4)

The board of directors of our general partner has adopted an amended policy to calculate available cash for distribution starting with Adjusted EBITDA. For the three and six months ended June 30, 2014 and 2013, available cash for distribution equaled our Adjusted EBITDA reduced for cash needed for (i) net 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 incurred and reserves for future operating or capital needs that the board of directors of the general partner deems necessary or appropriate, if any. Available cash for distribution may be increased by the release of previously established cash reserves, if any, at the discretion of the board of directors of our general partner.

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 as 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.

Below is a table reconciling Adjusted EBITDA to available cash for distribution:



	Three Months Ended June 30, 2014			Six Months Ended June 30, 2014
	(in millions, except units and per unit data)
Reconciliation of Adjusted EBITDA to Available cash for distribution
Adjusted EBITDA	$	25.7		$	55.7
Adjustments:
Less:
Net cash interest expense (excluding capitalized interest) and debt service	(1.4		)	(2.9		)
Maintenance capital expenditures	(1.0		)	(2.0		)
Plus:
Distribution of previously established cash reserves, net	0.7			1.0
Available cash for distribution	$	24.0		$	51.8
Available cash for distribution, per common unit	$	0.33		$	0.71
Common units outstanding (in thousands)	73,114			73,114

Table of Contents

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,
	2014			2013			2014			2013
Key Operating Statistics
Production (thousand tons):
Ammonia (gross produced)(1)	92.2			91.3			183.3			202.7
Ammonia (net available for sale)(1)(2)	3.2			2.2			12.1			32.9
UAN	223.4			225.2			480.6			421.3

Pet coke consumed (thousand tons)	117.3			114.4			242.1			244.2
Pet coke (cost per ton)(3)	$	27		$	29		$	28		$	30
Sales (thousand tons):
Ammonia	2.9			7.1			8.3			34.6
UAN	239.2			217.3			493.9			411.4
Product pricing at gate (dollars per ton)(4):
Ammonia	$	521		$	688		$	493		$	668
UAN	283			331			$	267		$	314
On-stream factors(5):
Gasification	94.2		%	91.6		%	96.5		%	95.5		%
Ammonia	88.1		%	89.1		%	90.1		%	93.9		%
UAN	85.9		%	86.5		%	91.4		%	89.7		%



	Three Months Ended June 30,				Six Months Ended June 30,
	2014		2013		2014		2013
Market Indicators
Natural gas NYMEX (dollars per MMBtu)	$	4.58	$	4.02	$	4.65	$	3.76
Ammonia — Southern Plains (dollars per ton)	$	561	$	653	$	501	$	674
UAN — Corn belt (dollars per ton)	$	333	$	381	$	332	$	380

____________


(1)	Gross tons produced for ammonia represent total ammonia produced, including ammonia that was upgraded into UAN. As a result of the completion of the UAN expansion project in February 2013, we expect to upgrade substantially all of the ammonia we produce 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 3,000 and 4,000 tons of ammonia during the three months ended June 30, 2014 and 2013, respectively. The Partnership acquired approximately 26,000 and 4,000 tons of ammonia during the six months ended June 30, 2014 and 2013, respectively.

(3)

Our pet coke cost per ton purchased from CVR Refining averaged $24 and $27 for the three months ended June 30, 2014 and 2013, respectively. Third-party pet coke prices averaged $41 and $40 for the three months ended June 30, 2014 and 2013, respectively. For the six months ended June 30, 2014 and 2013, our pet coke cost per ton purchased from CVR Refining averaged $24 and $27, respectively. For the six months ended June 30, 2014 and 2013, third-party pet coke prices averaged $40 and $40, respectively.


(4)	Product pricing at gate per ton 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.

Table of Contents


(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 June 30, 2014 would have been 100.0% for gasifier, 94.9% for ammonia and 92.9% for UAN. Excluding the impact of the unplanned Linde air separation unit outages and the unplanned downtime associated with weather issues, the on-stream factors for the three months ended June 30, 2013 would have been 99.6% for gasifier, 99.1% for ammonia and 97.1% for UAN.

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 six months ended June 30, 2014 would have been 99.4% for gasifier, 93.5% for ammonia and 95.0% for UAN. Excluding the impact of the unplanned Linde air separation unit outages, the UAN expansion coming on-line and the unplanned downtime associated with weather issues, the on-stream factors for the six months ended June 30, 2013 would have been 99.6% for gasifier, 98.9% for ammonia and 97.7% for UAN.

Three Months Ended June 30, 2014 Compared to the Three Months Ended June 30, 2013

Net Sales. Net sales were $77.2 million for the three months ended June 30, 2014 compared to $88.8 million for the three months ended June 30, 2013. The decrease of $11.6 million was primarily the result of lower UAN sales prices ($13.5 million), lower ammonia sales volumes ($3.0 million) and lower hydrogen sales volumes ($3.0 million), partially offset by higher UAN sales volumes ($8.1 million). For the three months ended June 30, 2014, UAN and ammonia made up $74.4 million and $1.5 million of our net sales, respectively. This compared to UAN and ammonia net sales of $79.8 million and $5.0 million, respectively, for the three months ended June 30, 2013. The following table demonstrates the impact of sales volumes and pricing for UAN, ammonia and hydrogen for the three months ended June 30, 2014 and 2013:



	Three Months Ended June 30, 2014					Three Months Ended June 30, 2013					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	239,216	$	311	$	74.4	217,287	$	367	$	79.8	21,929		$	(5.4	)	$	(13.5	)	$	8.1
Ammonia	2,854	$	542	$	1.5	7,068	$	710	$	5.0	(4,214	)	$	(3.5	)	$	(0.5	)	$	(3.0	)
Hydrogen	92,967	$	10	$	0.9	375,102	$	11	$	4.0	(282,135	)	$	(3.1	)	$	(0.1	)	$	(3.0	)

____________

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

(2) Includes freight charges

(3) Sales dollars in millions

The increase in UAN sales volume for the three months ended June 30, 2014 compared to the three months ended June 30, 2013 was primarily attributable to product availability resulting from the UAN expansion, which came on line in February 2013. On-stream factors (total number of hours operated divided by total hours in the reporting period) for the gasification, ammonia and UAN units were 94.2%, 88.1% and 85.9%, respectively, for the three months ended June 30, 2014.

Product pricing at gate per ton represents net sales less freight revenue divided by product sales volume in tons. We believe product pricing at gate is meaningful because we sell products both at our plant gate (sold plant) and delivered to the customer’s designated delivery site (sold delivered) and the percentage of sold plant versus sold delivered can change month-to-month or quarter-to-quarter. The product pricing at gate provides a measure that is consistently comparable period to period. Average product prices at gate for the three months ended June 30, 2014 compared to the three months ended June 30, 2013 decreased 14.5% for UAN and decreased 24.3% for ammonia, respectively.

Table of Contents

Cost of Product Sold (Exclusive of Depreciation and Amortization). Cost of product sold (exclusive of depreciation and amortization) is primarily comprised of pet coke expense and freight and distribution expenses. Cost of product sold (exclusive of depreciation and amortization) for the three months ended June 30, 2014 was $19.4 million, compared to $15.6 million for the three months ended June 30, 2013. The $3.8 million increase resulted from $4.3 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 three months ended June 30, 2014 were primarily the result of increased railcar repairs and inspections.

Direct Operating Expenses (Exclusive of Depreciation and Amortization). Direct operating expenses (exclusive of depreciation and amortization) include costs associated with the actual operations of our plant, such as repairs and maintenance, energy and utility costs, property taxes, catalyst and chemical costs, outside services, labor and environmental compliance costs. Direct operating expenses (exclusive of depreciation and amortization) for the three months ended June 30, 2014 were $26.9 million as compared to $24.4 million for the three months ended June 30, 2013. The $2.5 million increase resulted primarily from higher utilities ($1.2 million), refractory brick amortization ($0.9 million), outside services ($0.4 million), personnel costs ($0.1 million), repairs and maintenance ($0.1 million), and reimbursements of our general partner ($0.1 million), partially offset by lower insurance ($0.3 million), and property taxes ($0.2 million). The increased utility costs were largely due to higher electrical volumes associated with the higher gasification on-stream rate for the three months ended June 30, 2014.

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 & administrative expenses from affiliates. Certain of our expenses are subject to the services agreement with CVR Energy and our general partner. Selling, general and administrative expenses (exclusive of depreciation and amortization) were $5.3 million for the three months ended June 30, 2014, as compared to $5.5 million for the three months ended June 30, 2013. The decrease of $0.2 million for the three months ended June 30, 2014 as compared to the three months ended June 30, 2013 resulted from a decrease in costs of transactions with affiliates ($0.1 million) and a decrease in costs of transactions with third parties ($0.1 million). The overall variance was primarily the result of a decrease in reimbursements of our general partner ($0.4 million), and a decrease in outside services ($0.2 million), partially offset by increases in expenses related to the services agreement ($0.3 million).

Operating Income. Operating income was $18.8 million for the three months ended June 30, 2014, as compared to operating income of $37.1 million for the three months ended June 30, 2013. The decrease of $18.3 million for the three months ended June 30, 2014 as compared to the three months ended June 30, 2013 was the result of the decrease in net sales ($11.6 million), the increases in cost of product sold ($3.8 million), direct operating expenses ($2.5 million), and depreciation and amortization ($0.6 million), partially offset by a decrease in selling, general, and administrative expense ($0.2 million).

Net Income. For the three months ended June 30, 2014, net income was $17.1 million as compared to $35.4 million of net income for the three months ended June 30, 2013, a decrease of $18.3 million. The decrease in net income was primarily due to the factors noted above.

Table of Contents

Six Months Ended June 30, 2014 Compared to the Six Months Ended June 30, 2013

Net Sales. Net sales were $157.5 million for the six months ended June 30, 2014 compared to $170.2 million for the six months ended June 30, 2013. The decrease of $12.7 million was primarily the result of lower UAN sales prices ($25.5 million), lower ammonia sales volumes ($18.1 million), lower ammonia sales prices ($1.4 million), and lower hydrogen sales prices ($0.3 million), partially offset by higher UAN sales volumes ($28.6 million) and higher hydrogen sales volumes ($3.1 million). For the six months ended June 30, 2014, UAN and ammonia made up $145.5 million and $4.2 million of our net sales, respectively. This compared to UAN and ammonia net sales of $142.4 million and $23.7 million, respectively, for the six months ended June 30, 2013. The following table demonstrates the impact of sales volumes and pricing for UAN, ammonia and hydrogen for the six months ended June 30, 2014 and 2013:



	Six Months Ended June 30, 2014					Six Months Ended June 30, 2013					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	493,886	$	295	$	145.5	411,428	$	346	$	142.4	82,458		$	3.1		$	(25.5	)	$	28.6
Ammonia	8,301	$	511	$	4.2	34,640	$	685	$	23.7	(26,339	)	$	(19.5	)	$	(1.4	)	$	(18.1	)
Hydrogen	671,431	$	10	$	6.8	377,815	$	11	$	4.0	293,616		$	2.8		$	(0.3	)	$	3.1

____________

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

(2) Includes freight charges

(3) Sales dollars in millions

The increase in UAN sales volume for the six months ended June 30, 2014 compared to the six months ended June 30, 2013 was primarily attributable to the UAN expansion being available for the full period in 2014. On-stream factors (total number of hours operated divided by total hours in the reporting period) for the gasification, ammonia and UAN units were 96.5%, 90.1% and 91.4%, respectively, for the six months ended June 30, 2014.

Product pricing at gate per ton represents net sales less freight revenue divided by product sales volume in tons. We believe product pricing at gate is meaningful because we sell products both at our plant gate (sold plant) and delivered to the customer’s designated delivery site (sold delivered) and the percentage of sold plant versus sold delivered can change month-to-month or quarter-to-quarter. The product price at gate provides a measure that is consistently comparable period to period. Average product prices at gate for the six months ended June 30, 2014 compared to the six months ended June 30, 2013 decreased 15.0% for UAN and decreased 26.2% for ammonia, respectively.

Cost of Product Sold (Exclusive of Depreciation and Amortization). Cost of product sold (exclusive of depreciation and amortization) is primarily comprised of pet coke expense and freight and distribution expenses. Cost of product sold (exclusive of depreciation and amortization) for the six months ended June 30, 2014 was $41.1 million, compared to $26.2 million for the six months ended June 30, 2013. The $14.9 million increase resulted from $16.3 million in higher costs from transactions with third parties, partially offset by lower costs from transactions with affiliates of $1.4 million. The higher third-party costs incurred during the six months ended June 30, 2014 were primarily the result of ammonia purchases (approximately 26,000 tons for the six months ended June 30, 2014 and 4,000 tons in the six months ended June 30, 2013) and increased railcar repairs and inspections.

Direct Operating Expenses (Exclusive of Depreciation and Amortization). Direct operating expenses (exclusive of depreciation and amortization) include costs associated with the actual operations of our plant, such as repairs and maintenance, energy and utility costs, property taxes, catalyst and chemical costs, outside services, labor and environmental compliance costs. Direct operating expenses (exclusive of depreciation and amortization) for the six months ended June 30, 2014 were $51.1 million as compared to $47.0 million for the six months ended June 30, 2013. The $4.1 million increase resulted primarily from higher utilities ($2.8 million), refractory brick amortization ($1.4 million), catalyst amortization ($0.3 million), outside services ($0.3 million), repairs and maintenance ($0.2 million), reimbursements of our general partner ($0.2 million), partially offset by lower insurance ($0.7 million), property taxes ($0.5 million), and personnel costs ($0.3 million). The increased utility costs were largely due to higher electrical volumes associated with the UAN expansion, which came on-line in February 2013. The lower labor costs are mostly the result of the higher labor incurred during the UAN expansion project.

Table of Contents

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 & administrative expenses from affiliates. Certain of our expenses are subject to the services agreement with CVR Energy and our general partner. Selling, general and administrative expenses (exclusive of depreciation and amortization) were $9.9 million for the six months ended June 30, 2014, as compared to $11.1 million for the six months ended June 30, 2013. The decrease of $1.2 million for the six months ended June 30, 2014 as compared to the six months ended June 30, 2013 resulted from a decrease in costs of transactions with affiliates ($0.8 million) and a decrease in costs of transactions with third parties ($0.4 million). The overall variance was primarily the result of a decrease in reimbursements of our general partner ($1.1 million), a decrease in outside services ($0.7 million) and a decrease in share-based compensation ($0.5 million), partially offset by increases in expenses related to the services agreement ($0.7 million) and personnel costs ($0.2 million).

Operating Income. Operating income was $41.9 million for the six months ended June 30, 2014, as compared to operating income of $73.9 million for the six months ended June 30, 2013. The decrease of $32.0 million for the six months ended June 30, 2014 as compared to the six months ended June 30, 2013 was the result of an increase in cost of product sold ($14.9 million), a decrease in sales ($12.7 million), an increase to direct operating expenses ($4.1 million), and an increase in depreciation and amortization ($1.5 million), partially offset by a decrease in selling, general, and administrative expense ($1.2 million).

Interest Expense and Other Financing Costs. Interest expense for the six months ended June 30, 2014 was approximately $3.3 million as compared to $2.9 million for the six months ended June 30, 2013. Interest expense for the six months ended June 30, 2014 was attributable to bank interest expense of $2.4 million on the term loan facility, $0.5 million of interest expense related to the interest rate swap and $0.5 million of deferred financing amortization, partially offset by capitalized interest. The increase in expense as compared to the six months ended June 30, 2013 was primarily due to a decrease in capitalized interest associated with the UAN expansion being completed in the first quarter of 2013.

Net Income. For the six months ended June 30, 2014, net income was $38.6 million as compared to $71.0 million of net income for the six months ended June 30, 2013, a decrease of $32.4 million. The decrease in net income was primarily due to the factors noted above.

Liquidity and Capital Resources

Our principal source of liquidity has historically been cash from operations, which includes 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. We believe that our cash from operations, remaining proceeds from the Initial Public Offering, and available borrowings under our revolving credit facility 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 depends on our future performance, which is subject to general economic, political, financial, competitive, and other factors beyond 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, modify the terms of our existing 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.

Cash Balance and Other Liquidity

As of June 30, 2014, we had cash and cash equivalents of $78.5 million, including $0.4 million of customer advances. Working capital at June 30, 2014 was $93.9 million, consisting of $123.5 million in current assets and approximately $29.6 million in current liabilities. Working capital at December 31, 2013 was $108.4 million, consisting of $135.8 million in current assets and $27.4 million in current liabilities. As of July 28, 2014, we had cash and cash equivalents of $86.2 million.

Table of Contents

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. The credit facility is used 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 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, 2014 and December 31, 2013, 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 (ratio of Consolidated Adjusted EBITDA to interest) as of the end of any fiscal quarter of 3.0 to 1.0 and (ii) a maximum leverage ratio (ratio of debt to Consolidated Adjusted EBITDA) 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 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;

Table of Contents


•	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, 2014, 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.

On June 30 and July 1, 2011, CRNF entered into two Interest Rate Swap agreements. We have determined that the Interest Rate Swaps qualify for hedge accounting treatment. The impact recorded for the three months ended June 30, 2014 and 2013 was $0.3 million and $0.3 million, respectively, in interest expense. For the three months ended June 30, 2014 and 2013, the Partnership recorded a loss of $0.1 million and a gain of $0.2 million, respectively, in the fair market value on the interest rate swaps. The impact recorded for both the six months ended June 30, 2014 and 2013 was $0.5 million in interest expense. For the six months ended June 30, 2014 and 2013, the Partnership recorded a loss of $0.2 million and a gain of $0.2 million, respectively, in the fair market value on the interest rate swaps. The combined fair market value of the interest rate swaps recorded in current and non-current liabilities at June 30, 2014 is $1.6 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, 2014 were approximately $7.5 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 $7.5 million spent for the six months ended June 30, 2014, approximately $2.0 million was related to maintenance capital projects and the remainder was related to growth capital projects. Major scheduled turnaround expenses are expensed when incurred.

Our growth strategy includes expanding production of UAN and acquiring additional infrastructure and production assets. In 2013 we completed a significant two-year plant expansion designed to increase our UAN production capacity by 400,000 tons, or approximately 50% per year. Total capital expenditures associated with the UAN expansion were approximately $130.0 million, excluding capitalized interest, of which approximately $4.9 million and $19.0 million was spent during the three and six months ended June 30, 2013. The UAN expansion construction was completed in February 2013 and our expanded facility was running at full operating rates prior to the end of the first quarter of 2013.

Table of Contents

Our future capital spending 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 below. Our maintenance capital expenditures are expected to be approximately $9.0 million to $11.0 million for the year ending December 31, 2014. Our growth capital expenditures, which are inclusive of the upgrade to the pressure swing adsorption (“PSA”) unit discussed in the following paragraph and the railcar purchases as disclosed in both Note 13 ("Related Party Transactions") and Note 12 ("Commitments and Contingencies") to Part I, Item I of this Report, are projected to be approximately $15.0 million for the year ending December 31, 2014.

During the second quarter of 2014, the gasification, ammonia and UAN units were taken down for between 5 to 7 days each to both install a waste heat boiler and upgrade the PSA unit. The upgraded PSA unit is projected to increase hydrogen recovery enough to allow us to produce approximately 7,000 to 9,000 additional tons of ammonia annually, at a total cost of approximately $4.9 million.

Planned capital expenditures for 2014 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. Capital spending for our business has been and will be determined by our general partner.

Distributions to Unitholders

The board of directors of the Partnership's general partner has adopted 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. The following is a summary of cash distributions paid to the Partnership’s unitholders during 2014 for the respective quarters to which the distributions relate:



	December 31, 2013		March 31, 2014		Total Cash Distributions Paid in 2014
	($ in millions, expect per common unit amounts)
Amount paid to CRLLC	$	16.7	$	14.8	$	31.5
Amounts paid to public unitholders	14.7		13.0		27.7
Total amount paid	$	31.4	$	27.8	$	59.2
Per common unit	$	0.43	$	0.38	$	0.81
Common units outstanding (in thousands)	73,113		73,113

Table of Contents

Cash Flows

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



	Six Months Ended June 30,
	2014			2013
	(in millions)
Net cash provided by (used in):
Operating activities	$	59.9		$	74.6
Investing activities	(7.4		)	(31.8		)
Financing activities	(59.2		)	(58.8		)
Net increase (decrease) in cash and cash equivalents	$	(6.7	)	$	(16.0	)

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, 2014 were approximately $59.9 million. The positive cash flow from operating activities generated over this period was attributable to net income of $38.6 million, which was primarily driven by strong UAN product volumes, partially offset by higher costs associated with purchases of third party ammonia, increased railcar repairs and inspections and higher utilities partially associated with the UAN expansion. With respect to other working capital for the six months ended June 30, 2014, the primary sources of cash were due to changes in other working capital of $6.8 million, primarily due to a decrease to prepaid expenses and other current assets of $3.9 million and an increase to accrued expenses and other current liabilities of $3.2 million. For the six months ended June 30, 2014, 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, a increase in accounts receivable of $0.4 million, partially offset by a decrease in inventory of $2.2 million.

Net cash flows provided by operating activities for the six months ended June 30, 2013 were $74.6 million. The positive cash flow from operating activities generated over this period were primarily attributable to net income of $71.0 million, partially offset by unfavorable impacts to other working capital of $8.3 million and trade working capital of $2.4 million. Net Income was primarily driven by strong UAN product volumes and favorable fertilizer prices driving high profit margins, which was partially offset by a decline in production volumes that resulted from unplanned Linde air separation unit outages and the unscheduled downtime associated with weather issues. For the six months ended June 30, 2013, trade working capital decreased our operating cash flow by $2.4 million due to an increase in inventory of $3.9 million and a decrease in accounts payable of $0.4 million, partially offset by a decrease in accounts receivable of $1.9 million. Fluctuations in other working capital resulted in a decrease to operating cash flows of $8.3 million, primarily due to an increase to prepaid expenses of $2.6 million and a decrease to accrued expenses and other current liabilities of $6.2 million.

Cash Flows Used in Investing Activities

Net cash used in investing activities for the six months ended June 30, 2014 was $7.4 million compared to $31.8 million for the six months ended June 30, 2013. For the six months ended June 30, 2014 and 2013, net cash used in investing activities is primarily the result of capital expenditures. The decrease in capital expenditures during the six months ended June 30, 2014 compared against 2013 is primarily the result of the UAN expansion project expenditures in 2013.

Cash Flows Used in Financing Activities

Net cash flows used in financing activities for the six months ended June 30, 2014 were $59.2 million, compared to net cash flows used in financing activities for the six months ended June 30, 2013 of $58.8 million. The net cash used in financing activities for the six months ended June 30, 2014 and 2013 was primarily attributable to quarterly cash distributions.

Table of Contents

Contractual Obligations

As of June 30, 2014, our contractual obligations included long-term debt, operating leases, unconditional purchase obligations, other specified capital and commercial commitments and interest payments. Except for railcar purchases as disclosed in both Note 13 ("Related Party Transactions") and Note 12 ("Commitments and Contingencies") to Part I, Item I of this Report, 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, 2014, from those disclosed in our 2013 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

In May 2014, the FASB issued 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. The Partnership has not yet selected a transition method and is currently evaluating the standard and the impact on our consolidated financial statements and footnote disclosures.

Critical Accounting Policies

Our critical accounting policies are disclosed in the “Critical Accounting Policies” section of our 2013 Form 10-K. No modifications have been made to our critical accounting policies.

Table of Contents

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.

Our credit facility is disclosed in Note 10 ("Credit Facility") and our interest rate swap agreements are disclosed 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 and 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.

Table of Contents

Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

As of June 30, 2014, 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 Exchange Act Rule 13a-15(e). 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, 2014 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

Table of Contents

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 2013 Form 10-K.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

The table below sets forth information regarding repurchases of our common units during the three months ended June 30, 2014. These represent common units that a director elected to surrender to the Partnership to satisfy certain minimum tax withholding and other tax obligations upon the vesting of units. The Partnership does not consider this to be a unit buyback program.



Period	Total Number of Units Purchased	Average Price Paid per Unit		Total Number of Units Purchased as Part of Publicly Announced Plans or Programs	Maximum Number (or Approximate Dollar Value) of Units that May Yet Be Purchased Under the Plans or Programs
April 1, 2014 to April 30, 2014	—	—		—	—
May 1, 2014 to May 31, 2014	228	$	21.05	—	—
June 1, 2014 to June 30, 2014	—	—		—	—
Total	228	$	21.05	—	—

Table of Contents

Item 6. Exhibits



Exhibit Number	Exhibit Title

10.1*	Employment Agreement, dated as of April 16, 2014, by and between CVR GP, LLC and Mark A. Pytosh.
10.2*	Phantom Unit Agreement, dated as of May 5, 2014, by and between CVR Partners, LP and Mark A. Pytosh.
10.3*	Amendment to GP Services Agreement, dated as of June 27, 2014 by and among CVR Partners, LP, CVR GP, LLC and CVR Energy, Inc.
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.
31.3*	Rule 13a-14(a) or 15d-14(a) Certification of Chief Financial Officer.
32.1*	Section 1350 Certification of Executive Chairman.
32.2*	Section 1350 Certification of Chief Executive Officer.
32.3*	Section 1350 Certification of Chief Financial Officer.
101*	The following financial information for CVR Partners, LP’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2014, filed with the SEC on July 31, 2014, 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 Statements of Cash Flows (unaudited), (5) Condensed Consolidated Statement of Partners’ Capital (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.

Table of Contents

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 31, 2014	By:	/s/ JOHN J. LIPINSKI
		Executive Chairman
		(Principal Executive Officer)

July 31, 2014	By:	/s/ MARK A. PYTOSH
		Chief Executive Officer and President
		(Principal Executive Officer)

July 31, 2014	By:	/s/ SUSAN M. BALL
		Chief Financial Officer and Treasurer
		(Principal Financial and Accounting Officer)