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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 September 30, 2017
OR
¨	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from               to              .

Commission file number: 001-35120

CVR Partners, LP

(Exact name of registrant as specified in its charter)

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

(281) 207-3200

(Registrant’s telephone number, including area code)

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

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

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

Large accelerated filer  o	Accelerated filer þ	Non-accelerated filer o (Do not check if a smaller reporting company)
Smaller reporting company o	Emerging growth company o

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. o

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 113,282,973 common units outstanding at October 30, 2017.

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 CVR PARTNERS, LP AND SUBSIDIARIES

INDEX TO QUARTERLY REPORT ON FORM 10-Q

For The Quarter Ended September 30, 2017

		Page No.
Part I. Financial Information
Item 1.	Financial Statements	5
	Condensed Consolidated Balance Sheets - September 30, 2017 (unaudited) and December 31, 2016	5
	Condensed Consolidated Statements of Operations - Three and Nine Months Ended September 30, 2017 and 2016 (unaudited)	6
	Condensed Consolidated Statements of Comprehensive Income (Loss) - Three and Nine Months Ended September 30, 2017 and 2016 (unaudited)	7
	Condensed Consolidated Statements of Partners' Capital - Nine Months Ended September 30, 2017 (unaudited)	8
	Condensed Consolidated Statements of Cash Flows - Nine Months Ended September 30, 2017 and 2016 (unaudited)	9
	Notes to the Condensed Consolidated Financial Statements - September 30, 2017 (unaudited)	11
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	45
Part II. Other Information
Item 1.	Legal Proceedings	46
Item 1A.	Risk Factors	46
Item 6.	Exhibits	46
Signatures		47

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GLOSSARY OF SELECTED TERMS

The following are definitions of certain terms used in this Quarterly Report on Form 10-Q for the quarter ended September 30, 2017 (this "Report"):     

2023 Notes	$645.0 million aggregate principal amount of 9.25% Senior Notes due 2023, which were issued through CVR Partners and CVR Nitrogen Finance Corporation.
ABL Credit Facility	The Partnership's senior secured asset based revolving credit facility with a group of lenders and UBS AG, Stamford Branch, as administrative agent and collateral agent.
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.
Coffeyville Facility	CVR Partners' nitrogen fertilizer manufacturing facility located in Coffeyville, Kansas.
common units	Common units representing limited partner interests of CVR Partners.
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 Coffeyville Resources, LLC.
CVR Nitrogen	CVR Nitrogen, LP (formerly known as East Dubuque Nitrogen Partners, L.P. and also formerly known as Rentech Nitrogen Partners L.P.).
CVR Partners	CVR Partners, LP.
CVR Refining	CVR Refining, LP, a publicly traded limited partnership listed on the New York Stock Exchange under the ticker symbol "CVRR," which through its subsidiaries, currently owns and operates a complex full coking medium-sour crude oil refinery with a rated capacity of 115,000 barrels per calendar day (bpcd) in Coffeyville, Kansas, a complex crude oil refinery with a rated capacity of 70,000 bpcd in Wynnewood, Oklahoma and ancillary businesses.
East Dubuque Facility	CVR Partners' nitrogen fertilizer manufacturing facility located in East Dubuque, Illinois.
East Dubuque Merger	The transactions contemplated by the Agreement and Plan of Merger dated August 9, 2015, whereby the Partnership acquired CVR Nitrogen and CVR Nitrogen GP, LLC on April 1, 2016.
farm belt	Refers to the states of Illinois, Indiana, Iowa, Kansas, Minnesota, Missouri, Nebraska, North Dakota, Ohio, Oklahoma, South Dakota, Texas and Wisconsin.
general partner	CVR GP, LLC, our general partner, which is a wholly-owned subsidiary of Coffeyville Resources, LLC.
MMBtu	One million British thermal units: a measure of energy. One Btu of heat is required to raise the temperature of one pound of water one degree Fahrenheit.
MSCF	One thousand standard cubic feet, a customary gas measurement.
netback	Netback represents net sales less freight revenue divided by product sales volume in tons. Netback is also referred to as product pricing at gate.

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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.
Partnership	CVR Partners, LP.
pet coke	Petroleum coke - a coal-like substance that is produced during the oil refining process.
product pricing at gate	Product pricing at gate represents net sales less freight revenue divided by product sales volume in tons. Product pricing at gate is also referred to as netback.
southern plains	Primarily includes Oklahoma, Texas and New Mexico.
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.

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PART I. FINANCIAL INFORMATION

Item 1. Financial Statements

CVR PARTNERS, LP AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

	September 30, 2017				December 31, 2016
	(unaudited)
	(in thousands, except unit data)
ASSETS
Current assets:
Cash and cash equivalents	$	69,977			$	55,595
Accounts receivable, net of allowance for doubtful accounts of $44 and $46 at September 30, 2017 and December 31, 2016, respectively	12,345				13,924
Inventories	57,556				58,167
Prepaid expenses and other current assets, including $336 and $750 with affiliates at September 30, 2017 and December 31, 2016, respectively	5,128				6,845
Total current assets	145,006				134,531
Property, plant, and equipment, net of accumulated depreciation	1,083,999				1,130,121
Goodwill	40,969				40,969
Other long-term assets, including $463 and $598 with affiliates at September 30, 2017 and December 31, 2016, respectively	5,785				6,596
Total assets	$	1,275,759			$	1,312,217
LIABILITIES AND PARTNERS’ CAPITAL
Current liabilities:
Accounts payable, including $2,217 and $2,402 due to affiliates at September 30, 2017 and December 31, 2016, respectively	$	20,994			$	28,815
Personnel accruals, including $1,860 and $1,968 with affiliates at September 30, 2017 and December 31, 2016, respectively	7,454				9,256
Deferred revenue	19,361				12,571
Accrued expenses and other current liabilities, including $2,844 and $2,515 with affiliates at September 30, 2017 and December 31, 2016, respectively	23,915				12,374
Total current liabilities	71,724				63,016
Long-term liabilities:
Long-term debt, net of current portion	625,178				623,107
Other long-term liabilities	1,599				1,187
Total long-term liabilities	626,777				624,294
Commitments and contingencies
Partners’ capital:
Common unitholders, 113,282,973 units issued and outstanding at September 30, 2017 and December 31, 2016	577,257				624,906
General partner interest	1				1
Total partners’ capital	577,258				624,907
Total liabilities and partners’ capital	$	1,275,759			$	1,312,217

See accompanying notes to the condensed consolidated financial statements.

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CVR PARTNERS, LP AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

	Three Months Ended   September 30,								Nine Months Ended   September 30,
	2017				2016				2017				2016
	(unaudited)
	(in thousands, except per unit data)
Net sales	$	69,393			$	78,474			$	252,610			$	271,363
Operating costs and expenses:
Cost of materials and other — Affiliates	1,774				529				5,584				1,886
Cost of materials and other — Third parties	17,721				19,282				57,789				70,355
	19,495				19,811				63,373				72,241
Direct operating expenses (exclusive of depreciation and amortization) — Affiliates	978				1,106				2,848				3,207
Direct operating expenses (exclusive of depreciation and amortization) — Third parties	39,290				31,460				111,151				107,193
	40,268				32,566				113,999				110,400
Depreciation and amortization	19,483				16,452				54,877				40,987
Cost of sales	79,246				68,829				232,249				223,628
Selling, general and administrative expenses — Affiliates	3,917				3,560				11,399				10,939
Selling, general and administrative expenses — Third parties	2,166				3,701				7,351				11,057
	6,083				7,261				18,750				21,996
Total operating costs and expenses	85,329				76,090				250,999				245,624
Operating income (loss)	(15,936		)		2,384				1,611				25,739
Other income (expense):
Interest expense and other financing costs	(15,737		)		(15,633		)		(47,140		)		(32,820		)
Interest income	14				—				29				4
Loss on extinguishment of debt	—				—				—				(5,116		)
Other income, net	22				26				81				83
Total other expense	(15,701		)		(15,607		)		(47,030		)		(37,849		)
Loss before income tax expense	(31,637		)		(13,223		)		(45,419		)		(12,110		)
Income tax expense (benefit)	(35		)		207				(36		)		284
Net loss	$	(31,602	)		$	(13,430	)		$	(45,383	)		$	(12,394	)
Net loss per common unit — basic and diluted	$	(0.28	)		$	(0.12	)		$	(0.40	)		$	(0.12	)
Weighted-average common units outstanding — basic and diluted	113,283				113,283				113,283				99,947

See accompanying notes to the condensed consolidated financial statements.

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CVR PARTNERS, LP AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

	Three Months Ended   September 30,								Nine Months Ended   September 30,
	2017				2016				2017				2016
	(unaudited)
	(in thousands)
Net loss	$	(31,602	)		$	(13,430	)		$	(45,383	)		$	(12,394	)
Other comprehensive income:
Net loss reclassified into income on settlement of interest rate swaps	—				—				—				119
Other comprehensive income	—				—				—				119
Total comprehensive loss	$	(31,602	)		$	(13,430	)		$	(45,383	)		$	(12,275	)

See accompanying notes to the condensed consolidated financial statements.

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CVR PARTNERS, LP AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENT OF PARTNERS’ CAPITAL

	Common Units							General Partner Interest				Total
	Issued			Amount
	(unaudited)
	(in thousands, except unit data)
Balance at December 31, 2016	113,282,973			$	624,906			$	1			$	624,907
Cash distributions to common unitholders – Affiliates	—			(778		)		—				(778		)
Cash distributions to common unitholders – Non-affiliates	—			(1,488		)		—				(1,488		)
Net loss	—			(45,383		)		—				(45,383		)
Balance at September 30, 2017	113,282,973			$	577,257			$	1			$	577,258

See accompanying notes to the condensed consolidated financial statements.

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CVR PARTNERS, LP AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

	Nine Months Ended   September 30,
	2017				2016
	(unaudited)
	(in thousands)
Cash flows from operating activities:
Net loss	$	(45,383	)		$	(12,394	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation and amortization	54,877				40,987
Allowance for doubtful accounts	(2		)		14
Amortization of deferred financing costs and original issue discount	952				1,024
Amortization of debt fair value adjustment	1,306				1,250
Loss on disposition of fixed assets	58				127
Loss on extinguishment of debt	—				5,116
Share-based compensation – Affiliates	1,434				1,178
Share-based compensation	314				653
Change in assets and liabilities:
Accounts receivable	1,581				3,404
Inventories	167				32,244
Prepaid expenses and other current assets	1,721				4,218
Other long-term assets	330				(489		)
Accounts payable	(4,558		)		1,580
Deferred revenue	7,370				(27,672		)
Accrued expenses and other current liabilities	7,991				(4,008		)
Other long-term liabilities	(54		)		277
Net cash provided by operating activities	28,104				47,509
Cash flows from investing activities:
Capital expenditures	(11,456		)		(18,268		)
Acquisition of CVR Nitrogen, LP, net of cash acquired	—				(63,869		)
Net cash used in investing activities	(11,456		)		(82,137		)

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	Nine Months Ended   September 30,
	2017				2016
	(unaudited)
	(in thousands)
Cash flows from financing activities:
Principal and premium payments on 2021 Notes	—				(320,539		)
Principal payment on CRLLC Facility	—				(300,000		)
Principal payments on long-term debt	—				(125,000		)
Payment of revolving debt	—				(49,100		)
Payment of financing costs	—				(10,191		)
Proceeds on issuance of 2023 Notes, net of original issue discount	—				628,869
Proceeds on CRLLC Facility	—				300,000
Contribution from affiliate	—				507
Cash distributions to common unitholders – Affiliates	(778		)		(27,633		)
Cash distributions to common unitholders – Non-affiliates	(1,488		)		(41,956		)
Purchase of noncontrolling interest	—				(5,000		)
Net cash provided by (used in) financing activities	(2,266		)		49,957
Net increase in cash and cash equivalents	14,382				15,329
Cash and cash equivalents, beginning of period	55,595				49,967
Cash and cash equivalents, end of period	$	69,977			$	65,296
Supplemental disclosures:
Cash paid for income taxes, net	$	43			$	14
Cash paid for interest, net of capitalized interest of $150 and $422 in 2017 and 2016, respectively	$	29,896			$	22,304
Non-cash investing and financing activities:
Construction in progress additions included in accounts payable	$	608			$	1,394
Change in accounts payable related to construction in progress additions	$	(3,263	)		$	(3,816	)
Reduction of proceeds from 2023 Notes from original issue discount	$	—			$	16,131
Fair value of common units issued in a business combination	$	—			$	335,693
Fair value of debt assumed in a business combination	$	—			$	367,500

See accompanying notes to the condensed consolidated financial statements.

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CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

September 30, 2017

(unaudited)

(1) Organization and Nature of Business

CVR Partners, LP (referred to as "CVR Partners" or the "Partnership") is a Delaware limited partnership, formed by CVR Energy, Inc. (together with its subsidiaries, but excluding the Partnership and its subsidiaries, "CVR Energy") to own, operate and grow its nitrogen fertilizer business. Nitrogen fertilizer is used by farmers to improve the yield and quality of their crops, primarily corn and wheat. The Partnership principally produces ammonia and urea ammonium nitrate ("UAN"), an aqueous solution of urea and ammonium nitrate. The Partnership's product sales are sold on a wholesale basis in North America.

The Partnership produces nitrogen fertilizer products at two manufacturing facilities, which are located in Coffeyville, Kansas (the "Coffeyville Facility") and East Dubuque, Illinois (the "East Dubuque Facility"). On April 1, 2016, the Partnership completed the merger (the "East Dubuque Merger") with CVR Nitrogen, LP (formerly known as East Dubuque Nitrogen Partners, L.P. and also formerly known as Rentech Nitrogen Partners, L.P.) ("CVR Nitrogen") and with CVR Nitrogen GP, LLC (formerly known as East Dubuque Nitrogen GP, LLC and also formerly known as Rentech Nitrogen GP, LLC) ("CVR Nitrogen GP"), whereby the Partnership acquired the East Dubuque Facility. See Note 4 ("East Dubuque Merger") for further discussion.

The Partnership's subsidiaries include Coffeyville Resources Nitrogen Fertilizers, LLC ("CRNF"), which owns and operates the Coffeyville Facility, and East Dubuque Nitrogen Fertilizers, LLC ("EDNF"), which owns and operates the East Dubuque Facility. Both facilities manufacture ammonia and are able to further upgrade to other nitrogen fertilizer products, principally UAN.

Immediately subsequent to the East Dubuque Merger and as of September 30, 2017, public security holders held approximately 66% of the Partnership's outstanding limited partner interests and Coffeyville Resources, LLC ("CRLLC"), a wholly-owned subsidiary of CVR Energy, held approximately 34% of the Partnership's outstanding limited partner interests and 100% of the noneconomic general partner interest. As of September 30, 2017, Icahn Enterprises L.P. ("IEP") and its affiliates owned approximately 82% of the shares of CVR Energy.

Management and Operations

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

The Partnership is operated by a combination of the general partner's senior management team and CVR Energy's senior management team pursuant to a services agreement among CVR Energy, CVR GP and the Partnership. The various rights and responsibilities of the Partnership's partners are set forth in the limited partnership agreement. The Partnership also is party to a number of agreements with CVR Energy and CVR GP to regulate certain business relations between the Partnership and the other parties thereto. See Note 14 ("Related Party Transactions") for further discussion.

(2) Basis of Presentation

The accompanying Partnership condensed consolidated financial statements include the accounts of CVR Partners and its subsidiaries. All intercompany accounts and transactions have been eliminated in consolidation. The accompanying condensed consolidated financial statements were prepared in accordance with U.S. generally accepted accounting principles ("GAAP") and in accordance with the rules and regulations of the Securities and Exchange Commission ("SEC"). These condensed consolidated financial statements should be read in conjunction with the December 31, 2016 audited consolidated financial statements and notes thereto included in CVR Partners’ Annual Report on Form 10-K for the year ended December 31, 2016, which was filed with the SEC on February 21, 2017 (the "2016 Form 10-K").

The condensed consolidated financial statements include certain selling, general and administrative expenses and direct operating expenses that CVR Energy and its subsidiaries incurred on behalf of the Partnership. These related party transactions are governed by the services agreement. See Note 14 ("Related Party Transactions") for additional discussion of the services agreement and billing and allocation of certain costs.

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CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

September 30, 2017

(unaudited)

In the opinion of the Partnership’s management, the accompanying condensed consolidated financial statements and related notes reflect all adjustments (consisting only of normal recurring adjustments) that are necessary to fairly present the financial position of the Partnership as of September 30, 2017 and December 31, 2016, the results of operations and comprehensive income (loss) of the Partnership for the three and nine months ended September 30, 2017 and 2016, the cash flows of the Partnership for the nine months ended September 30, 2017 and 2016 and the changes in partners’ capital for the Partnership for the nine months ended September 30, 2017.

The preparation of condensed consolidated financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, expenses and the disclosure of contingent assets and liabilities. Actual results could differ from those estimates. Results of operations and cash flows for the interim periods presented are not necessarily indicative of the results that will be realized for the year ending December 31, 2017 or any other interim or annual period.

Planned Major Maintenance Costs

The direct-expense method of accounting is used for maintenance activities, including planned major maintenance activities and other less extensive shutdowns. Maintenance costs are recognized as expense when maintenance services are performed. Planned major maintenance activities generally occur every two to three years.

During the third quarter of 2017, the East Dubuque Facility completed a scheduled turnaround. Overall results were negatively impacted due to the lost production during the downtime that resulted in reduced sales and certain reduced variable expenses included in cost of materials and other and direct operating expenses (exclusive of depreciation and amortization). Exclusive of the impacts due to the lost production, costs of approximately $2.5 million and $2.6 million associated with the 2017 East Dubuque turnaround are included in direct operating expenses (exclusive of depreciation and amortization) in the Condensed Consolidated Statements of Operations for the three and nine months ended September 30, 2017, respectively.

During the second quarter of 2016, the East Dubuque Facility completed a major scheduled turnaround. Overall results were negatively impacted due to the lost production during the downtime that resulted in reduced sales and certain reduced variable expenses included in cost of materials and other and direct operating expenses (exclusive of depreciation and amortization). Exclusive of the impacts due to the lost production, costs of approximately $6.6 million associated with the 2016 East Dubuque turnaround are included in direct operating expenses (exclusive of depreciation and amortization) in the Condensed Consolidated Statements of Operations for the nine months ended September 30, 2016.

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CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

September 30, 2017

(unaudited)

(3) Recent Accounting Pronouncements

In May 2014, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2014-09, creating a new topic, FASB Accounting Standards Codification ("ASC") Topic 606, "Revenue from Contracts with Customers," which supersedes revenue recognition requirements in FASB ASC Topic 605, "Revenue Recognition." This ASU 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. In addition, an entity is required to disclose sufficient information to enable users of financial statements to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. The standard is effective for interim and annual periods beginning after December 15, 2017. The Partnership will adopt this standard as of January 1, 2018 using the modified retrospective application method, whereby the cumulative effect of initially applying the standard is recognized, if applicable, as an adjustment to the opening balance of partners’ capital. The guidance will be applied prospectively and revenues reported in the periods prior to the date of adoption will not be changed. The Partnership is executing its implementation plan to adopt the new standard and is currently finalizing the assessment phase of the plan, after which the Partnership will complete the design and implementation phases of the plan, which will include implementing any changes to existing business processes, internal controls and systems to accommodate the new standard. During the assessment phase, the Partnership has reviewed the majority of its existing revenue streams, including an evaluation of accounting policies, contract reviews, identification of the types of arrangements where differences may arise in the conversion to the new standard, identification of practical expedients to be elected and additional disclosure requirements. The Partnership is still evaluating certain revenue streams and contracts to determine the impact, if any, on the consolidated financial statements and related disclosures. To date, the Partnership has not identified any material differences in its existing revenue recognition methods that would require modification under the new standard. The Partnership has identified potential balance sheet presentation differences as well as additional disclosure requirements that the Partnership is in the process of evaluating.

In February 2016, the FASB issued ASU No. 2016-02, "Leases" ("ASU 2016-02"), creating a new topic, FASB ASC Topic 842, "Leases," which supersedes lease requirements in FASB ASC Topic 840, "Leases." The new standard revises accounting for operating leases by a lessee, among other changes, and requires a lessee to recognize a liability to make lease payments and an asset representing its right to use the underlying asset for the lease term in the balance sheet. The standard is effective for the first interim and annual periods beginning after December 15, 2018, with early adoption permitted. At adoption, ASU 2016-02 will be applied using the modified retrospective application method. The Partnership is formulating an assessment and implementation plan to adopt the new standard. The Partnership expects its assessment and implementation plan to be ongoing during 2017 and 2018 and is currently unable to reasonably estimate the impact of adopting the new leases standard on its consolidated financial statements and related disclosures.

In January 2017, the FASB issued ASU No. 2017-04, "Simplifying the Test for Goodwill Impairment." The new standard simplifies the accounting for goodwill impairments by eliminating step 2 from the goodwill quantitative impairment test. Instead, if the carrying amount of a reporting unit exceeds its fair value, an impairment loss shall be recognized in an amount equal to that excess, limited to the total amount of goodwill allocated to that reporting unit. The standard is effective for interim and annual periods beginning after December 15, 2019 and early adoption is permitted. The Partnership adopted this standard as of January 1, 2017.

(4) East Dubuque Merger

On April 1, 2016, the Partnership completed the East Dubuque Merger as contemplated by the Agreement and Plan of Merger, dated as of August 9, 2015 (the "Merger Agreement"), whereby the Partnership acquired CVR Nitrogen and CVR Nitrogen GP. Under the terms of the Merger Agreement, holders of CVR Nitrogen common units eligible to receive consideration received 1.04 common units representing limited partner interests in CVR Partners and $2.57 in cash, without interest, for each CVR Nitrogen common unit. Pursuant to the Merger Agreement, CVR Partners issued approximately 40.2 million CVR Partners common units and paid approximately $99.2 million in cash consideration to CVR Nitrogen common unitholders and certain holders of CVR Nitrogen phantom units.

The aggregate merger consideration was approximately $802.4 million, including the fair value of CVR Partners common units issued of $335.7 million, a cash contribution of $99.2 million and $367.5 million fair value of assumed debt. During the three and nine months ended September 30, 2016, the Partnership incurred approximately $0.7 million and $3.1 million, respectively, of legal and other professional fees and other merger-related expenses, which were included in selling, general and administrative expenses.

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CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

September 30, 2017

(unaudited)

CVR Nitrogen’s debt arrangements that remained in place after the closing date of the East Dubuque Merger included $320.0 million of its 6.500% notes due 2021 (the "2021 Notes"). The substantial majority of the 2021 Notes were repurchased in June 2016.

Immediately prior to the East Dubuque Merger, CVR Nitrogen also had outstanding balances under a credit agreement with Wells Fargo Bank, National Association, as successor-in-interest by assignment from General Electric Company, as administrative agent (the "Wells Fargo Credit Agreement"). In connection with the closing of the East Dubuque Merger, the Partnership paid $49.4 million for the outstanding balance, accrued interest and fees under the Wells Fargo Credit Agreement, and the Wells Fargo Credit Agreement was terminated.

(5) Share‑Based Compensation

Certain employees of CVR Partners and employees of CVR Energy who perform services for the Partnership under the services agreement with CVR Energy participate in equity-based compensation plans of CVR Partners' affiliates. Accordingly, CVR Partners has recorded compensation expense for these plans. All compensation expense related to these plans for full-time employees of CVR Partners has been attributed 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 recognizes the costs of share-based compensation in selling, general and administrative expenses and direct operating expenses (exclusive of depreciation and amortization). Allocated expense amounts related to plans for which the Partnership is responsible for payment are reflected as an increase or decrease to accrued expenses and other current liabilities.

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 September 30, 2017, only grants of 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’ employees, officers, consultants and directors.

Performance Unit Awards

In December 2015, CVR Energy entered into a performance unit award agreement (the "2015 Performance Unit Award Agreement") with its Chief Executive Officer. Compensation cost for the 2015 Performance Unit Award Agreement was recognized over the performance cycle from January 1, 2016 to December 31, 2016. The awards were fully vested at December 31, 2016 and the Partnership reimbursed CVR Energy $0.5 million for its allocated portion of the performance unit award during the first quarter of 2017. As of December 31, 2016, the Partnership had a liability of $0.5 million, for its allocated portion of the 2015 Performance Unit Award Agreement, which was recorded in accrued expenses and other current liabilities on the Condensed Consolidated Balance Sheets. Compensation expense recorded for the three and nine months ended September 30, 2016 related to the awards was approximately $0.2 million and $0.4 million, respectively.

In December 2016, CVR Energy entered into a performance unit award agreement (the "2016 Performance Unit Award Agreement") with its Chief Executive Officer. Compensation cost for the 2016 Performance Unit Award Agreement will be recognized over the performance cycle from January 1, 2017 to December 31, 2017. The performance unit award represents the right to receive, upon vesting, a cash payment equal to a defined threshold in accordance with the award agreement, multiplied by a performance factor that is based upon the achievement of certain operating objectives. The Partnership will be responsible for reimbursing CVR Energy for its allocated portion of the performance unit award. Assuming a target performance threshold and that the allocation of costs from CVR Energy remains consistent with the allocation percentages in place at September 30, 2017, there was approximately $0.1 million of total unrecognized compensation cost related to the 2016 Performance Unit Award Agreement to be recognized over approximately 0.3 years. Compensation expense recorded for the three and nine months ended September 30, 2017 related to the awards was approximately $0.1 million and $0.4 million, respectively. The Partnership will be responsible for reimbursing CVR Energy for its allocated portion of the awards. As of September 30, 2017, the Partnership had a liability of $0.4 million, for its allocated portion of

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the 2016 Performance Unit Award Agreement, which is recorded in accrued expenses and other current liabilities on the Condensed Consolidated Balance Sheets.

Incentive Unit Awards – CVR Energy

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

Assuming the portion of time spent on CVR Partners related matters by CVR Energy employees providing services to CVR Partners remains consistent with the amount of services provided during September 30, 2017, there was approximately $0.7 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 1.0 year. Inclusion of a vesting table would not be meaningful due to changes in allocation percentages that may occur from time to time. The unrecognized compensation expense has been determined by the number of incentive units and respective allocation percentage for individuals for whom, as of September 30, 2017, compensation expense has been allocated to the Partnership. Compensation expense recorded for both the three months ended September 30, 2017 and 2016 was approximately $0.2 million. Compensation expense recorded for the nine months ended September 30, 2017 and 2016 was approximately $0.7 million and $0.2 million, respectively. The Partnership is responsible for reimbursing CVR Energy for its allocated portion of the awards.

As of September 30, 2017 and December 31, 2016, the Partnership had a liability related to these awards of $1.0 million and $0.4 million, respectively, which is recorded in accrued expenses and other current liabilities on the Condensed Consolidated Balance Sheets.

Long-Term Incentive Plan – CVR Partners

The Partnership has a long-term incentive plan ("CVR Partners LTIP") that provides for the grant of options, unit appreciation rights, distribution equivalent rights, restricted units, phantom units and other unit-based awards, each in respect of common units. Individuals eligible to receive awards pursuant to the CVR Partners LTIP include (i) employees of the Partnership and its subsidiaries, (ii) employees of the general partner, (iii) members of the board of directors of the general partner, and (iv) certain CVR Partners' parent's employees, consultants and directors who perform services for the benefit of the Partnership.

Through the CVR Partners LTIP, phantom unit awards outstanding include awards granted to employees of both the Partnership and the general partner. Phantom unit awards made to employees of the general partner are considered non-employee equity based-awards. The phantom unit awards outstanding vest over a three-year period. The maximum number of common units issuable under the CVR Partners LTIP is 5,000,000. As of September 30, 2017, there were 4,820,215 common units available for issuance under the CVR Partners LTIP. As all phantom unit awards discussed below are cash settled awards, they do not reduce the number of common units available for issuance.

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

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A summary of the phantom unit activity during the nine months ended September 30, 2017 is presented below:

	Phantom Units			Weighted-Average Grant Date Fair Value
Non-vested at January 1, 2017	771,786			$	6.47
Granted	3,172			4.73
Vested	(7,333	)		8.03
Forfeited	(23,222	)		6.49
Non-vested at September 30, 2017	744,403			$	6.45

Unrecognized compensation expense associated with the unvested phantom units at September 30, 2017 was approximately $1.0 million and is expected to be recognized over a weighted average period of 1.0 year. Compensation expense recorded for the three months ended September 30, 2017 related to the awards under the CVR Partners LTIP was approximately $0.3 million. Compensation benefit recorded for the three months ended September 30, 2016 related to the awards under the CVR Partners LTIP was approximately $0.2 million. Compensation expense recorded for the nine months ended September 30, 2017 and 2016 related to the awards under the CVR Partners LTIP was approximately $0.7 million and $1.2 million, respectively. Compensation expense related to the awards to employees of the Partnership and its subsidiaries under the CVR Partners LTIP has been recorded in selling, general and administrative expenses - third parties and direct operating expenses (exclusive of depreciation and amortization) - third parties. Compensation expense related to the awards issued to employees of the general partner under the CVR Partners LTIP has been recorded in selling, general and administrative expenses - affiliates and direct operating expenses (exclusive of depreciation and amortization) - affiliates. As of September 30, 2017 and December 31, 2016, the Partnership had a liability of $1.6 million and $1.0 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.

(6) Inventories

Inventories consisted of the following:

	September 30, 2017				December 31, 2016
	(in thousands)
Finished goods	$	17,422			$	15,860
Raw materials and precious metals	7,022				8,818
Parts and supplies	33,112				33,489
Total inventories	$	57,556			$	58,167

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(7) Property, Plant and Equipment

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

	September 30, 2017				December 31, 2016
	(in thousands)
Land and improvements	$	12,987			$	12,995
Buildings and improvements	17,298				14,881
Machinery and equipment	1,351,165				1,343,980
Automotive equipment	599				599
Furniture and fixtures	1,421				1,437
Railcars	16,261				16,261
Construction in progress	7,508				9,588
	1,407,239				1,399,741
Less: Accumulated depreciation	323,240				269,620
Total property, plant and equipment, net	$	1,083,999			$	1,130,121

Capitalized interest recognized as a reduction of interest expense was approximately $41,000 and $21,000 for the three months ended September 30, 2017 and 2016, respectively. Capitalized interest recognized as a reduction of interest expense was approximately $0.2 million and $0.4 million, respectively, for the nine months ended September 30, 2017 and 2016.

(8) 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.

Immediately subsequent to the East Dubuque Merger and as of September 30, 2017, the Partnership had a total of 113,282,973 common units issued and outstanding, of which 38,920,000 common units were owned by CRLLC, representing approximately 34% of the total Partnership common units outstanding.

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

Available cash begins with Adjusted EBITDA reduced for cash needed for (i) net cash interest expense (excluding capitalized interest) and debt service and other contractual obligations; (ii) maintenance capital expenditures; and (iii) to the extent applicable, major scheduled turnaround expenses, reserves for future operating or capital needs that the board of directors of the general partner deems necessary or appropriate, and expenses associated with the East Dubuque Merger, if any. Adjusted EBITDA is defined as EBITDA (net income before interest expense, net, income tax expenses, depreciation and amortization) further adjusted for the impact of major scheduled turnaround expense, gain or loss on extinguishment of debt, loss on disposition of assets, expenses associated with the East Dubuque Merger and business interruption insurance recovery, when applicable. Available cash for distribution may be increased by the release of previously established cash reserves, if any, at the discretion of the board of directors of the general partner, and available cash is increased by the business interruption insurance proceeds and the impact of purchase accounting. Actual distributions are set by the board of directors of the general partner. The board of directors of the general partner may modify the cash distribution policy at any time, and the partnership agreement does not require the board of directors of the general partner to make distributions at all.

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The following is a summary of cash distributions paid to the Partnership's unitholders during 2017 for the respective quarters to which the distributions relate:

	December 31, 2016				March 31, 2017				June 30, 2017				Total Cash Distributions Paid in 2017
	($ in millions, except per common unit amounts)
Amount paid to CRLLC	$	—			$	0.8			$	—			$	0.8
Amount paid to public unitholders	—				1.5				—				1.5
Total amount paid	$	—			$	2.3			$	—			$	2.3
Per common unit	$	—			$	0.02			$	—			$	0.02
Common units outstanding (in thousands)	113,283				113,283				113,283

(9) Goodwill

The Partnership evaluates the carrying value of goodwill annually as of November 1 and between annual evaluations if events occur or circumstances change that would more likely than not reduce the fair value of the reporting unit below its carrying amount. The Partnership's goodwill reporting unit is the Coffeyville Facility.

Based on a significant decline in market capitalization and lower cash flow forecasts resulting from weakened fertilizer pricing trends that occurred during the third quarter of 2017, the Partnership identified a triggering event and therefore performed an interim goodwill impairment test as of August 31, 2017. The quantitative goodwill impairment analysis compares the fair value of the reporting unit to its carrying value. The Coffeyville Facility reporting unit fair value is based upon consideration of various valuation methodologies, including guideline public company multiples and projected future cash flows discounted at rates commensurate with the risk involved. The carrying amount of the reporting unit was less than its fair value; therefore, no impairment was recorded.

The fair value of the reporting unit exceeded its carrying value by approximately 12% based upon the results of the interim goodwill impairment test as of August 31, 2017. Judgments and assumptions are inherent in management’s estimates used to determine the fair value of the reporting unit. Assumptions used in the discounted cash flows ("DCF") included estimating appropriate discount rates and growth rates and estimating the amount and timing of expected future cash flows. The discount rates used in the DCF, which are intended to reflect the risks inherent in future cash flow projections, are based on estimates of the weighted-average cost of capital of a market participant. Such estimates are derived from analysis of peer companies and consider the industry weighted average return on debt and equity from a market participant perspective. The most significant assumption to determining the fair value of the reporting unit was forecasted fertilizer pricing. Changes in assumptions may result in a change in management's estimates and may result in an impairment in future periods, including, but not limited to, further declines in the forecasted fertilizer pricing. The Partnership also calculated fair value estimates derived from the market approach utilizing the public company market multiple method, which required assumptions about the applicability of those multiples to the Coffeyville Facility reporting unit.

(10) Net Income (Loss) per Common Unit

The Partnership's net income (loss) is allocated wholly to the common units as the general partner does not have an economic interest. Basic and diluted net income (loss) per common unit is calculated by dividing net income (loss) by the weighted-average number of common units outstanding during the period. The common units issued during the period are included on a weighted-average basis for the days in which they were outstanding.

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(11) Accrued Expenses and Other Current Liabilities

Accrued expenses and other current liabilities were as follows:

	As of   September 30,   2017				As of   December 31,   2016
	(in thousands)
Property taxes	$	1,700			$	1,742
Accrued interest	17,635				2,683
Railcar maintenance accruals	152				2,502
Affiliates (1)	2,844				2,515
Other accrued expenses and liabilities	1,584				2,932
Total accrued expenses and other current liabilities	$	23,915			$	12,374

________________________________

(1)	Accrued expenses and other current liabilities include amounts owed by the Partnership to CVR Energy under the feedstock and shared services agreement. Refer to Note 14 ("Related Party Transactions") for additional discussion.

(12) Debt

Long-term debt consisted of the following:

	As of   September 30,   2017				As of   December 31,   2016
	(in thousands)
9.250% senior secured notes, due 2023	$	645,000			$	645,000
6.500% notes, due 2021	2,240				2,240
Total long-term debt, before debt issuance costs and discount	647,240				647,240
Less:
Unamortized discount	13,914				15,220
Unamortized debt issuance costs	8,148				8,913
Total long-term debt, net of current portion	$	625,178			$	623,107

For the three months ended September 30, 2017 and 2016, amortization of the discount on debt and amortization of debt issuance costs reported as interest expense and other financing costs totaled approximately $0.7 million and $0.6 million, respectively. For the nine months ended September 30, 2017 and 2016, amortization of the discount on debt and amortization of debt issuance costs reported as interest expense and other financing costs totaled approximately $2.1 million and $1.0 million, respectively.

2023 Notes

On June 10, 2016, the Partnership and CVR Nitrogen Finance Corporation ("CVR Nitrogen Finance"), an indirect wholly-owned subsidiary of the Partnership, (together the "2023 Notes Issuers"), certain subsidiary guarantors named therein and Wilmington Trust, National Association, as trustee and as collateral trustee, completed a private offering of $645.0 million aggregate principal amount of 9.250% Senior Secured Notes due 2023 (the "2023 Notes"). The 2023 Notes mature on June 15, 2023, unless earlier redeemed or repurchased by the issuers. Interest on the 2023 Notes is payable semi-annually in arrears on June 15 and December 15 of each year. The 2023 Notes are guaranteed on a senior secured basis by all of the Partnership’s existing subsidiaries.

The 2023 Notes contain customary covenants for a financing of this type that, among other things, restrict the Partnership’s ability and the ability of certain of its subsidiaries to: (i) sell assets; (ii) pay distributions on, redeem or repurchase the Partnership’s units or

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redeem or repurchase its subordinated debt; (iii) make investments; (iv) incur or guarantee additional indebtedness or issue preferred units; (v) create or incur certain liens; (vi) enter into agreements that restrict distributions or other payments from the Partnership’s restricted subsidiaries to the Partnership; (vii) consolidate, merge or transfer all or substantially all of the Partnership’s assets; (viii) engage in transactions with affiliates; and (ix) create unrestricted subsidiaries.

The indenture governing the 2023 Notes prohibits the Partnership from making distributions to unitholders if any default or event of default (as defined in the indenture) exists. In addition, the indenture limits the Partnership's ability to pay distributions to unitholders. The covenants will apply differently depending on the Partnership's fixed charge coverage ratio (as defined in the indenture). If the fixed charge coverage ratio is not less than 1.75 to 1.0, the Partnership will generally be permitted to make restricted payments, including distributions to its unitholders, without substantive restriction. If the fixed charge coverage ratio is less than 1.75 to 1.0, the Partnership will generally be permitted to make restricted payments, including distributions to our unitholders, up to an aggregate $75.0 million basket plus certain other amounts referred to as "incremental funds" under the indenture. As of September 30, 2017, the ratio was less than 1.75 to 1.0. Restricted payments have been made, and $72.7 million of the basket was available as of September 30, 2017. The Partnership was in compliance with the covenants contained in the 2023 Notes as of September 30, 2017.

Included in other current liabilities on the Condensed Consolidated Balance Sheets is accrued interest payable totaling approximately $17.6 million and $2.7 million, respectively, as of September 30, 2017 and December 31, 2016 related to the 2023 Notes. At September 30, 2017 and December 31, 2016, respectively, the estimated fair value of the 2023 Notes was approximately $686.9 million and $664.4 million. This estimate of fair value is Level 2 as it was determined by quotations obtained from a broker-dealer who makes a market in these and similar securities.

2021 Notes

The $320.0 million of 2021 Notes were issued by CVR Nitrogen and CVR Nitrogen Finance prior to the East Dubuque Merger. The 2021 Notes bear interest at a rate of 6.500% per annum, payable semi-annually in arrears on April 15 and October 15 of each year. The 2021 Notes are scheduled to mature on April 15, 2021, unless repurchased or redeemed earlier in accordance with their terms. The substantial majority of the 2021 Notes were repurchased in 2016. During the nine months ended September 30, 2016, the Partnership recognized a loss on debt extinguishment of $5.1 million. As of September 30, 2017 and December 31, 2016, $2.2 million of principal amount of the 2021 Notes remained outstanding and accrued interest was nominal.

Asset Based (ABL) Credit Facility

On September 30, 2016, the Partnership entered into a senior secured asset based revolving credit facility (the "ABL Credit Facility") with a group of lenders and UBS AG, Stamford Branch ("UBS"), as administrative agent and collateral agent. The ABL Credit Facility has an aggregate principal amount of availability of up to $50.0 million with an incremental facility, which permits an increase in borrowings of up to $25.0 million in the aggregate subject to additional lender commitments and certain other conditions. The proceeds of the loans may be used for capital expenditures and working capital and general corporate purposes of the Partnership and its subsidiaries. The ABL Credit Facility provides for loans and standby letters of credit in an amount up to the aggregate availability under the facility, subject to meeting certain borrowing base conditions, with sub-limits of the lesser of 10% of the total facility commitment and $5.0 million for swingline loans and $10.0 million for letters of credit. The ABL Credit Facility is scheduled to mature on September 30, 2021.

At the option of the borrowers, loans under the ABL Credit Facility initially bear interest at an annual rate equal to (i) 2.00% plus LIBOR or (ii) 1.00% plus a base rate, subject to a 0.50% step-down based on the previous quarter’s excess availability. The borrowers must also pay a commitment fee on the unutilized commitments and also pay customary letter of credit fees.

The ABL Credit Facility also contains customary covenants for a financing of this type that limit the ability of the Partnership and its subsidiaries to, among other things, incur liens, engage in a consolidation, merger, purchase or sale of assets, pay dividends, incur indebtedness, make advances, investments and loans, enter into affiliate transactions, issue equity interests or create subsidiaries and unrestricted subsidiaries. The ABL Credit Facility also contains a fixed charge coverage ratio financial covenant, as defined therein. The Partnership was in compliance with the covenants of the ABL Credit Facility as of September 30, 2017.

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As of September 30, 2017, the Partnership and its subsidiaries had availability under the ABL Credit Facility of $47.6 million. There were no borrowings outstanding under the ABL Credit Facility as of September 30, 2017.

CRLLC Facility

On April 1, 2016, in connection with the closing of the East Dubuque Merger, the Partnership entered into a $300.0 million senior term loan credit facility (the "CRLLC Facility") with CRLLC, as the lender, the proceeds of which were used by the Partnership (i) to fund the repayment of amounts outstanding under the Wells Fargo Credit Agreement discussed in Note 4 ("East Dubuque Merger"), (ii) to pay the cash consideration and to pay fees and expenses in connection with the East Dubuque Merger and related transactions and (iii) to repay all of the loans outstanding under the Credit Agreement discussed below. The CRLLC Facility had a term of two years and an interest rate of 12.0% per annum. Interest was calculated on the basis of the actual number of days elapsed over a 360-day year and payable quarterly. In April 2016, the Partnership borrowed $300.0 million under the CRLLC Facility. On June 10, 2016, the Partnership paid off the $300.0 million outstanding under the CRLLC Facility, paid $7.0 million in interest, and terminated the CRLLC Facility.

Credit Agreement

On April 13, 2011, CRNF, as borrower, and CVR Partners, as guarantor, entered into a credit facility with a group of lenders including Goldman Sachs Lending Partners LLC, as administrative and collateral agent (the "Credit Agreement"). The Credit Agreement included 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. At March 31, 2016, the effective rate of the term loan was approximately 3.98%. On April 1, 2016, the Partnership repaid all amounts outstanding under the Credit Agreement and the Credit Agreement was terminated.

(13) 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
	(in thousands)
Three months ending December 31, 2017	$	1,162			$	8,907
Year Ending December 31,
2018	4,424				17,321
2019	3,676				12,099
2020	3,138				6,978
2021	2,955				5,572
Thereafter	3,039				54,386
	$	18,394			$	105,263

CRNF leases railcars and facilities under long-term operating leases. Lease expense included in cost of materials and other for the three months ended September 30, 2017 and 2016 totaled approximately $1.2 million and $1.3 million, respectively. Lease expense included in cost of materials and other for the nine months ended September 30, 2017 and 2016 totaled approximately $3.7 million and $3.6 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 may be renewed or replaced as they expire. The Partnership leases railcars from a related party, which is included in the operating lease commitments shown above. See Note 14 ("Related Party Transactions") for further discussion.

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CRNF’s purchase obligation for pet coke from a subsidiary of CVR Refining has been derived from a calculation of the average pet coke price paid to such subsidiary over the preceding two-year period. See Note 14 ("Related Party Transactions") for further discussion of the coke supply agreement.

CRNF is party to a hydrogen purchase and sale agreement with a subsidiary of CVR Refining, pursuant to which CRNF agrees to pay a monthly fixed fee. See Note 14 ("Related Party Transactions") for further discussion of the hydrogen purchase and sale agreement.

CRNF is party to the Amended and Restated On-Site Product Supply Agreement with The BOC Group, Inc. (as predecessor in interest to Linde LLC). Pursuant to the agreement, which expires in 2020, CRNF is required to take as available and pay for the supply of oxygen and nitrogen to the fertilizer operation. Expenses associated with this agreement are included in direct operating expenses (exclusive of depreciation and amortization), and, for the three months ended September 30, 2017 and 2016, totaled approximately $1.1 million and $1.0 million, respectively, and for the nine months ended September 30, 2017 and 2016, totaled approximately $3.2 million and $2.9 million, respectively.

CRNF is a party to a pet coke supply agreement with HollyFrontier Corporation. The term of this agreement ends in December 2017. The delivered cost of this pet coke is included in cost of materials and other and totaled approximately $1.0 million and $1.1 million, respectively, for the three months ended September 30, 2017 and 2016 and totaled approximately $3.0 million and $3.6 million, respectively, for the nine months ended September 30, 2017 and 2016.

EDNF is a party to a utility service agreement with Jo-Carroll Energy, Inc. The term of this agreement ends in 2019 and includes certain charges on a take-or-pay basis. The cost of utilities is included in direct operating expenses (exclusive of depreciation and amortization) and amounts associated with this agreement totaled approximately $2.5 million for both the three months ended September 30, 2017 and 2016 and totaled approximately $8.0 million and $4.3 million, respectively, for the nine months ended September 30, 2017 and 2016.

Commitments for natural gas purchases consist of the following:

	September 30, 2017
	(in thousands, except weighted average rate)
MMBtus under fixed-price contracts	2,169
Commitments to purchase natural gas	$	6,488
Weighted average rate per MMBtu (1)	$	2.99

________________________________

(1)	Weighted average rate per MMBtu is based on the fixed rates applicable to each contract, exclusive of transportation costs.

Litigation

From time to time, the Partnership is involved in various lawsuits arising in the normal course of business, including environmental, health and safety ("EHS") matters described below under "Environmental, Health and Safety Matters." Liabilities, if any, related to such litigation are recognized when the related costs are probable and can be reasonably estimated. These provisions are reviewed at least quarterly and adjusted to reflect the impacts of negotiations, settlements, rulings, advice of legal counsel and other information and events pertaining to a particular case. It is possible that management’s estimates of the outcomes will change within the next year due to uncertainties inherent in litigation and settlement negotiations. There were no new proceedings or material developments in proceedings from those provided in the 2016 Form 10-K. In the opinion of management, the ultimate resolution of any other litigation matters is not expected to have a material adverse effect on the accompanying condensed consolidated financial statements. There can be no assurance that management’s beliefs or opinions with respect to liability for potential litigation matters are accurate.

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(unaudited)

Environmental, Health and Safety Matters

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

There have been no new developments or material changes to the environmental accruals or expected capital expenditures related to compliance with environmental matters from those provided in the 2016 Form 10-K. The Partnership believes its subsidiaries are in material compliance with existing EHS rules and regulations. There can be no assurance that the EHS matters which may develop in the future will not have a material adverse effect on the Partnership's business, financial condition or results of operations.

(14) Related Party Transactions

Related Party Agreements

CVR Partners and its subsidiaries are party to, or otherwise subject to certain agreements with CVR Energy and its subsidiaries (including CVR Refining and its subsidiary Coffeyville Resources Refining & Marketing, LLC ("CRRM")) that govern the business relations among each party including: the (i) Feedstock and Shared Services Agreement; (ii) Hydrogen Purchase and Sale Agreement; (iii) Coke Supply Agreement; (iv) Environmental Agreement; (v) Services Agreement; (vi) GP Services Agreement; and (vii) Limited Partnership Agreement. The agreements are described as in effect at September 30, 2017. Except as otherwise described below, there have been no new developments or material changes to these agreements from those provided in the 2016 Form 10-K.

Amounts owed to CVR Partners and its subsidiaries 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 its subsidiaries with respect to these agreements are included in accounts payable, personnel accruals and accrued expenses and other current liabilities on the Partnership's Condensed Consolidated Balance Sheets.

Feedstock and Shared Services Agreement

CRNF is party to a feedstock and shared services agreement with CRRM under which the two parties provide feedstock and other services to one another. These feedstocks and services are utilized in the respective production processes of CRRM's Coffeyville, Kansas refinery and CRNF's Coffeyville Facility. The agreement was amended and restated effective January 1, 2017.

Prior to January 1, 2017, CRNF and CRRM transferred hydrogen to one another pursuant to the feedstock and shared services agreement. CRNF is not required to sell hydrogen to CRRM if such hydrogen is required for operation of CRNF's Coffeyville Facility, 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, when applicable. Net monthly receipts of hydrogen from CRRM have been reflected in cost of materials and other for CVR Partners, when applicable. For the three and nine months ended September 30, 2016, the net sales generated from the sale of hydrogen to CRRM were approximately $1.2 million and $2.9 million, respectively. At December 31, 2016, there was approximately $0.1 million included in accounts payable on the Condensed Consolidated Balance Sheets associated with net hydrogen purchases.

Beginning January 1, 2017, hydrogen purchases from CRRM are governed pursuant to the hydrogen purchase and sale agreement discussed below, but hydrogen sales to CRRM remain governed pursuant to the feedstock and shared services agreement. For the nine months ended September 30, 2017, the gross sales generated from the sale of hydrogen to CRRM pursuant to the feedstock and shared services agreement were approximately $0.1 million, which is included in net sales in the Condensed Consolidated Statements of Operations. There were no gross sales generated from the sale of hydrogen to CRRM for the three months ended September 30, 2017. The monthly hydrogen sales are cash settled net on a monthly basis with hydrogen purchases, pursuant to the hydrogen purchase and sale agreement.

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CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

September 30, 2017

(unaudited)

The feedstock and shared services agreement also provides a mechanism pursuant to which CRNF transfers a tail gas stream to CRRM. CRNF receives the benefit of eliminating a waste gas stream and recovers the fuel value of the tail gas system. For the three and nine months ended September 30, 2017 and 2016, 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 Coffeyville Facility to transfer the tail gas. CRNF agreed to pay CRRM the cost of installing the pipe and provide an additional 15% to cover the cost of capital, which was due from CRNF to CRRM over four years. At both September 30, 2017 and December 31, 2016, there were assets of approximately $0.2 million included in prepaid expenses and other current assets and approximately $0.5 million and $0.6 million, respectively, included in other long-term assets in the Condensed Consolidated Balance Sheets.

At September 30, 2017 and December 31, 2016, receivables of $0.1 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 transfers and tail gas discussed above. At September 30, 2017 and December 31, 2016, current obligations of approximately $0.8 million and $0.9 million 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.

Hydrogen Purchase and Sale Agreement

CRNF and CRRM entered into a hydrogen purchase and sale agreement that was effective on January 1, 2017, pursuant to which CRRM agrees to sell and deliver a committed hydrogen volume of 90,000 mscf per month, and CRNF agrees to purchase and receive the committed volume. The committed volume pricing is based on a monthly fixed fee (based on the fixed and capital charges associated with producing the committed volume) and a monthly variable fee (based on the natural gas price associated with hydrogen actually received). In the event CRNF fails to take delivery of the full committed volume in a month, CRNF remains obligated to pay CRRM for the monthly fixed fee and the monthly variable fee based upon the actual hydrogen volume received, if any. In the event CRRM fails to deliver any portion of the committed volume for the applicable month for any reason other than planned repairs and maintenance, CRNF will be entitled to a pro-rata reduction of the monthly fixed fee. CRNF also has the option to purchase excess volume of up to 60,000 mscf per month, or more upon mutual agreement, from CRRM, if available for purchase.

A portion of the monthly variable fee, as defined in the terms of the agreement, is determined according to the natural gas costs incurred by CRRM in operation of the hydrogen plant, which will reflect market-driven changes in the natural gas prices. In addition, certain fixed fees will be adjusted on an annual basis according to the changes in a cost index, as defined in the terms of the agreement.

CRRM is not required to sell hydrogen to CRNF if such sale would adversely affect CVR Refining’s classification as a partnership for federal income tax purposes, and is not required to sell hydrogen to CRNF in excess of the committed volume if such volumes are needed for CRRM’s operations.

The agreement has an initial term of 20 years and will be automatically extended following the initial term for additional successive five-year renewal terms unless either party gives 180 days written notice. Certain fees under the agreement are subject to modification after this initial term. The agreement contains customary terms related to indemnification, as well as termination for breach, by mutual consent, or due to insolvency or cessation of operations.

For the three and nine months ended September 30, 2017, the cost of hydrogen purchases from CRRM was approximately $0.9 million and $3.0 million, respectively, which were included in cost of materials and other in the Condensed Consolidated Statement of Operations. The monthly hydrogen purchases are cash settled net on a monthly basis with hydrogen sales pursuant to the feedstock and shared services agreement. At September 30, 2017, current obligations, net of any amounts due to CRNF under the feedstock and shared services agreement for hydrogen, of approximately $0.4 million were included in accounts payable on the Condensed Consolidated Balance Sheets associated with net hydrogen purchases from CRRM.

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CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

September 30, 2017

(unaudited)

Coke Supply Agreement

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

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

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

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

The cost of pet coke associated with the transfer of pet coke from CRRM to CRNF were approximately $0.6 million and $0.5 million for the three months ended September 30, 2017 and 2016, respectively, which was recorded in cost of materials and other. For the nine months ended September 30, 2017 and 2016, these expenses were approximately $1.6 million and $1.7 million, respectively. Payables of approximately $0.1 million related to the coke supply agreement were included in accounts payable on the Condensed Consolidated Balance Sheets at both September 30, 2017 and December 31, 2016.

Services Agreement

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

Net amounts incurred under the services agreement for the three and nine months ended September 30, 2017 and 2016 were as follows:

	Three Months Ended   September 30,								Nine Months Ended   September 30,
	2017				2016				2017				2016
	(in thousands)
Direct operating expenses (exclusive of depreciation and amortization) — Affiliates	$	766			$	976			$	2,158			$	2,616
Selling, general and administrative expenses — Affiliates	3,239				2,939				9,398				8,562
Total	$	4,005			$	3,915			$	11,556			$	11,178

For services performed in connection with the services agreement, the Partnership recognized personnel costs, excluding amounts related to share-based compensation that are disclosed in Note 5 ("Share‑Based Compensation"), of $1.8 million and $1.7 million, respectively, for the three months ended September 30, 2017 and 2016. For services performed in connection with the services agreement, the Partnership recognized personnel costs, excluding amounts related to share-based compensation, of $5.0 million for both the nine months ended September 30, 2017 and 2016. At September 30, 2017 and December 31, 2016, current obligations of $3.7 million and $3.5 million, respectively, were included in accounts payable and accrued expenses and other current liabilities on the Condensed Consolidated Balance Sheets with respect to amounts billed in accordance with the services agreement.

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CVR PARTNERS, LP AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

September 30, 2017

(unaudited)

Limited Partnership Agreement

The partnership agreement provides that the Partnership will reimburse its general partner for all direct and indirect expenses it incurs or payments it makes on behalf of the Partnership (including salary, bonus, incentive compensation and other amounts paid to any person to perform services for the Partnership or for its general partner in connection with operating the Partnership). Pursuant to the partnership agreement, the Partnership incurred approximately $0.8 million and $0.7 million for the three months ended September 30, 2017 and 2016, respectively, primarily for personnel costs related to the compensation of executives at the general partner, who manage the Partnership's business. For the nine months ended September 30, 2017 and 2016, approximately $2.4 million and $2.9 million were incurred related to amounts due for reimbursement, respectively. At September 30, 2017 and December 31, 2016, current obligations of $1.9 million and $2.0 million, respectively, were included in personnel accruals on the Condensed Consolidated Balance Sheets related to amounts outstanding in accordance with the limited partnership agreement.

Insight Portfolio Group

Insight Portfolio Group LLC ("Insight Portfolio Group") is an entity formed by Mr. Carl C. 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.

CRLLC Facility

On April 1, 2016, in connection with the closing of the East Dubuque Merger, the Partnership entered into the CRLLC Facility. See Note 12 ("Debt") for further discussion.

Parent Affiliate Units

In March 2016, CVR Energy purchased 400,000 CVR Nitrogen common units, representing approximately 1% of the outstanding CVR Nitrogen limited partner interests. CVR Energy did not receive merger consideration for these designated CVR Nitrogen common units. Subsequent to the East Dubuque Merger, the Partnership purchased 400,000 CVR Nitrogen common units from CVR Energy during the three months ended June 30, 2016 for $5.0 million.

Railcar Lease Agreements and Maintenance

CRNF has agreements to lease a total of 115 UAN railcars from ARI Leasing, LLC ("ARI"), a company controlled by IEP. The lease agreements will expire in 2023. For the three and nine months ended September 30, 2017, rent expense of approximately $0.2 million and $0.7 million, respectively, was recorded in cost of materials and other in the Condensed Consolidated Statement of Operations related to these agreements. Rent expense related to these agreements were nominal for the three and nine months ended September 30, 2016.

In the second quarter of 2017, CRNF entered into an agreement to lease an additional 70 UAN railcars from ARI. The lease agreement has a term of 5 years. The Partnership obtained physical receipt of the majority of the leased railcars and associated lease payment obligations commenced during the third quarter of 2017. Almost all of the additional railcars were received in October 2017.

American Railcar Industries, Inc., a company controlled by IEP, performed railcar maintenance for CRNF and the expense associated with this maintenance was approximately $0.2 million for the nine months ended September 30, 2017 and was included in cost of materials and other in the Condensed Consolidated Statement of Operations. There were no expenses associated with this maintenance for the three months ended September 30, 2017.

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

The following discussion and analysis of our financial condition, results of operations and cash flows should be read in conjunction with the unaudited condensed consolidated financial statements and related notes and with the statistical information and financial data appearing in this Report, as well as the 2016 Form 10-K. Results of operations and cash flows for the three and nine months ended September 30, 2017 and 2016 are not necessarily indicative of results to be attained for any other period.

Forward-Looking Statements

This Report, including this Management’s Discussion and Analysis of Financial Condition and Results of Operations, contains "forward-looking statements" as defined by the Securities and Exchange Commission ("SEC"), including statements concerning contemplated transactions and strategic plans, expectations and objectives for future operations. Forward-looking statements include, without limitation:

•	statements, other than statements of historical fact, that address activities, events or developments that we expect, believe or anticipate will or may occur in the future;

•	statements relating to future financial or operational performance, future distributions, future capital sources and capital expenditures; and

•	any other statements preceded by, followed by or that include the words "anticipates," "believes," "expects," "plans," "intends," "estimates," "projects," "could," "should," "may" or similar expressions.

Although we believe that our plans, intentions and expectations reflected in or suggested by the forward-looking statements we make in this Report, including this Management’s Discussion and Analysis of Financial Condition and Results of Operations, are reasonable, we can give no assurance that such plans, intentions or expectations will be achieved. These statements are based on assumptions made by us based on our experience and perception of historical trends, current conditions, expected future developments and other factors that we believe are appropriate in the circumstances. Such statements are subject to a number of risks and uncertainties, many of which are beyond our control. You are cautioned that any such statements are not guarantees of future performance and that 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 the section captioned "Risk Factors" in the 2016 Form 10-K, filed with the SEC on February 21, 2017. 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;

 

•	our reliance on the natural gas and electricity that we purchase from third parties;

•	the supply and price levels of essential raw materials;

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

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

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•	competition in the nitrogen fertilizer businesses;

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

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

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

•	the risk of security breaches;

•	our lack of asset diversification;

•	our dependence on significant customers;

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

•	our partial dependence on customer and distributor transportation of purchased goods;

•	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;

•	the risk of labor disputes and adverse employee relations;

•	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;

•	instability and volatility in the capital and credit markets; and

•	CVR Energy and its affiliates may compete with us.

All forward-looking statements contained in this Report speak only as of the date of this Report. We undertake no obligation to publicly update or revise any forward-looking statements to reflect events or circumstances that occur after the date of this Report, or to reflect the occurrence of unanticipated events, except to the extent required by law.

Partnership Overview

CVR Partners, LP ("CVR Partners," the "Partnership," "we," "us" or "our") is a Delaware limited partnership formed by CVR Energy to own, operate and grow our nitrogen fertilizer business. We produce and distribute nitrogen fertilizer products, which are used by farmers to improve the yield and quality of their crops. Our principal products are UAN and ammonia. All of our products are sold on a wholesale basis.

We produce our nitrogen fertilizer products at two manufacturing facilities, which are located in Coffeyville, Kansas and East Dubuque, Illinois. We acquired the East Dubuque, Illinois facility in April 2016 through our acquisition of CVR Nitrogen. For a

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discussion of the East Dubuque Merger, refer to Note 4 ("East Dubuque Merger") of Part I, Item 1 of this Report. The consolidated financial statements and key operating metrics include the results of the East Dubuque Facility beginning on April 1, 2016, the date of the closing of the acquisition.

Our Coffeyville Facility includes a 1,300 ton-per-day capacity ammonia unit, a 3,000 ton-per-day capacity UAN unit, and a gasifier complex having a capacity of 89 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. Strategically located adjacent to CVR Refining’s refinery in Coffeyville, Kansas, our Coffeyville Facility is the only operation in North America that utilizes a petroleum coke, or pet coke, gasification process to produce nitrogen fertilizer. During the past five years, over 70% of the pet coke consumed by our Coffeyville Facility was produced and supplied by CVR Refining’s Coffeyville, Kansas crude oil refinery. We upgrade substantially all of the ammonia we produce at our Coffeyville Facility to higher margin UAN, which has historically commanded a premium price over ammonia. Approximately 93% of our Coffeyville Facility produced ammonia tons were upgraded into UAN in 2016. For the three months ended September 30, 2017 and 2016, approximately 95% and 96%, respectively, of our Coffeyville Facility produced ammonia tons were upgraded into UAN. For the nine months ended September 30, 2017 and 2016, approximately 88% and 92%, respectively, of our Coffeyville Facility produced ammonia tons were upgraded into UAN.

Our East Dubuque Facility includes a 1,075 ton-per-day capacity ammonia unit and a 1,100 ton-per-day capacity UAN unit. The facility is located on a 210-acre, 140-foot bluff above the Mississippi River, with access to the river for loading certain products. The East Dubuque Facility uses natural gas as its primary feedstock. The East Dubuque Facility has the flexibility to significantly vary its product mix. This enables us to upgrade our ammonia production into varying amounts of UAN, nitric acid and liquid and granulated urea each season, depending on market demand, pricing and storage availability. Product sales are heavily weighted toward sales of ammonia and UAN. For the post-acquisition period ended December 31, 2016, approximately 44% of our East Dubuque Facility produced ammonia tons were upgraded to other products. For the three months ended September 30, 2017 and 2016, approximately 44% and 41%, respectively, of our East Dubuque Facility produced ammonia tons were upgraded to other products. For the nine months ended September 30, 2017, approximately 44% of our East Dubuque Facility produced ammonia tons were upgraded to other products.

CVR Energy, which indirectly owns our general partner and approximately 34% of our outstanding common units, also indirectly owns the general partner and approximately 66% of the outstanding common units of CVR Refining at September 30, 2017. CVR Refining's subsidiaries own and operate a complex full coking medium-sour crude oil refinery with a rated capacity of 115,000 barrels per calendar day (bpcd) in Coffeyville, Kansas, a complex crude oil refinery with a rated capacity of 70,000 bpcd in Wynnewood, Oklahoma and ancillary businesses.

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 operating costs and expenses.

The price at which our products are ultimately sold depends on numerous factors, including the global supply and demand for nitrogen fertilizer products which, in turn, depends on, among other factors, world grain demand and production levels, changes in world population, the cost and availability of fertilizer transportation infrastructure, weather conditions, the availability of imports and the extent of government intervention in agriculture markets.

Nitrogen fertilizer prices are also affected by local factors, including local market conditions and the operating levels of competing facilities. An expansion or upgrade of competitors' facilities, new facility development, 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.

We have the capacity to store approximately 160,000 tons of UAN and 80,000 tons of ammonia. Our storage tanks are located primarily at our two production facilities. Inventories are often allowed to accumulate to allow customers to take delivery to meet the seasonal demand.

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

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the customer's designated delivery site ("sold delivered"). The relative percentage of sold gate versus sold delivered can change period to period. The product pricing at gate provides a measure that is consistently comparable period to period.

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. Our products leave our Coffeyville Facility either in railcars for destinations located principally on the Union Pacific Railroad or in trucks for direct shipment to customers. We do not currently incur significant intermediate transfer, storage, barge freight or pipeline freight charges; however, we do incur costs to maintain and repair our railcar fleet. Selling products to customers within economic rail transportation limits of the Coffeyville Facility and keeping transportation costs low are keys to maintaining profitability.

The East Dubuque Facility is located in northwest Illinois, in the corn belt. The East Dubuque Facility primarily sells its product to customers located within 200 miles of the facility. In most instances, customers take delivery of nitrogen products at the plant and arrange and pay to transport them to their final destinations by truck. The East Dubuque Facility has direct access to a barge dock on the Mississippi River as well as a nearby rail spur serviced by the Canadian National Railway Company.

The high fixed cost of the Coffeyville Facility direct operating expense structure also directly affects our profitability. Our Coffeyville Facility's pet coke gasification process results in a significantly higher percentage of fixed costs than a natural gas-based fertilizer plant, such as our East Dubuque Facility. Major fixed operating expenses include a large portion of electrical energy, employee labor, and maintenance, including contract labor and outside services.

Our largest raw material expense used in the production of ammonia at our Coffeyville Facility is pet coke, which we purchase from CVR Refining and third parties. For the three months ended September 30, 2017 and 2016, we incurred approximately $2.0 million and $1.7 million, respectively, for the cost of pet coke, which equaled an average cost per ton of $18 and $13, respectively. For the nine months ended September 30, 2017 and 2016, we incurred approximately $6.5 million and $5.4 million, respectively, for the cost of pet coke, which equaled an average cost per ton of $18 and $14, respectively.

Our largest raw material expense used in the production of ammonia at our East Dubuque Facility is natural gas, which we purchase from third parties. Our East Dubuque Facility's natural gas process results in a higher percentage of variable costs as compared to the Coffeyville Facility. For the three months ended September 30, 2017 and 2016, we expensed approximately $6.1 million and $4.9 million, respectively, for feedstock natural gas, which equaled an average cost per MMBtu of $3.15 and $2.92, respectively. For the nine months ended September 30, 2017, we expensed approximately $19.5 million for feedstock natural gas, which equaled an average cost per MMBtu of $3.30.

Consistent, safe and reliable operations at our nitrogen fertilizer plants are critical to our financial performance and results of operations. Unplanned downtime 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 Coffeyville Facility has undergone a full facility turnaround approximately every two to three years. The Coffeyville Facility underwent a full facility turnaround in the third quarter of 2015, at a cost of approximately $7.0 million, exclusive of the impacts due to the lost production during the downtime. The Coffeyville Facility is planning to undergo the next scheduled full facility turnaround in 2018.

Historically, the East Dubuque Facility has also undergone a full facility turnaround approximately every two to three years. The East Dubuque Facility underwent a full facility turnaround in the second quarter of 2016, at a cost of approximately $6.6 million, exclusive of the impacts due to the lost production during the downtime. We determined that there were more pressing preventative maintenance issues at the East Dubuque Facility, so we completed a scheduled turnaround at the East Dubuque Facility in the third quarter of 2017 at a cost of approximately $2.6 million, exclusive of the impacts of the lost production during the downtime.

Production levels in the third quarter of 2017 were negatively impacted by the planned 14-day turnaround at our East Dubuque Facility. Production levels in the third quarter of 2017 were also impacted an additional eight days of unplanned downtime due to an exchanger outage at the East Dubuque Facility that resulted in repair costs which were not material. Subsequent to the third quarter of 2017, the East Dubuque Facility experienced an additional outage caused by refractory failing in piping.  As of the date of this filing, the piping repair work is ongoing and the total outage is expected to last 12 days and the repair cost is estimated to be immaterial.

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Agreements with CVR Energy and CVR Refining

We are party to several agreements with CVR Energy and its affiliates that govern the business relations among us, CVR Energy and its subsidiaries (including CVR Refining), and our general partner. These include the pet coke supply agreement under which we buy the pet coke we use in our Coffeyville Facility; a services agreement, under which CVR Energy and its subsidiaries provide us with management services including the services of its senior management team; a feedstock and shared services agreement, which governs the provision of feedstocks for our Coffeyville Facility, including, but not limited to, high-pressure steam, nitrogen, instrument air, oxygen and natural gas; a hydrogen purchase and sale agreement, which governs the purchase of hydrogen for our Coffeyville Facility; a raw water and facilities sharing agreement, which allocates raw water resources between the two facilities in Coffeyville; an easement agreement; an environmental agreement; a lease agreement pursuant to which we lease office space and laboratory space; and certain financing agreements that we entered into in connection with the East Dubuque Merger. These agreements were not the result of arm's-length negotiations and the terms of these agreements are not necessarily as favorable to the parties to these agreements as terms which could have been obtained from unaffiliated third parties. See Note 14 ("Related Party Transactions") to Part I, Item 1 of this Report for additional discussion of the agreements.

Factors Affecting Comparability of Our Financial Results

Our historical results of operations for the periods presented may not be comparable with prior periods or to our results of operations in the future for the reason discussed below.

East Dubuque Merger

On April 1, 2016, the Partnership completed the East Dubuque Merger, whereby the Partnership acquired the East Dubuque Facility. The consolidated financial statements and key operating metrics include the results of the East Dubuque Facility beginning on April 1, 2016, the date of the closing of the acquisition. During the three and nine months ended September 30, 2016, the Partnership incurred $0.7 million and $3.1 million, respectively, of legal and other professional fees and other merger-related expenses, which were included in selling, general and administrative expenses. See Note 4 ("East Dubuque Merger") to Part I, Item 1 of this Report for further discussion.

Major Scheduled Turnaround Activities

During the third quarter of 2017, the East Dubuque Facility completed a scheduled turnaround and the ammonia and UAN units were down for approximately 14 days. Overall results were negatively impacted due to the lost production during the downtime that resulted in lost sales and certain reduced variable expenses included in cost of materials and other and direct operating expenses (exclusive of depreciation and amortization). Exclusive of the impacts due to the lost production during the turnaround downtime, costs of approximately $2.5 million and $2.6 million, respectively, are included in direct operating expenses (exclusive of depreciation and amortization) in the Consolidated Statements of Operations for the three and nine months ended September 30, 2017.

During the second quarter of 2016, the East Dubuque Facility completed a major scheduled turnaround and the ammonia and UAN units were down for approximately 28 days. Overall results were negatively impacted due to the lost production during the downtime that resulted in lost sales and certain reduced variable expenses included in cost of materials and other and direct operating expenses (exclusive of depreciation and amortization). Exclusive of the impacts due to the lost production during the turnaround downtime, costs of approximately $6.6 million are included in direct operating expenses (exclusive of depreciation and amortization) in the Consolidated Statements of Operations for the nine months ended September 30, 2016.

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Indebtedness

On April 1, 2016, as a result of the East Dubuque Merger, the Partnership acquired CVR Nitrogen, including its debt. During the second quarter of 2016, the Partnership used $300.0 million of funds from the senior term loan credit facility with Coffeyville Resources, LLC, a related party, to finance the payoff of CVR Partners' $125.0 million term loan, payoff CVR Nitrogen's credit facility outstanding balance of $49.1 million, and to fund the cash merger consideration and certain merger-related expenses. In June 2016, the Partnership issued $645.0 million aggregate principal of 9.250% Senior Secured Notes due 2023 to refinance the substantial majority of its existing debt. Also as a result of the financing transactions, the Partnership recognized a loss on debt extinguishment of approximately $5.1 million during the nine months ended September 30, 2016. As a result of the financing transactions, the Partnership's interest expense increased for the nine months ended September 30, 2017 as compared to the prior year. Further discussion regarding the Partnership's indebtedness can be found in Note 12 ("Debt") to Part I, Item 1 of this Report.

Results of Operations

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

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

The following tables summarize the financial data and key operating statistics for CVR Partners and our subsidiaries for the three and nine months ended September 30, 2017 and 2016. The results of operations for our East Dubuque Facility are included for the post acquisition period beginning April 1, 2016. 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, 2016, is unaudited.

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	Three Months Ended   September 30,								Nine Months Ended   September 30,
	2017				2016				2017				2016
	(in millions)
Consolidated Statements of Operations Data:
Net sales	$	69.4			$	78.5			$	252.6			$	271.4
Cost of materials and other – Affiliates	1.8				0.6				5.6				1.9
Cost of materials and other – Third parties	17.6				19.3				57.7				70.3
	19.4				19.9				63.3				72.2
Direct operating expenses – Affiliates (1)	1.0				1.1				2.8				3.2
Direct operating expenses – Third parties (1)	36.8				31.4				108.6				100.6
Major scheduled turnaround expenses	2.5				—				2.6				6.6
	40.3				32.5				114.0				110.4
Depreciation and amortization	19.5				16.4				54.9				41.0
Cost of sales	79.2				68.8				232.2				223.6
Selling, general and administrative expenses – Affiliates (2)	3.9				3.6				11.4				10.9
Selling, general and administrative expenses – Third parties (2)	2.2				3.7				7.4				11.1
	6.1				7.3				18.8				22.0
Operating income (loss)	(15.9		)		2.4				1.6				25.8
Interest expense and other financing costs	(15.7		)		(15.6		)		(47.1		)		(32.8		)
Loss on extinguishment of debt	—				—				—				(5.1		)
Other income, net	—				—				0.1				—
Total other expense	(15.7		)		(15.6		)		(47.0		)		(37.9		)
Loss before income tax expense	(31.6		)		(13.2		)		(45.4		)		(12.1		)
Income tax expense	—				0.2				—				0.3
Net loss	$	(31.6	)		$	(13.4	)		$	(45.4	)		$	(12.4	)
EBITDA (3)*	$	3.6			$	18.8			$	56.6			$	61.7
Adjusted EBITDA (3)*	$	5.0			$	17.4			$	58.1			$	74.4
Available cash for distribution (4)*	$	(1.2	)		$	0.4			$	0.6			$	50.8
Reconciliation to net sales:
Fertilizer sales net at gate	$	59.4			$	66.7			$	223.0			$	234.8
Freight in revenue	8.3				8.8				23.6				24.4
Hydrogen revenue	—				1.2				0.1				2.9
Other, including the impact of purchase accounting	1.7				1.8				5.9				9.3
Total net sales	$	69.4			$	78.5			$	252.6			$	271.4

________________________________

* See footnote (3) and (4) below for discussion of non-GAAP financial measures.

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	As of   September 30,   2017				As of   December 31,   2016
					(audited)
	(in millions)
Balance Sheet Data:
Cash and cash equivalents	$	70.0			$	55.6
Working capital	73.3				71.5
Total assets	1,275.8				1,312.2
Total debt, net of current portion	625.2				623.1
Total partners’ capital	577.3				624.9

	Three Months Ended   September 30,								Nine Months Ended   September 30,
	2017				2016				2017				2016
	(in millions)
Cash Flow Data:
Net cash flow provided by (used in):
Operating activities	$	21.1			$	18.4			$	28.1			$	47.5
Investing activities	(2.8		)		(6.4		)		(11.4		)		(82.1		)
Financing activities	—				(23.0		)		(2.3		)		49.9
Net increase (decrease) in cash and cash equivalents	$	18.3			$	(11.0	)		$	14.4			$	15.3
Capital expenditures:
Maintenance capital expenditures	$	2.7			$	3.4			$	11.1			$	8.3
Growth capital expenditures	0.1				3.0				0.3				10.0
Total capital expenditures	$	2.8			$	6.4			$	11.4			$	18.3

______________________________

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

(2)	The Partnership incurred approximately $0.7 million and $3.1 million, respectively, of legal and other professional fees and other merger-related expenses for the three and nine months ended September 30, 2016, as discussed in Note 4 ("East Dubuque Merger") to Part I, Item 1 of this Report, which are included in selling, general and administrative expenses.

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

Adjusted EBITDA is defined as EBITDA further adjusted for the impact of major scheduled turnaround expenses, gain or loss on extinguishment of debt, loss on disposition of assets, expenses associated with the East Dubuque Merger and business interruption insurance recovery, when applicable.

We present EBITDA because we believe it allows users of our financial statements, such as investors and analysts, to assess our financial performance without regard to financing methods, capital structure or historical cost basis. We present Adjusted EBITDA because we have found it helpful to consider an operating measure that excludes amounts, such as major scheduled turnaround expenses, gain or loss on extinguishment of debt, loss on disposition of assets, expenses associated with the East Dubuque Merger and business interruption insurance recovery, relating to transactions not reflective of our core operations. When applicable, each of these amounts is discussed herein, so that investors have complete information about these amounts. We also present Adjusted EBITDA because it is the starting point used by the board of directors of our general partner when calculating our available cash for distribution.

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

A reconciliation of consolidated Net loss to consolidated EBITDA and consolidated Adjusted EBITDA is as follows:

	Three Months Ended   September 30,								Nine Months Ended   September 30,
	2017				2016				2017				2016
	(in millions)
Net loss	$	(31.6	)		$	(13.4	)		$	(45.4	)		$	(12.4	)
Add:
Interest expense and other financing costs, net	15.7				15.6				47.1				32.8
Income tax expense	—				0.2				—				0.3
Depreciation and amortization	19.5				16.4				54.9				41.0
EBITDA	$	3.6			$	18.8			$	56.6			$	61.7
Add:
Major scheduled turnaround expenses	2.5				—				2.6				6.6
Loss on extinguishment of debt	—				—				—				5.1
Expenses associated with the East Dubuque Merger	—				0.7				—				3.1
Less:
Insurance recovery - business interruption	(1.1		)		(2.1		)		(1.1		)		(2.1		)
Adjusted EBITDA	$	5.0			$	17.4			$	58.1			$	74.4

(4)

The board of directors of our general partner has a policy to calculate available cash for distribution starting with Adjusted EBITDA. For the three and nine months ended September 30, 2017 and 2016, available cash for distribution equaled our Adjusted EBITDA reduced for cash needed for (i) net cash interest expense (excluding capitalized interest) and debt service and other contractual obligations; (ii) maintenance capital expenditures; and (iii) to the extent applicable, major scheduled turnaround expenses, reserves for future operating or capital needs that the board of directors of the general partner deems necessary or appropriate, and expenses associated with the East Dubuque Merger, 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, and available cash is increased by the business interruption insurance proceeds and the impact of purchase accounting. Actual distributions are set by the board of directors of our general partner. The board of directors of our general partner may modify our cash distribution policy at any time, and our partnership agreement does not require us to make distributions at all.

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

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

	Three Months Ended   September 30,								Nine Months Ended   September 30,
	2017				2016				2017				2016
	(in millions, except units and per unit data)
Adjusted EBITDA	$	5.0			$	17.4			$	58.1			$	74.4
Adjustments:
Less:
Net cash interest expense (excluding capitalized interest) and debt service	(15.0		)		(15.0		)		(44.9		)		(31.0		)
Maintenance capital expenditures	(2.7		)		(3.4		)		(11.1		)		(8.3		)
Major scheduled turnaround expenses	(2.5		)		—				(2.6		)		(6.6		)
Expenses associated with the East Dubuque Merger	—				(0.7		)		—				(3.1		)
Add:
Insurance recovery - business interruption	1.1				2.1				1.1				6.1
Impact of purchase accounting	—				—				—				13.0
Available cash associated with East Dubuque 2016 first quarter	—				—				—				6.3
Release of previously established cash reserves, net	12.9				—				—				—
Available cash for distribution	$	(1.2	)		$	0.4			$	0.6			$	50.8
Available cash for distribution, per common unit	$	(0.01	)		$	—			$	—			$	0.45
Distribution declared, per common unit	$	—			$	—			$	0.02			$	0.44
Common units outstanding (in thousands)	113,283				113,283				113,283				113,283

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

	Three Months Ended   September 30,								Nine Months Ended   September 30,
	2017				2016				2017				2016
Key Operating Statistics:
Consolidated sales (thousand tons):
Ammonia	65.3				47.7				201.8				145.7
UAN	299.1				296.0				951.6				902.4
Consolidated product pricing at gate (dollars per ton) (1):
Ammonia	$	214			$	345			$	287			$	385
UAN	$	138			$	154			$	158			$	187
Consolidated production volume (thousand tons):
Ammonia (gross produced) (2)	180.7				200.8				615.2				485.9
Ammonia (net available for sale) (2)	46.2				60.3				203.7				121.0
UAN	306.6				317.2				962.3				861.9
Feedstock:
Petroleum coke used in production (thousand tons)	114.3				126.8				371.0				384.4
Petroleum coke used in production (dollars per ton)	$	18			$	13			$	18			$	14
Natural gas used in production (thousands of MMBtu)	1,555.4				2,075.5				5,780.7				3,471.6
Natural gas used in production (dollars per MMBtu) (3)	$	3.12			$	2.97			$	3.25			$	2.75
Natural gas in cost of materials and other (thousands of MMBtu)	1,934.9				1,679.5				5,898.3				2,742.5
Natural gas in cost of materials and other (dollars per MMBtu) (3)	$	3.15			$	2.92			$	3.30			$	2.68
Coffeyville Facility on-stream factors (4):
Gasification	96.3		%		95.9		%		98.0		%		97.2		%
Ammonia	93.5		%		94.7		%		96.7		%		96.2		%
UAN	93.9		%		94.1		%		92.6		%		93.1		%
East Dubuque Facility on-stream factors (4):
Ammonia	76.3		%		94.4		%		91.9		%		81.7		%
UAN	77.1		%		92.9		%		91.5		%		81.1		%
Market Indicators:
Ammonia - Southern plains (dollars per ton)	$	238			$	315			$	314			$	368
Ammonia - Corn belt (dollars per ton)	$	303			$	372			$	364			$	432
UAN - Corn belt (dollars per ton)	$	165			$	188			$	192			$	218
Natural gas NYMEX (dollars per MMBtu)	$	2.95			$	2.79			$	3.05			$	2.35

______________________________

(1)	Product pricing at gate represents net sales less freight revenue divided by product sales volume in tons and is shown in order to provide a pricing measure that is comparable across the fertilizer industry.

(2)	Gross tons produced for ammonia represent total ammonia produced, including ammonia produced that was upgraded into other fertilizer products. Net tons available for sale represent ammonia available for sale that was not upgraded into other fertilizer products.

 

(3)	The cost per MMBtu excludes derivative activity, when applicable. The impact of natural gas derivative activity during the periods presented was not material.

(4)	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.

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Coffeyville Facility

The Linde air separation unit experienced a shut down during the second quarter of 2017. Following the Linde outage, the Coffeyville Facility UAN unit experienced a number of operational challenges, resulting in approximately 11 days of UAN downtime during the second quarter of 2017. Excluding the impact of the Linde air separation unit outage at the Coffeyville Facility, the UAN unit on-stream factors at the Coffeyville Facility would have been 96.7% for the nine months ended September 30, 2017.

East Dubuque Facility

Excluding the impact of approximately 14 days of downtime associated with the 2017 full facility turnaround at the East Dubuque Facility, the on-stream factors at the East Dubuque Facility would have been 91.3% for ammonia and 91.8% for UAN for the three months ended September 30, 2017 and 96.9% for ammonia and 96.4% for UAN for the nine months ended September 30, 2017.

Excluding the impact of approximately 28 days of downtime associated with the 2016 full facility turnaround at the East Dubuque Facility, the on-stream factors at the East Dubuque Facility would have been 97.2% for ammonia and 96.2% for UAN for the six months ended September 30, 2016.

Three Months Ended September 30, 2017 Compared to the Three Months Ended September 30, 2016

Net Sales. Net sales were $69.4 million for the three months ended September 30, 2017 compared to $78.5 million for the three months ended September 30, 2016. The decrease of $9.1 million for the three months ended September 30, 2017 compared to the three months ended September 30, 2016 was primarily attributable to the lower ammonia sales prices ($8.4 million), lower UAN sales prices ($5.7 million), partially offset by higher ammonia sales volumes ($6.2 million). For the three months ended September 30, 2017, UAN and ammonia made up $48.8 million and $14.9 million of our consolidated net sales, respectively, including freight. This compared to UAN and ammonia consolidated net sales of $53.9 million and $17.1 million, respectively, for the three months ended September 30, 2016, including freight.

The following table demonstrates the impact of changes in sales volumes and pricing for the primary components of net sales for the three months ended September 30, 2017 as compared to the three months ended September 30, 2016:

	Price  Variance				Volume  Variance
	(in millions)
UAN	$	(5.7	)		$	0.6
Ammonia	$	(8.4	)		$	6.2

The decrease in UAN and ammonia sales prices for the three months ended September 30, 2017 compared to the three months ended September 30, 2016 was primarily attributable to pricing fluctuation in the market.

Cost of Materials and Other. Cost of materials and other consists primarily of freight and distribution expenses, feedstock expenses, purchased ammonia and purchased hydrogen. Cost of materials and other for the three months ended September 30, 2017 was $19.4 million, compared to $19.9 million for the three months ended September 30, 2016. The $0.5 million decrease was primarily due to lower costs from transactions with third parties of $1.7 million, partially offset by an increase in transactions with affiliates of $1.2 million. The lower third-party costs incurred were primarily the result of decreased distribution costs due to the timing of regulatory railcar repairs and maintenance. The higher affiliate costs incurred were primarily the result of increased hydrogen purchases from a subsidiary of CVR Refining.

Direct Operating Expenses (Exclusive of Depreciation and Amortization). Direct operating expenses consist primarily of energy and utility costs, direct costs of labor, property taxes, plant-related maintenance services and environmental and safety compliance costs as well as catalyst and chemical costs. Direct operating expenses (exclusive of depreciation and amortization) for the three months ended September 30, 2017 were $40.3 million as compared to $32.5 million for the three months ended September 30, 2016. The $7.8 million increase was primarily due to the third quarter 2017 turnaround at East Dubuque, which resulted in turnaround expenses of $2.5 million. The remaining increase was primarily due to having to expense fixed operating costs while idle as well as higher sales tons in the three months ended September 30, 2017 as compared to 2016, resulting in higher cost of inventory expensed during 2017.

Selling, General and Administrative Expenses. 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 its subsidiaries,

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on our behalf and billed or allocated to us in accordance with the applicable agreements. We also reimburse our general partner in accordance with the partnership agreement for expenses it incurs on our behalf. Reimbursed expenses to our general partner are included as selling, general and administrative expenses from affiliates. Selling, general and administrative expenses were $6.1 million for the three months ended September 30, 2017 and $7.3 million for the three months ended September 30, 2016. The $1.2 million decrease was primarily due to decreases in expenses associated with the East Dubuque Merger ($0.7 million).

Operating Income (Loss). Operating loss was $15.9 million for the three months ended September 30, 2017, as compared to operating income of $2.4 million for the three months ended September 30, 2016. The decrease of $18.3 million was the result of a decrease in net sales ($9.1 million), an increase in direct operating expenses ($7.8 million), an increase in depreciation and amortization ($3.1 million), partially offset by a decrease in cost of materials and other ($0.5 million) and a decrease in selling, general and administrative expenses ($1.2 million).

Net Loss. For the three months ended September 30, 2017, net loss was $31.6 million, as compared to $13.4 million of net loss for the three months ended September 30, 2016, an increase in net loss of $18.2 million. The increase in net loss was primarily due to the factors noted above.

Nine months ended September 30, 2017 Compared to the Nine months ended September 30, 2016

The nine months ended September 30, 2017 is not comparable to the nine months ended September 30, 2016 due to the acquisition of the East Dubuque Facility on April 1, 2016. Where appropriate, the East Dubuque Facility has been excluded from comparative discussions.

Net Sales. Consolidated net sales were $252.6 million for the nine months ended September 30, 2017 compared to $271.4 million for the nine months ended September 30, 2016.

Excluding the East Dubuque Facility, net sales were $150.1 million for the nine months ended September 30, 2017 compared to $179.0 million for the nine months ended September 30, 2016. The decrease of $28.9 million was primarily attributable to the lower UAN sales prices ($22.4 million), lower ammonia sales prices ($3.7 million) and lower UAN sales volumes ($3.6 million), partially offset by higher ammonia sales volumes ($3.6 million) at the Coffeyville Facility. For the nine months ended September 30, 2017, UAN and ammonia made up $131.8 million and $13.4 million of our net sales, respectively, including freight. This compared to UAN and ammonia net sales of $157.8 million and $13.5 million, respectively, for the nine months ended September 30, 2016, including freight.

The following table demonstrates the impact of changes in sales volumes and pricing for the primary components of net sales at the Coffeyville Facility for the nine months ended September 30, 2017 as compared to the nine months ended September 30, 2016:

	Price  Variance				Volume  Variance
	(in millions)
UAN	$	(22.4	)		$	(3.6	)
Ammonia	$	(3.7	)		$	3.6

The decrease in UAN and ammonia sales prices at the Coffeyville Facility for the nine months ended September 30, 2017 compared to the nine months ended September 30, 2016 was primarily attributable to pricing fluctuation in the market.

Cost of Materials and Other. Cost of materials and other consists primarily of freight and distribution expenses, feedstock expenses, purchased ammonia and purchased hydrogen. Consolidated cost of materials and other was $63.3 million for the nine months ended September 30, 2017 compared to $72.2 million for the nine months ended September 30, 2016.

Excluding the East Dubuque Facility, cost of materials and other was $41.3 million for the nine months ended September 30, 2017 compared to $42.3 million for the nine months ended September 30, 2016. The decrease of $1.0 million was attributable to lower costs from transactions with third parties of $4.7 million, partially offset by higher transactions with affiliates of $3.7 million. The decrease in transactions with third parties was primarily the result of decreased distribution costs due to the timing of regulatory railcar repairs and maintenance ($2.7 million) and lower freight expense ($1.3 million). The increase in transactions with affiliates was primarily the result of increased hydrogen purchases from a subsidiary of CVR Refining ($3.0 million).

Direct Operating Expenses (Exclusive of Depreciation and Amortization). Direct operating expenses consist primarily of energy and utility costs, direct costs of labor, property taxes, plant-related maintenance services and environmental and safety

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compliance costs as well as catalyst and chemical costs. Consolidated direct operating expenses were $114.0 million for the nine months ended September 30, 2017 compared to $110.4 million for the nine months ended September 30, 2016.

Excluding the East Dubuque Facility, direct operating expenses were $69.1 million for the nine months ended September 30, 2017 compared to $68.6 million for the nine months ended September 30, 2016. The increase of $0.5 million was attributable to higher costs from transactions with third parties of $1.5 million, partially offset by a decrease in transactions with affiliates of $1.0 million. The increase in transactions with third parties was primarily the result of increased electrical prices ($3.6 million), partially offset by lower repairs and maintenance ($2.3 million).

Depreciation and Amortization Expense. Consolidated depreciation expense was $54.9 million for the nine months ended September 30, 2017 compared to $41.0 million for the nine months ended September 30, 2016.

Excluding the East Dubuque Facility, depreciation expense was $21.0 million for both the nine months ended September 30, 2017 and 2016.

Selling, General and Administrative Expenses. 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 its subsidiaries, on our behalf and billed or allocated to us in accordance with the applicable agreements. We also reimburse our general partner in accordance with the partnership agreement for expenses it incurs on our behalf. Reimbursed expenses to our general partner are included as selling, general and administrative expenses from affiliates. Consolidated selling, general and administrative expenses were $18.8 million for the nine months ended September 30, 2017 compared to $22.0 million for the nine months ended September 30, 2016.

Excluding the East Dubuque Facility, selling, general and administrative expenses were $14.5 million for the nine months ended September 30, 2017 compared to $17.4 million for the nine months ended September 30, 2016. The decrease of $2.9 million was primarily attributable to a decrease in expenses associated with the East Dubuque Merger ($3.1 million).

Interest Expense and Other Financing Costs. Consolidated interest expense was $47.1 million for the nine months ended September 30, 2017, as compared to $32.8 million for the nine months ended September 30, 2016. The increase of $14.3 million was primarily due to lower outstanding debt in the first quarter of 2016. See Note 12 ("Debt") to Part I, Item 1 of this Report for a discussion of the financing transactions that occurred in the second quarter of 2016.

Liquidity and Capital Resources

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

We believe that our cash from operations and existing cash and cash equivalents, along with borrowings, as necessary, under the ABL Credit Facility will be sufficient to satisfy anticipated cash commitments associated with our existing operations for at least the next 12 months. However, our future capital expenditures and other cash requirements could be higher than we currently expect as a result of various factors. Additionally, our ability to generate sufficient cash from our operating activities and secure additional financing depends on our future performance, which is subject to general economic, political, financial, competitive and other factors outside of our control.

Depending on the needs of our business, contractual limitations and market conditions, we may from time to time seek to issue equity securities, incur additional debt, issue debt securities, or otherwise refinance our existing debt. There can be no assurance that we will seek to do any of the foregoing or that we will be able to do any of the foregoing on terms acceptable to us or at all.

Cash Balance and Other Liquidity

As of September 30, 2017, we had cash and cash equivalents of $70.0 million, including $19.4 million of customer advances. Working capital at September 30, 2017 was $73.3 million, consisting of $145.0 million in current assets and approximately $71.7 million in current liabilities. Working capital at December 31, 2016 was $71.5 million, consisting of $134.5 million in current assets and $63.0 million in current liabilities. As of October 30, 2017, we had cash and cash equivalents of $74.9 million.

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2023 Notes

On June 10, 2016, the Partnership and CVR Nitrogen Finance Corporation issued $645.0 million aggregate principal amount of 9.250% Senior Secured Notes due 2023. The 2023 Notes were issued at a $16.1 million discount, which is being amortized over the term of the 2023 Notes as interest expense using the effective-interest method. As a result of the issuance, approximately $9.4 million of debt issuance costs were incurred, which are being amortized over the term of the 2023 Notes as interest expense using the effective-interest method.

The 2023 Notes are guaranteed on a senior secured basis by all of the Partnership’s existing subsidiaries.

At any time prior to June 15, 2019, we may on any of one or more occasions redeem up to 35% of the aggregate principal amount of the 2023 Notes issued under the indenture governing the 2023 Notes in an amount not greater than the net proceeds of one or more public equity offerings at a redemption price of 109.250% of the principal amount of the 2023 Notes, plus any accrued and unpaid interest to the date of redemption. Prior to June 15, 2019, we may on any one or more occasions redeem all or part of the 2023 Notes at a redemption price equal to the sum of: (i) the principal amount thereof, plus (ii) the Make Whole Premium, as defined in the indenture governing the 2023 Notes, at the redemption date, plus any accrued and unpaid interest to the applicable redemption date.

On and after June 15, 2019, we may on any one or more occasions redeem all or a part of the 2023 Notes at the redemption prices (expressed as percentages of principal amount) set forth below, plus any accrued and unpaid interest to the applicable redemption date on such Notes, if redeemed during the 12-month period beginning on June 15 of the years indicated below:

Year		Percentage
2019		104.625%
2020		102.313%
2021 and thereafter		100.000%

Upon the occurrence of certain change of control events as defined in the indenture (including the sale of all or substantially all of the properties or assets of the Partnership and its subsidiaries, taken as a whole), each holder of the 2023 Notes will have the right to require that the Partnership repurchase all or a portion of such holder’s 2023 Notes in cash at a purchase price equal to 101% of the aggregate principal amount thereof plus any accrued and unpaid interest to the date of repurchase.

The 2023 Notes contain customary covenants for a financing of this type that, among other things, restrict the Partnership’s ability and the ability of certain of its subsidiaries to: (i) sell assets; (ii) pay distributions on, redeem or repurchase the Partnership’s units or redeem or repurchase its subordinated debt; (iii) make investments; (iv) incur or guarantee additional indebtedness or issue preferred units; (v) create or incur certain liens; (vi) enter into agreements that restrict distributions or other payments from the Partnership’s restricted subsidiaries to the Partnership; (vii) consolidate, merge or transfer all or substantially all of the Partnership’s assets; (viii) engage in transactions with affiliates; and (ix) create unrestricted subsidiaries.  Most of the foregoing covenants would cease to apply at such time that the 2023 Notes are rated investment grade by both Standard & Poor's Ratings Services and Moody's Investors Service, Inc. However, such covenants would be reinstituted if the 2023 Notes subsequently lost their investment grade rating. In addition, the indenture contains customary events of default, the occurrence of which would result in, or permit the trustee or the holders of at least 25% of the 2023 Notes to cause, the acceleration of the 2023 Notes, in addition to the pursuit of other available remedies.

The indenture governing the 2023 Notes prohibits us from making distributions to unitholders if any default or event of default (as defined in the indenture) exists. In addition, the indenture limits our ability to pay distributions to unitholders. The covenants will apply differently depending on our fixed charge coverage ratio (as defined in the indenture). If the fixed charge coverage ratio is not less than 1.75 to 1.0, we will generally be permitted to make restricted payments, including distributions to our unitholders, without substantive restriction. If the fixed charge coverage ratio is less than 1.75 to 1.0, we will generally be permitted to make restricted payments, including distributions to our unitholders, up to an aggregate $75.0 million basket plus certain other amounts referred to as "incremental funds" under the indenture. As of September 30, 2017, the ratio was less than 1.75 to 1.0. Restricted payments have been made, and $72.7 million of the basket was available as of September 30, 2017. As of September 30, 2017, we were in compliance with the covenants contained in the 2023 Notes.

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Asset Based (ABL) Credit Facility

On September 30, 2016, the Partnership entered into the ABL Credit Facility with a group of lenders and UBS AG, Stamford Branch, as administrative agent and collateral agent. The ABL Credit Facility is a senior secured asset based revolving credit facility in an aggregate principal amount of availability of up to $50.0 million with an incremental facility, which permits an increase in borrowings of up to $25.0 million in the aggregate subject to additional lender commitments and certain other conditions. The proceeds of the loans may be used for capital expenditures and working capital and general corporate purposes of the Partnership and its subsidiaries. The ABL Credit Facility provides for loans and standby letters of credit in an amount up to the aggregate availability under the facility, subject to meeting certain borrowing base conditions, with sub-limits of the lesser of 10% of the total facility commitment and $5.0 million for swingline loans and $10.0 million for letters of credit. The ABL Credit Facility has a five-year maturity and will be used for working capital and other general corporate purposes.

At the option of the borrowers, loans under the ABL Credit Facility initially bear interest at an annual rate equal to (i) 2.00% plus LIBOR or (ii) 1.00% plus a base rate, subject to a 0.50% step-down based on the previous quarter’s excess availability.

The Partnership must also pay a commitment fee on the unutilized commitments to the lenders under the ABL Credit Facility equal to (a) 0.375% per annum for the first full calendar quarter after the closing date and (b) thereafter, (i) 0.375% per annum if utilization under the facility is less than 50% of the total commitments and (ii) 0.25% per annum if utilization under the facility is equal to or greater than 50% of the total commitments. The borrowers must also pay customary letter of credit fees equal to 2.00%, subject to a 0.50% step-down based on the previous quarter’s excess availability, on the maximum amount available to be drawn under, and customary facing fees equal to 0.125% of the face amount of, each letter of credit.

The ABL Credit Facility also contains customary covenants for a financing of this type that limit the ability of the Partnership to, among other things, incur liens, engage in a consolidation, merger, purchase or sale of assets, pay dividends, incur indebtedness, make advances, investments and loans, enter into affiliate transactions, issue equity interests, or create subsidiaries and unrestricted subsidiaries. The ABL Credit Facility also contains a fixed charge coverage ratio financial covenant, as defined therein. The Partnership was in compliance with the covenants of the ABL Credit Facility as of September 30, 2017.

As of September 30, 2017, the Partnership and its subsidiaries had availability under the ABL Credit Facility of $47.6 million. There were no borrowings outstanding under the ABL Credit Facility as of September 30, 2017.

Capital Spending

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. Major scheduled turnaround expenses are expensed when incurred. Our total capital expenditures for the nine months ended September 30, 2017 were approximately $11.4 million, including $11.1 million of maintenance capital spending and the remainder for growth capital projects.

Capital spending for our business has been and will be determined by the Board of Directors of our general partner. Our estimated maintenance capital expenditures are expected to be approximately $15 million for the year ending December 31, 2017. Our estimated capital expenditures are subject to change due to unanticipated changes in the cost, scope and completion time for our capital projects. For example, we may experience increases/decreases in labor or equipment costs necessary to comply with government regulations or to complete projects that sustain or improve the profitability of our facilities.

Major Scheduled Turnaround Expenditures

Consistent, safe and reliable operations are critical to our financial performance and results of operations. Unplanned downtime of either 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 Coffeyville Facility has undergone a full facility turnaround every two to three years. The Coffeyville Facility underwent a full facility turnaround in the third quarter of 2015, at a cost of approximately $7.0 million, exclusive of the impacts due to the lost production during the downtime. The Partnership is planning to undergo the next scheduled full facility turnaround at the Coffeyville Facility in 2018.

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Historically, the East Dubuque Facility has also undergone a full facility turnaround every two to three years. The East Dubuque Facility underwent a full facility turnaround in the second quarter of 2016, at a cost of approximately $6.6 million, exclusive of the impacts due to the lost production during the downtime. We determined that there were more pressing preventative maintenance issues at the East Dubuque Facility, so we completed a scheduled turnaround at the East Dubuque Facility in the third quarter of 2017 at a cost of approximately $2.6 million, exclusive of the impacts of the lost production during the downtime.

Distributions to Unitholders

The board of directors of the Partnership's general partner has a policy for the Partnership to distribute all available cash generated on a quarterly basis. See Note 8 ("Partners’ Capital and Partnership Distributions") to Part I, Item 1 of this Report for information on our distribution policy. The following is a summary of cash distributions paid to the Partnership's unitholders during 2017 for the respective quarters to which the distributions relate:

	December 31, 2016				March 31, 2017				June 30, 2017				Total Cash Distributions Paid in 2017
	($ in millions, except per common unit amounts)
Amount paid to CRLLC	$	—			$	0.8			$	—			$	0.8
Amount paid to public unitholders	—				1.5				—				1.5
Total amount paid	$	—			$	2.3			$	—			$	2.3
Per common unit	$	—			$	0.02			$	—			$	0.02
Common units outstanding (in thousands)	113,283				113,283				113,283

Cash Flows

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

	Nine Months Ended   September 30,
	2017				2016
	(in millions)
Net cash flow provided by (used in):
Operating activities	$	28.1			$	47.5
Investing activities	(11.4		)		(82.1		)
Financing activities	(2.3		)		49.9
Net increase in cash and cash equivalents	$	14.4			$	15.3

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 nine months ended September 30, 2017 were approximately $28.1 million. The positive cash flow from operating activities generated over this period was primarily driven by a net loss of $45.4 million offset by non-cash depreciation and amortization of $54.9 million, net cash inflows from other working capital of $17.1 million and net cash outflows from trade working capital of $2.8 million. The net cash inflow for other working capital was due to an increase to accrued expenses and other current liabilities of $8.0 million, an increase in deferred revenue of $7.4 million and a decrease to prepaid expenses and other current assets of $1.7 million. The increase in accrued expenses and other current liabilities is primarily a result of higher accrued interest of $14.9 million, partially offset by decreases in balances related to the timing of accrued railcar regulatory inspections of $2.4 million and timing of personnel expenses. The increase in deferred revenue was primarily due to collection of customer prepayments scheduled for deliveries during the three months ended December 31, 2017. The net cash outflow for trade working capital was due to a decrease in accounts payable of $4.6 million, partially offset by a decrease in accounts receivable of $1.6 million and an increase in inventory of $0.2 million. The decrease in accounts payable was primarily attributable to normal fluctuations in the timing of payments.

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Net cash flows provided by operating activities for the nine months ended September 30, 2016 were approximately $47.5 million. The positive cash flow from operating activities generated over this period was primarily driven by a net loss of $12.4 million offset by non-cash depreciation and amortization of $41.0 million and net cash inflows from trade working capital of $37.2 million, partially offset by net cash outflows from other working capital of $27.5 million. Fluctuations in trade working capital increased our operating cash flow by $37.2 million due to a decrease in inventory of $32.2 million, a decrease in accounts receivable of $3.4 million and an increase in accounts payable of $1.6 million. The decrease in inventory was primarily attributable to a decrease in finished goods inventory as a result of increased sales volumes for the nine months ended September 30, 2016. Fluctuations in other working capital of $27.5 million decreased our operating cash flow and were due to a decrease in deferred revenue of $27.7 million and a decrease to accrued expenses and other current liabilities of $4.0 million, partially offset by a decrease to prepaid expenses and other current assets of $4.2 million for the nine months ended September 30, 2016. The decrease in deferred revenue was primarily attributable to increased sales for the nine months ended September 30, 2016.

Cash Flows Used in Investing Activities

Net cash used in investing activities for the nine months ended September 30, 2017 was $11.4 million compared to $82.1 million for the nine months ended September 30, 2016. For the nine months ended September 30, 2017, net cash used in investing activities was the result of capital expenditures. For the nine months ended September 30, 2016, net cash used in investing activities was the result of cash merger consideration of $63.9 million, net of cash acquired, and was the result of capital expenditures of $18.3 million.

Cash Flows Used in Financing Activities

Cash flows used in financing activities for the nine months ended September 30, 2017 were $2.3 million, compared to net cash flows provided by financing activities for the nine months ended September 30, 2016 of $49.9 million. The net cash used in financing activities for the nine months ended September 30, 2017 was attributable to quarterly cash distributions. The net cash provided by financing activities for the nine months ended September 30, 2016 was primarily attributable to the financing transactions discussed in Note 12 ("Debt") to Part I, Item 1 of this Report, partially offset by the quarterly cash distributions and the purchase of 400,000 CVR Nitrogen common units from CVR Energy for $5.0 million.

Contractual Obligations

As of September 30, 2017, our contractual obligations included long-term debt, operating leases, unconditional purchase obligations, other specified capital and commercial commitments and interest payments. There were no material changes outside the ordinary course of our business with respect to our contractual obligations during the nine months ended September 30, 2017, from those disclosed in our 2016 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

Refer to Note 3 ("Recent Accounting Pronouncements") to Part I, Item 1 of this Report for a discussion of recent accounting pronouncements applicable to the Partnership.

Critical Accounting Policies and Estimates

Our critical accounting policies are disclosed in the "Critical Accounting Policies" section of our 2016 Form 10-K. No modifications have been made to our critical accounting policies. See Note 9 ("Goodwill") to Part I, Item 1 of this Report for a discussion of goodwill considerations.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk

Commodity Price, Foreign Currency Exchange and Non-Operating Risks

We are exposed to significant market risk due to potential changes in prices for fertilizer products and natural gas. Natural gas is the primary raw material used in the production of various nitrogen-based products manufactured at our East Dubuque Facility. We have commitments to purchase natural gas for use in our East Dubuque Facility on the spot market, and through short-term, fixed supply, fixed price and index price purchase contracts. Natural gas prices have fluctuated during the last several years, increasing substantially in 2008 and subsequently declining to the current lower pricing levels.

In the normal course of business, we produce nitrogen-based fertilizer products throughout the year to supply the needs of our customers during the high-delivery-volume spring and fall seasons. The value of fertilizer product inventory is subject to market risk due to fluctuations in the relevant commodity prices. Prices of nitrogen fertilizer products can be volatile. We believe that market prices of nitrogen products are affected by changes in grain prices and demand, natural gas prices and other factors. 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 sales transactions.

We do not currently use derivative financial instruments to manage risks related to changes in prices of commodities (e.g., UAN, ammonia, natural gas or pet coke), except as noted above. 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. Our management may, in the future, elect to use derivative financial instruments consistent with our overall business objectives to avoid unnecessary risk and to limit, to the extent practical, risks associated with our operating activities.

Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

As of September 30, 2017, we have evaluated, under the direction of our Executive Chairman, Chief Executive Officer and Chief Financial Officer, the effectiveness of our disclosure controls and procedures, as defined in Rule 13a-15(e) under the Securities Exchange Act of 1934, as amended (the "Exchange Act"). There are inherent limitations to the effectiveness of any system of disclosure controls and procedures, including the possibility of human error and the circumvention or overriding of the controls and procedures. Accordingly, even effective disclosure controls and procedures can only provide reasonable assurance of achieving their control objectives. Based upon and as of the date of that evaluation, our Executive Chairman, Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were effective to provide reasonable assurance that information required to be disclosed in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to the Partnership’s management, including our Executive Chairman, Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure. It should be noted that any system of disclosure controls and procedures, however well designed and operated, can provide only reasonable, and not absolute, assurance that the objectives of the system are met. In addition, the design of any system of disclosure controls and procedures is based in part upon assumptions about the likelihood of future events. Due to these and other inherent limitations of any such system, there can be no assurance that any design will always succeed in achieving its stated goals under all potential future conditions.

Changes in Internal Control Over Financial Reporting

There has been no material change in our internal control over financial reporting required by Rule 13a-15 of the Exchange Act that occurred during the fiscal quarter ended September 30, 2017 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

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Part II. Other Information

Item 1. Legal Proceedings

See Note 13 ("Commitments and Contingencies") to Part I, Item 1 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 2016 Form 10-K.

Item 6. Exhibits

EXHIBIT INDEX
Exhibit Number	Exhibit Description
31.1*	Rule 13a-14(a) or 15d-14(a) Certification of Executive Chairman.
31.2*	Rule 13a-14(a) or 15d-14(a) Certification of Chief Executive Officer and President.
31.3*	Rule 13a-14(a) or 15d-14(a) Certification of Chief Financial Officer and Treasurer.
32.1†	Section 1350 Certification of Executive Chairman.
32.2†	Section 1350 Certification of Chief Executive Officer and President.
32.3†	Section 1350 Certification of Chief Financial Officer and Treasurer.
101*	The following financial information for CVR Partners, LP’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2017, formatted in XBRL ("Extensible Business Reporting Language") includes: (1) Condensed Consolidated Balance Sheets (unaudited), (2) Condensed Consolidated Statements of Operations (unaudited), (3) Condensed Consolidated Statements of Comprehensive Income (Loss) (unaudited), (4) Condensed Consolidated Statement of Partners’ Capital (unaudited), (5) Condensed Consolidated Statements of Cash Flows (unaudited) and (6) the Notes to Condensed Consolidated Financial Statements (unaudited), tagged in detail.

*	Filed herewith.

†	Furnished 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, 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, its business or operations on the date hereof.

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

		CVR Partners, LP
		By:	CVR GP, LLC, its general partner
November 1, 2017		By:	/s/  JOHN J. LIPINSKI
			Executive Chairman
			(Principal Executive Officer)
November 1, 2017		By:	/s/  MARK A. PYTOSH
			Chief Executive Officer and President
			(Principal Executive Officer)
November 1, 2017		By:	/s/  SUSAN M. BALL
			Chief Financial Officer and Treasurer
			(Principal Financial and Accounting Officer)

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