UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)



x	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934.

For the quarterly period ended ~~March 31,~~June 30, 2018



o	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: 001-14901

CONSOL Coal Resources LP

(Exact name of registrant as specified in its charter)



Delaware		47-3445032
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

1000 CONSOL Energy Drive, Suite 100

Canonsburg, PA 15317-6506

(724) 485-3300

(Address, including zip code, and telephone number, including area code, of registrant’s principal executive offices)

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 x 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 x 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 x Non-accelerated filer o Smaller Reporting Company o Emerging Growth Company x

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 x

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

CONSOL Coal Resources LP had 15,909,323 common units, 11,611,067 subordinated units and a 1.7% general partner interest outstanding at ~~April 18,~~July 15, 2018.

TABLE OF CONTENTS



		Page
	Part I. Financial Information

Item 1.	Financial Statements
	Consolidated Statements of Operations for the three and six months ended ~~March 31,~~June 30, 2018 and 2017	5
	Consolidated Statements of Comprehensive Income for the three and six months ended ~~March 31,~~June 30, 2018 and 2017	6
	Consolidated Balance Sheets at ~~March 31,~~June 30, 2018 and December 31, 2017	7
	Consolidated Statement of Partners’ Capital for the ~~three~~six months ended ~~March 31,~~June 30, 2018	8
	Consolidated Statements of Cash Flows for the ~~three~~six months ended ~~March 31,~~June 30, 2018 and 2017	9
	Notes to the Consolidated Financial Statements	10

Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	20

Item 3.	Quantitative and Qualitative Disclosures About Market Risk	3135

Item 4.	Controls and Procedures	3135

	Part II. Other Information

Item 1.	Legal Proceedings	3236

Item 1A.	Risk Factors	3236

Item 4.	Mine Safety Disclosures	3336

Item 6.	Exhibits	3336

	Signatures	3437

Significant Relationships and Other Terms Referenced in this Quarterly Report

“Affiliated Company Credit Agreement” refers to an agreement entered into on November 28, 2017 among the Partnership and certain of its subsidiaries (collectively, the “Credit Parties”), CONSOL Energy, as lender and administrative agent, and PNC Bank, National Association, as collateral agent (“PNC”). The Affiliated Company Credit Agreement provides for a revolving credit facility in an aggregate principal amount of up to $275 million to be provided by CONSOL Energy, as lender;

“Class A Preferred Units” refers to the convertible preferred units representing limited partner interests in CONSOL Coal Resources LP. The Partnership issued 3,956,496 Class A Preferred Units to CNX on September 30, 2016. On October 2, 2017 the 3,956,496 Class A Preferred Units were converted to common units on a one-for-one basis, in accordance with our Partnership Agreement. The key terms of the Class A Preferred Units were described in our Annual Report on Form 10-K for the year ended December 31, 2016;

“CNX” refers to CNX Resources Corporation and its consolidated subsidiaries on or after November 28, 2017 and to CONSOL Energy Inc. and its consolidated subsidiaries prior to November 28, 2017;

“common units” refer to the limited partner interests in CONSOL Coal Resources LP. The holders of common units are entitled to participate in partnership distributions and are entitled to exercise the rights or privileges of limited partners under the Partnership Agreement. The common units are listed on the New York Stock Exchange under the symbol “CCR”;

“Conrhein” refers to Conrhein Coal Company, a Pennsylvania general partnership and a ~~wholly-owned~~wholly owned subsidiary of CONSOL Energy;

“CONSOL Coal Finance” refers to CONSOL Coal Finance Corporation, a Delaware corporation and a direct, wholly owned subsidiary of the Partnership;

“CONSOL Coal Resources LP,” the “Partnership,” “we,” “our,” “us” and similar terms ~~when used in a historical context,~~ refer to CONSOL Coal Resources LP, a Delaware limited partnership, and its subsidiaries, with common units listed for trading on the New York Stock Exchange under the ticker “CCR.” Prior to November 28, 2017, we were called CNX Coal Resources LP and our common units traded on the New York Stock Exchange under the ticker “CNXC”;

“CONSOL Energy” and our “sponsor” refer to CONSOL Energy Inc., a Delaware corporation and the parent of our general partner, and its subsidiaries other than our general partner, us and our subsidiaries;

“CONSOL Operating” refers to CONSOL Operating LLC, a Delaware limited liability company and a direct, wholly owned subsidiary of the Partnership;

“CONSOL Thermal Holdings” refers to CONSOL Thermal Holdings LLC, a Delaware limited liability company and a direct, wholly owned subsidiary of CONSOL Operating; following the PA Mining Acquisition, CONSOL Thermal Holdings owns a 25% undivided interest in the assets, liabilities, revenues and expenses comprising the Pennsylvania Mining Complex;

“CPCC” refers to CONSOL Pennsylvania Coal Company LLC, a Delaware limited liability company and a wholly owned subsidiary of CONSOL Energy;

“general partner” refers to CONSOL Coal Resources GP LLC, a Delaware limited liability company and our general partner;

“IPO” refers to the completion of the Partnership’s initial public offering on July 7, 2015;

“Omnibus Agreement” refers to the Omnibus Agreement dated July 7, 2015, as replaced by the First Amended and Restated Omnibus Agreement dated as of September 30, 2016, and as amended by the First Amendment to the First Amended and Restated Omnibus Agreement, dated November 28, 2017;

“PA Mining Acquisition” refers to a transaction which closed on September 30, 2016, wherein the Partnership and its wholly owned subsidiary, CONSOL Thermal Holdings, entered into a Contribution Agreement with CNX, CPCC and

Conrhein, under which CONSOL Thermal Holdings acquired an undivided 6.25% of the contributing parties’ right,

title and interest in and to the Pennsylvania Mining Complex (which represents an aggregate 5% undivided interest in and to the Pennsylvania Mining Complex);

“Partnership Agreement” refers to the First Amended and Restated Agreement of Limited Partnership of the Partnership, as replaced by the Second Amended and Restated Agreement of Limited Partnership of the Partnership dated as of September 30, 2016, as replaced by the Third Amended and Restated Partnership Agreement dated as of November 28, 2017;

“Pennsylvania Mining Complex” refers to the coal mines, coal reserves and related assets and operations, located primarily in southwestern Pennsylvania. The Pennsylvania Mining Complex was owned 80% by CNX and 20% by CONSOL Thermal Holdings from July 2015 until the closing of the PA Mining Acquisition in September 2016. Following the PA Mining Acquisition until November 28, 2017, the Pennsylvania Mining Complex was owned 75% by CNX and its subsidiaries and 25% by CONSOL Thermal Holdings. In connection with the separation on November 28, 2017, CNX’s 75% undivided interest in the Pennsylvania Mining Complex was transferred to CONSOL Energy;

“PNC Revolving Credit Facility” refers to a credit agreement that the Partnership entered into on July 7, 2015, as borrower, and certain subsidiaries of the Partnership, as guarantors, for a $400 million revolving credit facility with PNC, as administrative agent, and other lender parties. On November 28, 2017, in connection with the separation, the Partnership paid all fees and other amounts outstanding under the PNC Revolving Credit Facility and terminated the PNC Revolving Credit Facility and the related loan documents;

“preferred units” refer to any limited partnership interests, other than the common units and subordinated units, issued in accordance with the Partnership Agreement that, as determined by our general partner, have special voting rights to which our common units are not entitled. As of the date of this Quarterly Report on Form 10-Q, there are no outstanding preferred units;

“SEC” refers to the United States Securities and Exchange Commission;

“separation” refers to the separation of the coal business from CNX’s other businesses and the creation, as a result of the distribution, of an independent, publicly traded company (CONSOL Energy) to hold the assets and liabilities associated with the coal business (including CNX’s interest in the general partner and in us) after the distribution;

“sponsor” or “our sponsor” refers to CNX prior to the completion of the separation on November 28, 2017 and to CONSOL Energy following the completion of the separation; and

“subordinated units” refer to limited partner interests in CONSOL Coal Resources LP having the rights and obligations specified with respect to subordinated units in the Partnership Agreement. In connection with the completion of the IPO, we issued 11,611,067 subordinated units to CNX. In connection with the separation and the Affiliated Company Credit Agreement, all of the subordinated units were transferred directly to CONSOL Energy.

PART I : FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

CONSOL COAL RESOURCES LP

CONSOLIDATED STATEMENTS OF OPERATIONS

(Dollars in thousands, except unit data)

(unaudited)


	Three Months Ended March 31,				Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017		2018		2017
Coal Revenue	$	87,752	$	79,112	$	92,674	$	75,927	$	180,426	$	155,039
Freight Revenue	4,472		3,070		4,361		4,441		8,833		7,511
Other Income	2,277		1,098		1,022		2,104		3,299		3,202
Total Revenue and Other Income	94,501		83,280		98,057		82,472		192,558		165,752

Operating and Other Costs ¹	52,287		49,883		57,299		50,232		109,586		100,115
Depreciation, Depletion and Amortization	10,814		10,521		11,896		10,277		22,710		20,798
Freight Expense	4,472		3,070		4,361		4,441		8,833		7,511
Selling, General and Administrative Expenses ²	3,020		3,283		3,341		3,652		6,361		6,935
Interest Expense, Net ³	1,951		2,457		1,784		2,396		3,735		4,853
Total Costs	72,544		69,214		78,681		70,998		151,225		140,212
Net Income	$	21,957	$	14,066	$	19,376	$	11,474	$	41,333	$	25,540

Net Income Attributable to General and Limited Partner Ownership Interest in CONSOL Coal Resources	$	21,957	$	14,066	$	19,376	$	11,474	$	41,333	$	25,540
Less: General Partner Interest in Net Income	372		243		328		192		700		435
Less: Net Income Allocable to Class A Preferred Units	—		1,851		—		1,851		—		3,702
Net Income Allocable to Limited Partner Units - Basic	$	21,585	$	11,972
Add: Net Income Allocable to Class A Preferred Units	—		1,851
Net Income Allocable to Limited Partner Units - Diluted	$	21,585	$	13,823
Net Income Allocable to Limited Partner Units					$	19,048	$	9,431	$	40,633	$	21,403

Net Income per Limited Partner Unit - Basic	$	0.79	$	0.51	$	0.69	$	0.40	$	1.48	$	0.92
Net Income per Limited Partner Unit - Diluted	$	0.78	$	0.50	$	0.69	$	0.40	$	1.47	$	0.91

Limited Partner Units Outstanding - Basic	27,482,544		23,292,099		27,520,333		23,329,702		27,501,543		23,311,004
Limited Partner Units Outstanding - Diluted	27,567,690		27,379,800		27,588,062		23,470,050		27,578,427		23,444,923

Cash Distributions Declared per Unit ⁴
Common Unit	$	0.5125	$	0.5125	$	0.5125	$	0.5125	$	1.0250	$	1.0250
Subordinated Unit	$	0.5125	$	0.5125	$	0.5125	$	0.5125	$	1.0250	$	1.0250

¹Related Party of ~~$685~~$761 and ~~$872~~$867 for the three months ended ~~March 31,~~and $1,447 and $1,739 for the six months ended June 30, 2018 and ~~March 31,~~June 30, 2017, respectively.

²Related Party of ~~$1,645~~$1,953 and ~~$717~~$737 for the three months ended ~~March 31,~~and $3,598 and $1,454 for the six months ended June 30, 2018 and ~~March 31,~~June 30, 2017, respectively.

³Related party of ~~$1,951~~$1,784 and $0 for the three months ended ~~March 31,~~and $3,735 and $0 for the six months ended June 30, 2018 and ~~March 31,~~June 30, 2017, respectively.

⁴Represents the cash distributions declared related to the period presented. See Note 15 - Subsequent Events.

The accompanying notes are an integral part of these consolidated financial statements.

CONSOL COAL RESOURCES LP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Dollars in thousands)

(unaudited)


	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017			2018			2017
Net Income	$	21,957		$	14,066		$	19,376		$	11,474		$	41,333		$	25,540

Recognized Net Actuarial Gain	(2		)	(39		)	(2		)	(40		)	(4		)	(79		)
Other Comprehensive Loss	(2		)	(39		)	(2		)	(40		)	(4		)	(79		)

Comprehensive Income	$	21,955		$	14,027		$	19,374		$	11,434		$	41,329		$	25,461

The accompanying notes are an integral part of these consolidated financial statements.

CONSOL COAL RESOURCES LP

CONSOLIDATED BALANCE SHEETS

(Dollars in thousands)


	(Unaudited)				(Unaudited)
	March 31, 2018		December 31, 2017		June 30, 2018		December 31, 2017
ASSETS
Current Assets:
Cash	$	748	$	1,533	$	646	$	1,533
Trade Receivables	30,772		31,473		22,857		31,473
Other Receivables	1,431		1,970		1,514		1,970
Inventories	14,121		12,303		11,018		12,303
Prepaid Expenses	4,404		4,428		3,698		4,428
Total Current Assets	51,476		51,707		39,733		51,707
Property, Plant and Equipment:
Property, Plant and Equipment	919,878		910,468		927,658		910,468
Less—Accumulated Depreciation, Depletion and Amortization	493,758		483,410		505,299		483,410
Total Property, Plant and Equipment—Net	426,120		427,058		422,359		427,058
Other Assets:
Other	14,683		15,474		14,507		15,474
Total Other Assets	14,683		15,474		14,507		15,474
TOTAL ASSETS	$	492,279	$	494,239	$	476,599	$	494,239


LIABILITIES AND PARTNERS’ CAPITAL
Current Liabilities:
Accounts Payable	$	16,937		$	19,718		$	21,470		$	19,718
Accounts Payable—Related Party	935			3,071			3,455			3,071
Other Accrued Liabilities	45,345			44,179			40,390			44,179
Total Current Liabilities	63,217			66,968			65,315			66,968
Long-Term Debt:
Affiliated Company Credit Agreement—Related Party	187,000			196,583			160,500			196,583
Capital Lease Obligations	3,768			73			6,961			73
Total Long-Term Debt	190,768			196,656			167,461			196,656
Other Liabilities:
Pneumoconiosis Benefits	4,205			3,833			4,584			3,833
Workers’ Compensation	3,453			3,404			3,452			3,404
Asset Retirement Obligations	9,808			9,615			9,422			9,615
Other	603			607			605			607
Total Other Liabilities	18,069			17,459			18,063			17,459
TOTAL LIABILITIES	272,054			281,083			250,839			281,083
Partners’ Capital:
Common Units (15,906,728 Units Outstanding at March 31 2018; 15,789,106 Units Outstanding at December 31, 2017)	209,758			205,974
Subordinated Units (11,611,067 Units Outstanding at March 31, 2018 and December 31, 2017)	(12,068		)	(15,225		)
Common Units (15,909,323 Units Outstanding at June 30, 2018; 15,789,106 Units Outstanding at December 31, 2017)							213,126			205,974
Subordinated Units (11,611,067 Units Outstanding at June 30, 2018 and December 31, 2017)							(9,983		)	(15,225		)
General Partner Interest	12,094			11,964			12,178			11,964
Accumulated Other Comprehensive Income	10,441			10,443			10,439			10,443
Total Partners’ Capital	220,225			213,156			225,760			213,156
TOTAL LIABILITIES AND PARTNERS’ CAPITAL	$	492,279		$	494,239		$	476,599		$	494,239

The accompanying notes are an integral part of these consolidated financial statements.

CONSOL COAL RESOURCES LP

CONSOLIDATED STATEMENT OF PARTNERS’ CAPITAL

(Dollars in thousands)


	Limited Partners															Limited Partners
	Common			Subordinated			General Partner			Accumulated Other Comprehensive Income			Total			Common			Subordinated			General Partner			Accumulated Other Comprehensive Income			Total
Balance at December 31, 2017	$	205,974		$	(15,225	)	$	11,964		$	10,443		$	213,156		$	205,974		$	(15,225	)	$	11,964		$	10,443		$	213,156
(unaudited)
Net Income	12,477			9,108			372			—			21,957			23,490			17,143			700			—			41,333
Unitholder Distributions	(8,153		)	(5,951		)	(242		)	—			(14,346		)	(16,306		)	(11,901		)	(486		)	—			(28,693		)
Unit Based Compensation	359			—			—			—			359
Unit-Based Compensation																867			—			—			—			867
Units Withheld for Taxes	(899		)	—			—			—			(899		)	(899		)	—			—			—			(899		)
Actuarially Determined Long-Term Liability Adjustments	—			—			—			(2		)	(2		)	—			—			—			(4		)	(4		)
Balance at March 31, 2018	$	209,758		$	(12,068	)	$	12,094		$	10,441		$	220,225
Balance at June 30, 2018																$	213,126		$	(9,983	)	$	12,178		$	10,439		$	225,760

The accompanying notes are an integral part of these consolidated financial statements.

CONSOL COAL RESOURCES LP

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Dollars in thousands)

(unaudited)


	Three Months Ended March 31,						Six Months Ended June 30,
	2018			2017			2018			2017
Cash Flows from Operating Activities:
Net Income	$	21,957		$	14,066		$	41,333		$	25,540
Adjustments to Reconcile Net Income to Net Cash Provided by Operating Activities:
Depreciation, Depletion and Amortization	10,814			10,521			22,710			20,798
(Gain) Loss on Sale of Assets	(76		)	3
Unit Based Compensation	359			866
Gain on Sale of Assets							(62		)	(1,400		)
Unit-Based Compensation							867			1,707
Other Adjustments to Net Income	—			224			—			449
Changes in Operating Assets:
Accounts and Notes Receivable	1,240			(2,362		)	9,072			(3,244		)
Inventories	(1,818		)	(1,225		)	1,285			(2,516		)
Prepaid Expenses	224			(5		)	930			832
Changes in Other Assets	791			268			967			326
Changes in Operating Liabilities:
Accounts Payable	(1,931		)	(3,069		)	1,723			(2,460		)
Accounts Payable—Related Party	(2,136		)	98			384			530
Other Operating Liabilities	(575		)	(1,860		)	(1,466		)	84
Changes in Other Liabilities	415			137			470			108
Net Cash Provided by Operating Activities	29,264			17,662			78,213			40,754
Cash Flows from Investing Activities:
Capital Expenditures	(4,929		)	(2,030		)	(12,179		)	(5,472		)
Proceeds from Sales of Assets	75			—			165			1,500
Net Cash Used in Investing Activities	(4,854		)	(2,030		)	(12,014		)	(3,972		)
Cash Flows from Financing Activities:
Payments on Capitalized Leases	(367		)	(26		)	(1,411		)	(52		)
Net Payments on Related Party Long-Term Notes	(9,583		)	—			(36,083		)	—
Net Payments on Revolver	—			(4,000		)	—			(11,000		)
Payments for Unitholder Distributions	(14,346		)	(14,050		)	(28,693		)	(28,100		)
Units Withheld for Taxes	(899		)	(807		)	(899		)	(807		)
Net Cash Used in Financing Activities	(25,195		)	(18,883		)	(67,086		)	(39,959		)
Net Decrease in Cash	(785		)	(3,251		)	(887		)	(3,177		)
Cash at Beginning of Period	1,533			9,785			1,533			9,785
Cash at End of Period	$	748		$	6,534		$	646		$	6,608

Non-Cash Investing and Financing Activities:
Capital Lease	$	5,658		$	—		$	11,495		$	—

The accompanying notes are an integral part of these consolidated financial statements.

CONSOL COAL RESOURCES LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Dollars in thousands, except per unit amounts)

NOTE 1—BASIS OF PRESENTATION:

The accompanying unaudited consolidated financial statements were prepared in accordance with accounting principles generally accepted in the United States (“U.S. GAAP”) for interim financial information. Accordingly, they do not include all of the information and footnotes required by U.S. GAAP for complete financial statements. In the opinion of management, all adjustments (consisting of normal recurring adjustments) considered necessary for a fair presentation have been included.

For the three and six months ended ~~March 31,~~June 30, 2018 and 2017, the unaudited Consolidated Financial Statements include the accounts of CONSOL Operating and CONSOL Thermal Holdings, wholly owned and controlled subsidiaries.

On November 28, 2017, CONSOL Energy was separated from CNX into an independent, publicly traded coal company via a pro rata distribution of all of CONSOL Energy’s common stock to CNX’s stockholders. CONSOL Energy was originally formed as CONSOL Mining Corporation in Delaware on June 21, 2017 to hold CNX’s coal business including its interest in the Pennsylvania Mining Complex and certain related coal assets, including CNX’s ownership interest in the Partnership and our general partner, CNX’s terminal operations at the Port of Baltimore and undeveloped coal reserves located in the Northern Appalachian, Central Appalachian and Illinois basins and certain related coal assets and liabilities. As part of the separation, CONSOL Mining Corporation changed its name to CONSOL Energy Inc. and its ticker to “CEIX”, CNX changed its name to CNX Resources Corporation and its ticker to “CNX”, the Partnership changed its name to CONSOL Coal Resources LP and its ticker to “CCR” and the general partner changed its name to CONSOL Coal Resources GP LLC.

Recent Accounting Pronouncements:

In ~~January~~June 2018, the Financial Accounting Standards Board (“FASB”) issued Update 2018-07 - Stock Compensation (Topic 718) Improvements to Nonemployee Share-Based Payment Accounting. The amendments in this update seek to simplify accounting for nonemployee share-based payments by clarifying and improving the areas of the overall measurement objective, measurement date, and awards with performance conditions. For public business entities, the amendments in this update are effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. Management does not expect this update to have a material impact on the Partnership's financial statements.

In January 2018, the FASB issued Update 2018-01 - Leases (Topic 842) Land Easement Practical Expedient for Transition to Topic 842. This update, if elected, would not require an entity to reassess the accounting treatment of existing land easements not currently accounted for as a lease under Topic 840. Once an entity adopts Topic 842, it should apply that Topic prospectively to all new (or modified) land easements to determine whether the arrangement should be accounted for as a lease. For public business entities, the amendments in this update are effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. Early application of the amendments in this update is permitted for all entities. Management is currently evaluating the impact this guidance may have on the Partnership’s financial statements.

In ~~February~~ 2016, the FASB issued ~~Update 2016-02 - Leases (Topic 842). This update is intended to improve financial reporting about leasing transactions. This update will require~~a new lease accounting standard which requires lessees to ~~recognize all~~put most leases ~~with terms greater than 12 months~~ on their balance ~~sheet as lease liabilities with a corresponding right-of-use asset. This update maintains~~sheets, but recognize the ~~dual model for lease accounting, requiring leases to be classified as either operating or finance, with lease classification determined~~expenses in their income statements in a manner similar to ~~existing~~current practice. The new standard states that a lessee will recognize a lease ~~guidance. The basic principle is that leases of all types convey~~liability for the obligation to make lease payments and a right-of-use asset for the right to ~~direct~~use the ~~use and obtain substantially all~~underlying asset for the ~~economic benefits of an identified asset, meaning they create an asset and liability for lessees. Lessees will classify~~lease term. Expenses related to leases ~~as either finance leases (comparable~~determined to ~~current capital leases) or~~be operating leases ~~(comparable to current operating leases). Costs for a finance lease~~ will be ~~split between~~recognized on a straight-line basis, while those determined to be financing leases will be recognized following a front-loaded expense profile in which interest and amortization are presented separately in the income statement. The ultimate impact of the standard will depend on the Partnership's lease portfolio as of the adoption date. CONSOL Energy has started compiling and ~~interest expense,~~reviewing its population of leases and assessing its systems and internal controls relating to the Partnership's accounting for leases. In addition to monitoring FASB activity regarding ASU 2016-02, the Partnership continues to monitor various non-authoritative groups with ~~a single lease expense reported for operating leases. This update also~~respect to implementation issues that could affect its assessment. These changes will require both qualitative and quantitative disclosures to help investors and other financial statement users better understand the amount, timing, and uncertainty of cash flows arising from leases. For public business entities, the amendments in this update arebe effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. Early application of the amendments in this update is permitted for all entities. Management is currently evaluating the impact this guidance may have on the Partnership’s financial statements, specifically as it relates to potential embedded leases contained within long-term contracts.

NOTE 2—REVENUE:

The following table disaggregates our revenue by major source for the ~~period~~three and six months ended ~~March 31,~~June 30, 2018:


	Three Months Ended March 31, 2018		Three Months Ended June 30, 2018		Six Months Ended June 30, 2018
Coal Revenue	$	87,752	$	92,674	$	180,426
Freight Revenue	4,472		4,361		8,833
Total Revenue from Contracts with Customers	$	92,224	$	97,035	$	189,259

ASU 2014-09 - Revenue from Contracts with Customers. On January 1, 2018, we adopted the new accounting standard ASC 606, Revenue from Contracts with Customers and all the related amendments (“new revenue standard”) for all contracts using the modified retrospective method. There was no cumulative adjustment to the opening balance of retained earnings as a result of initially applying the new revenue standard. The comparative information has not been restated and continues to be reported under the accounting standards in effect for those periods. We do not expect the adoption of the new revenue standard to have a material impact to our net income on an ongoing basis. Our revenue continues to be recognized when title passes to the customer.

Coal Revenue

Revenues are recognized when title passes to the customers and the price is fixed and determinable. Generally, title passes when coal is loaded at the central preparation facility and, on occasion, at terminal locations or other customer destinations. Our coal contract revenue per ton is fixed and determinable and adjusted for nominal quality adjustments. Some coal contracts also contain positive electric power price related adjustments in addition to a fixed base price per ton. None of the Partnership's coal contracts allow for retroactive adjustments to pricing after title to the coal has passed.

Some of our contracts span multiple years and have annual pricing modification, based upon market-driven or inflationary adjustments, where no additional value is exchanged. Also, our contracts contain favorable electric power price related adjustments, which represent market-driven price adjustments, wherein there is no additional value being exchanged. Management believes that the invoice price is the most appropriate rate at which to recognize revenue.

While we do, from time to time, experience costs of obtaining coal customer contracts with amortization periods greater than one year, those costs would be immaterial to our net income. As of and for the three and six months ended ~~March 31,~~June 30, 2018, we do not have any capitalized costs to obtain customer contracts on our balance sheet nor have we recognized any amortization of previously existing capitalized costs of obtaining customer contracts. Further, the Partnership has not recognized any revenue in the current period that is not a result of current period performance.

Freight Revenue

Some of our coal contracts require that we sell our coal at locations other than our central preparation plant. The cost to transport our coal to the ultimate sales point is passed through to our customers and we recognize the freight revenue equal to the transportation cost when title of the coal passes to the customer.

NOTE 3—NET INCOME PER LIMITED PARTNER AND GENERAL PARTNER INTEREST:

The Partnership allocates net income among our general partner and limited partners using the two-class method in accordance with applicable authoritative accounting guidance. Under the two-class method, we allocate our net income to our limited partners and our general partner in accordance with the terms of our Partnership Agreement. We also allocate any earnings in excess of distributions to our limited partners and our general partner in accordance with the terms of our Partnership Agreement. We allocate any distributions in excess of earnings for the period to our general partner and our limited partners based on their respective proportionate ownership interests in us, after taking into account distributions to be paid with respect to the incentive distribution rights, as set forth in the Partnership Agreement.

Diluted net income per limited partner unit reflects the potential dilution that could occur if securities or agreements to issue common units, such as awards under the long-term incentive plan, were exercised, settled or converted into common units. When it is determined that potential common units resulting from an award subject to performance or market conditions should be included in the diluted net income per limited partner unit calculation, the impact is reflected by applying the treasury stock method.

The following table illustrates the Partnership’s calculation of net income per unit for common units and subordinated units (in thousands, except for per unit information):


	Three Months Ended March 31,				Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017		2018		2017
Net Income	$	21,957	$	14,066	$	19,376	$	11,474	$	41,333	$	25,540
Less: General Partner Interest in Net Income	372		243		328		192		700		435
Less: Net Income Allocable to Class A Preferred Units	—		1,851		—		1,851		—		3,702
Net Income Allocable to Limited Partner Units	$	21,585	$	11,972	$	19,048	$	9,431	$	40,633	$	21,403

Net Income Allocable to Common Units - Basic	12,477		6,014
Add: Net Income Allocable to Class A Preferred Units	—		1,851
Net Income Allocable to Common Units - Diluted	$	12,477	$	7,865
Net Income Allocable to Common Units - Basic & Diluted					$	11,013	$	4,737	$	23,490	$	10,751

Net Income Allocable to Subordinated Units - Basic & Diluted	$	9,108	$	5,958	$	8,035	$	4,694	$	17,143	$	10,652

Weighted Average Limited Partner Units Outstanding - Basic
Common Units	15,871,477		11,681,032		15,909,266		11,718,635		15,890,476		11,699,937
Subordinated Units	11,611,067		11,611,067		11,611,067		11,611,067		11,611,067		11,611,067
Total	27,482,544		23,292,099		27,520,333		23,329,702		27,501,543		23,311,004

Weighted Average Limited Partner Units Outstanding - Diluted
Common Units	15,956,623		15,768,733		15,976,995		11,858,983		15,967,360		11,833,856
Subordinated Units	11,611,067		11,611,067		11,611,067		11,611,067		11,611,067		11,611,067
Total	27,567,690		27,379,800		27,588,062		23,470,050		27,578,427		23,444,923

Net Income Per Limited Partner Unit - Basic
Common Units	$	0.79	$	0.51	$	0.69	$	0.40	$	1.48	$	0.92
Subordinated Units	$	0.78	$	0.51	$	0.69	$	0.40	$	1.48	$	0.92
Net Income Per Limited Partner Unit - Basic	$	0.79	$	0.51	$	0.69	$	0.40	$	1.48	$	0.92

Net Income Per Limited Partner Unit - Diluted
Common Units	$	0.78	$	0.50	$	0.69	$	0.40	$	1.47	$	0.91
Subordinated Units	$	0.78	$	0.51	$	0.69	$	0.40	$	1.48	$	0.92
Net Income Per Limited Partner Unit - Diluted	$	0.78	$	0.50	$	0.69	$	0.40	$	1.47	$	0.91

The outstanding Class A Preferred Units were converted on a one-to-one basis into common units on October 2, 2017, under the terms of the Partnership Agreement. As a result, the Partnership issued an aggregate of 3,956,496 Common Units to CNX and canceled the Class A Preferred Units. Following the conversion of the Class A Preferred Units into Common Units, no Class A Preferred Units are outstanding.

There were ~~129,850~~126,799 and ~~369,210~~365,131 phantom units excluded from the computation of the diluted earnings per unit because their effect would be anti-dilutive for the three and six months ended ~~March 31,~~June 30, 2018 and ~~March 31,~~June 30, 2017, respectively. Diluted net income per limited partner unit does not reflect the potential dilution that could occur if the preferred units of the partnership were converted to common units because the effect would be anti-dilutive for the three and six months ended June 30, 2017.

NOTE 4—INVENTORIES:


	March 31, 2018		December 31, 2017		June 30, 2018		December 31, 2017
Coal	$	4,276	$	2,853	$	1,231	$	2,853
Supplies	9,845		9,450		9,787		9,450
Total Inventories	$	14,121	$	12,303	$	11,018	$	12,303

Inventories are stated at the lower of cost or net realizable value. The cost of coal inventories is determined by the first-in, first-out (FIFO) method. Coal inventory costs include labor, supplies, equipment costs, operating overhead, depreciation, depletion and amortization, and other related costs. The cost of supplies inventory is determined by the average cost method and includes operating and maintenance supplies to be used in our coal operations.

NOTE 5—PROPERTY, PLANT AND EQUIPMENT:

March 31,
2018 December 31,
2017
Coal and other plant and equipment $ 616,143
$ 607,314
Coal properties and surface lands 122,680
122,377
Airshafts 95,836
95,566
Mine development 81,538
81,538
Coal advance mining royalties 3,681
3,673
Total property, plant and equipment 919,878
910,468
Less: Accumulated depreciation, depletion and amortization 493,758
483,410
Total Net Property, Plant and Equipment $ 426,120
$ 427,058



	June 30, 2018		December 31, 2017
Coal and Other Plant and Equipment	$	622,411	$	607,314
Coal Properties and Surface Lands	122,874		122,377
Airshafts	97,143		95,566
Mine Development	81,538		81,538
Coal Advance Mining Royalties	3,692		3,673
Total Property, Plant and Equipment	927,658		910,468
Less: Accumulated Depreciation, Depletion and Amortization	505,299		483,410
Total Property, Plant and Equipment, Net	$	422,359	$	427,058

Coal reserves are controlled either through fee ownership or by lease. The duration of the leases vary; however, the lease terms generally are extended automatically to the exhaustion of economically recoverable reserves, as long as active mining continues. Coal interests held by lease provide the same rights as fee ownership for mineral extraction and are legally considered real property interests.

As of ~~March 31,~~June 30, 2018 and December 31, 2017, property, plant and equipment includes gross assets under capital lease of ~~$6,050~~$11,881 and $625, respectively. Accumulated amortization for capital leases was ~~$634~~$1,596 and $473 at ~~March 31,~~June 30, 2018 and December 31, 2017, respectively. Amortization expense for assets under capital leases approximated ~~$327~~$968 and $24 for the three months ended ~~March 31,~~and $1,295 and $48 for the six months ended June 30, 2018 and 2017, respectively, and is included in Depreciation, Depletion and Amortization in the accompanying Consolidated Statements of Operations.

NOTE 6—OTHER ACCRUED LIABILITIES:

March 31,
2018 December 31, 2017
Subsidence liability $ 22,315
$ 22,430
Longwall equipment buyout 5,837
5,658
Accrued payroll and benefits 3,202
3,219
Equipment lease rental 2,657
2,906
Accrued other taxes 1,972
1,399
Accrued interest (related party) 2,131
824
Goods received, not invoiced 1,013
1,057
Other 1,795
4,012
Current portion of long-term liabilities:
Workers’ compensation 1,403
1,381
Capital leases 1,818
77
Asset retirement obligations 881
881
Pneumoconiosis benefits 185
195
Long-term disability 136
140
Total Other Accrued Liabilities $ 45,345
$ 44,179



	June 30, 2018		December 31, 2017
Subsidence Liability	$	22,815	$	22,430
Accrued Payroll and Benefits	4,138		3,219
Accrued Interest (Related Party)	1,976		824
Accrued Other Taxes	1,893		1,399
Equipment Lease Rental	490		2,906
Longwall Equipment Buyout	—		5,658
Other	2,731		5,069
Current Portion of Long-Term Liabilities:
Capital Leases	3,412		77
Workers’ Compensation	1,424		1,381
Asset Retirement Obligations	1,202		881
Pneumoconiosis Benefits	176		195
Long-Term Disability	133		140
Total Other Accrued Liabilities	$	40,390	$	44,179

NOTE 7—LONG-TERM DEBT:


	March 31, 2018		December 31, 2017		June 30, 2018		December 31, 2017
Affiliated Company Credit Agreement	$	187,000	$	196,583	$	160,500	$	196,583

Total Long-Term Debt	$	187,000	$	196,583	$	160,500	$	196,583

Affiliated Company Credit Agreement

On November 28, 2017, the Partnership and the other Credit Parties entered into the Affiliated Company Credit Agreement by and among the Credit Parties, CONSOL Energy, as lender and administrative agent, and PNC. The Affiliated Company Credit Agreement provides for a revolving credit facility in an aggregate principal amount of up to $275,000 to be provided by CONSOL Energy, as lender. In connection with the completion of the separation and the Partnership’s entry into the Affiliated Company Credit Agreement, the Partnership made an initial draw of $200,583, the net proceeds of which were used to repay the PNC Revolving Credit Facility, to provide working capital for the Partnership following the separation and for other general corporate purposes. Additional drawings under the Affiliated Company Credit Agreement are available for general partnership purposes. The Affiliated Company Credit Agreement matures on February 27, 2023. The collateral obligations under the Affiliated Company Credit Agreement generally mirror the PNC Revolving Credit Facility, including the list of entities that act as guarantors thereunder. The obligations under the Affiliated Company Credit Agreement are guaranteed by the Partnership’s subsidiaries and secured by substantially all of the assets of the Partnership and its subsidiaries pursuant to the security agreement and various mortgages.

Interest on outstanding obligations under our Affiliated Company Credit Agreement accrues at a fixed rate ranging from 3.75% to 4.75%, depending on the total net leverage ratio. The unused portion of our Affiliated Company Credit Agreement is subject to a commitment fee of 0.50% per annum.

The Partnership had available capacity under the Affiliated Company Credit Agreement of ~~$88,000~~$114,500 and $78,417 as of ~~March 31,~~June 30, 2018 and December 31, 2017, respectively. Interest on outstanding borrowings under the Affiliated Company Credit Agreement ~~at March 31, 2018 and December 31, 2017~~ was accrued at a rate of 4.00% and 4.25%. as of June 30, 2018 and December 31, 2017, respectively. The Affiliated Company Credit Agreement contains certain covenants and conditions that, among other things, limit the Partnership’s ability to: (i) incur or guarantee additional debt; (ii) make cash distributions (subject to certain limited exceptions); provided that we will be able to make cash distributions of available cash to partners so long as no event of default is continuing or would result therefrom; (iii) incur certain liens or permit them to exist; (iv) make particular investments and loans; provided that we will be able to increase our ownership percentage of our undivided interest in the Pennsylvania Mining Complex and make investments in the Pennsylvania Mining Complex in accordance with our ratable ownership; (v) enter into certain types of transactions with affiliates; (vi) merge or consolidate with another company; and (vii) transfer, sell or otherwise dispose of assets. The Partnership is also subject to covenants that require the Partnership to maintain certain financial ratios.

For example, the Partnership is obligated to maintain at the end of each fiscal quarter (a) maximum first lien gross leverage ratio of 2.75 to 1.00 and (b) a maximum total net leverage ratio of 3.25 to 1.00, each of which will be calculated on a consolidated basis for the Partnership and its restricted subsidiaries at the end of each fiscal quarter. At ~~March 31,~~June 30, 2018, the Partnership was in compliance with its debt covenants with the first lien gross leverage ratio ~~was 1.77~~at 1.45 to 1.00 and the total net leverage ratio ~~was 1.77~~at 1.45 to 1.00.

NOTE 8—COMPONENTS OF COAL WORKERS’ PNEUMOCONIOSIS (CWP) AND WORKERS’ COMPENSATION NET PERIODIC BENEFIT COSTS:

The Partnership is obligated to CONSOL Energy for medical and disability benefits to certain CPCC employees and their dependents resulting from occurrences of coal workers’ pneumoconiosis disease and is also obligated to CONSOL Energy to compensate certain individuals who are entitled benefits under workers’ compensation laws.

CWP
Workers’ Compensation
Three Months Ended
March 31, Three Months Ended
March 31,
2018 2017 2018 2017
Service cost $ 372
$ 283
$ 366
$ 320
Interest cost 36
18
35
33
Amortization of actuarial gain (5 ) (34 ) (1 ) (8 )
State administrative fees and insurance bond premiums —
—
7
57
Net periodic benefit cost $ 403
$ 267
$ 407
$ 402



	CWP												Workers’ Compensation
	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017			2018			2017			2018			2017
Service Cost	$	372		$	283		$	745		$	566		$	366		$	320		$	732		$	641
Interest Cost	36			18			72			36			35			33			70			65
Amortization of Actuarial Gain	(5		)	(34		)	(11		)	(68		)	(1		)	(8		)	(3		)	(17		)
State Administrative Fees and Insurance Bond Premiums	—			—			—			—			22			41			29			98
Net Periodic Benefit Cost	$	403		$	267		$	806		$	534		$	422		$	386		$	828		$	787

NOTE 9—FAIR VALUE OF FINANCIAL INSTRUMENTS:

The Partnership determines the fair value of assets and liabilities based on the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants. The fair values are based on assumptions that market participants would use when pricing an asset or liability, including assumptions about risk and the risks inherent in valuation techniques and the inputs to valuations. The fair value hierarchy is based on whether the inputs to valuation techniques are observable or unobservable. Observable inputs reflect market data obtained from independent sources (including LIBOR-based discount rates), while unobservable inputs reflect the Partnership’s own assumptions of what market participants would use.

The fair value hierarchy includes three levels of inputs that may be used to measure fair value as described below.

Level One - Quoted prices for identical instruments in active markets.

Level Two - The fair value of the assets and liabilities included in Level 2 are based on standard industry income approach models that use significant observable inputs, including LIBOR-based discount rates.

Level Three - Unobservable inputs significant to the fair value measurement supported by little or no market activity. The significant unobservable inputs used in the fair value measurement of the Partnership’s third party guarantees are the credit risk of the third party and the third party surety bond markets.

In those cases when the inputs used to measure fair value meet the definition of more than one level of the fair value hierarchy, the lowest level input that is significant to the fair value measurement in its totality determines the applicable level in the fair value hierarchy.

The following methods and assumptions were used to estimate the fair value for which the fair value option was not elected:

Long-term debt: The fair value of long-term debt is measured using unadjusted quoted market prices or estimated using discounted cash flow analyses. The discounted cash flow analyses are based on current market rates for instruments with similar cash flows.

The carrying amounts and fair values of financial instruments for which the fair value option was not elected are as follows:

March 31, 2018 December 31, 2017

Carrying
Amount

Fair
Value

Carrying
Amount

Fair
Value
Affiliated Company Credit Agreement - Related Party $ 187,000
$ 187,000
$ 196,583
$ 196,583



	June 30, 2018				December 31, 2017
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Affiliated Company Credit Agreement - Related Party	$	160,500	$	160,500	$	196,583	$	196,583

The Partnership’s debt obligations are valued through reference to the applicable underlying benchmark rate and, as a result, constitute Level 2 fair value measurements.

NOTE 10—COMMITMENTS AND CONTINGENT LIABILITIES:

The Partnership is subject to various lawsuits and claims with respect to such matters as personal injury, wrongful death, damage to property, exposure to hazardous substances, governmental regulations (including environmental remediation), employment and contract disputes and other claims and actions arising out of the normal course of its business. We accrue the estimated loss for these lawsuits and claims when the loss is probable and can be estimated. Our current estimated accruals related to these pending claims, individually and in the aggregate, are immaterial to the financial position, results of operations or cash flows of the Partnership. It is possible that the aggregate loss in the future with respect to these lawsuits and claims could ultimately be material to the financial position, results of operations or cash flows of the Partnership; however, such amounts cannot be reasonably estimated.

At ~~March 31,~~June 30, 2018, the Partnership was contractually obligated to CONSOL Energy for financial guarantees and letters of credit to certain third parties which were issued by CONSOL Energy on behalf of the Partnership. The maximum potential total of future payments that we could be required to make under these instruments is ~~$74,150.~~$85,539. The instruments are comprised of $301 of letters of credit expiring in the next ~~year, $64,212~~three years, $75,841 of environmental surety bonds expiring within the next three years, and ~~$9,637~~$9,397 of employee-related and other surety bonds expiring within the next three years. Employee-related financial guarantees have primarily been provided to support various state workers’ compensation and federal black lung self-insurance programs. Environmental financial guarantees have primarily been provided to support various performance bonds related to reclamation and other environmental issues. Other guarantees have been extended to support insurance policies, legal matters, full and timely payments of mining equipment leases, and various other items necessary in the normal course of business. These amounts have not been reduced for potential recoveries under recourse or collateralization provisions. Generally, recoveries under reclamation bonds would be limited to the extent of the work performed at the time of the default. No amounts related to these financial guarantees and letters of credit are recorded as liabilities on the financial statements. The Partnership’s management believes that these guarantees will expire without being funded, and therefore the commitments will not have a material adverse effect on the financial condition of the Partnership.

NOTE 11—RECEIVABLES FINANCING AGREEMENT

On November 30, 2017, (i) CONSOL Marine Terminals LLC, formerly known as CNX Marine Terminals LLC, as an originator of receivables, (ii) CPCC, as an originator of receivables and as initial servicer of the receivables for itself and the other originators (collectively, the “Originators”), each a wholly owned subsidiary of CONSOL Energy, and (iii) CONSOL Funding LLC (the “SPV”), as buyer, entered into a Purchase and Sale Agreement (the “Purchase and Sale Agreement”). Concurrently, (i) CONSOL Thermal Holdings, as sub-originator, and (ii) CPCC, as buyer and as initial servicer of the receivables for itself and CONSOL Thermal Holdings, entered into a Sub-Originator Agreement (the “Sub-Originator PSA”). In addition, on that date, the SPV entered into a Receivables Financing Agreement (the “Receivables Financing Agreement”) by and among (i) the SPV, as borrower, (ii) CPCC, as initial servicer, (iii) PNC, as administrative agent, LC Bank and lender, and (iv) the additional persons from time to time party thereto as lenders. Together, the Purchase and Sale Agreement, the Sub-Originator PSA and the Receivables Financing Agreement establish the primary terms and conditions of an accounts receivable securitization program (the “Securitization”).

Pursuant to the Securitization, (i) CONSOL Thermal Holdings will sell current and future trade receivables to CPCC and (ii) the Originators will sell and/or contribute current and future trade receivables (including receivables sold to CPCC by CONSOL Thermal Holdings) to the SPV and the SPV will, in turn, pledge its interests in the receivables to PNC, which will either make loans or issue letters of credit on behalf of the SPV. The maximum amount of advances and letters of credit outstanding under the Securitization may not exceed $100,000. Loans under the Securitization will accrue interest at a reserve-adjusted LIBOR market index rate equal to the one-month Eurodollar rate. Loans and letters of credit under the Securitization also will accrue a program fee and participation fee, respectively, equal to 4.00% per annum. In addition, the SPV paid certain structuring fees to PNC Capital Markets LLC and will pay other customary fees to the lenders, including a fee on unused commitments. The SPV’s assets and credit are not available to satisfy the debts and obligations owed to the creditors of CONSOL Energy, CONSOL Thermal Holdings or any of the Originators. CONSOL Thermal Holdings, the Originators and CPCC as servicer are independently liable for their own customary representations, warranties, covenants and indemnities. In addition, CONSOL Energy has guaranteed the performance of the obligations of CONSOL Thermal Holdings, the Originators and CPCC as servicer, and will guarantee the obligations of any additional originators or successor servicer that may become party to the Securitization. However, neither CONSOL Energy nor its affiliates will guarantee collectability of receivables or the creditworthiness of obligors thereunder.

The Securitization contains various customary representations and warranties, covenants and default provisions which provide for the termination and acceleration of the commitments and loans under the Securitization in circumstances including,

but not limited to, failure to make payments when due, breach of representation, warranty or covenant, certain insolvency events or failure to maintain the security interest in the trade receivables, and defaults under other material indebtedness.

As of ~~March 31,~~June 30, 2018, the Partnership, through CONSOL Thermal Holdings, sold ~~$30,772~~$22,857 of trade receivables to CPCC. The Partnership has not derecognized the receivables due to its continued involvement in the collections efforts.

The Securitization expires on August 30, 2018. CONSOL expects to renew the Securitization with PNC Bank for a three-year term.

NOTE 12—RELATED PARTY:

CONSOL Energy

In conjunction with the IPO, the Partnership entered into several agreements, including an omnibus agreement, with CNX. In connection with the PA Mining Acquisition, on September 30, 2016, the then General Partner and the Partnership entered into the First Amended and Restated Omnibus Agreement (the “Amended Omnibus Agreement”) with CNX and certain of its subsidiaries. Under the Amended Omnibus Agreement, CNX would indemnify the Partnership for certain liabilities, including those relating to:

all tax liabilities attributable to the assets contributed to the Partnership in connection with the PA Mining Acquisition (the “First Drop Down Assets”) arising prior to the closing of the PA Mining Acquisition or otherwise related to the ~~Contributing Parties’~~contributing parties’ contribution of the First Drop Down Assets to the Partnership in connection with the PA Mining Acquisition; and

certain operational and title matters related to the First Drop Down Assets, including the failure to have (i) the ability to operate under any governmental license, permit or approval or (ii) such valid title to the First Drop Down Assets, in each case, that is necessary for the Partnership to own or operate the First Drop Down Assets in substantially the same manner as owned or operated by the Contributing Parties prior to the Acquisition.

The Partnership would indemnify CNX for certain liabilities relating to the First Drop Down Assets, including those relating to:

the use, ownership or operation of the First Drop Down Assets; and

the Partnership’s operation of the First Drop Down Assets under permits and/or bonds, letters of credit, guarantees, deposits and other pre-payments held by CNX.

The Amended Omnibus Agreement amended the Partnership’s obligations to CNX with respect to the payment of an annual administrative support fee and reimbursement for the provision of certain management and operating services provided by CNX, in each case to reflect structural changes in how those services are provided to the Partnership by CNX.

On November 28, 2017, in connection with the separation, the general partner, the Partnership, CNX, CONSOL Energy and certain of its subsidiaries entered into the First Amendment to the First Amended and Restated Omnibus Agreement (the “First Amendment to Omnibus Agreement”), dated September 30, 2016, to, among other things:

add CONSOL Energy as a party to the omnibus agreement;

eliminate the right-of-first offer to the Partnership for the 75% of the Pennsylvania Mining Complex not owned by the Partnership;

effect an assignment of all of CNX’s rights and obligations under the omnibus agreement to CONSOL Energy and remove CNX as a party to and, except with respect to CNX’s obligations under Article II of the omnibus agreement, eliminate all of CNX’s obligations under, the omnibus agreement, as amended by the First Amendment to Omnibus Agreement; and

make certain adjustments to the indemnification obligations of the parties.

Charges for services from CONSOL Energy include the following:


	Three Months Ended March 31,				Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017		2018		2017
Operating and Other Costs	$	685	$	872	$	761	$	867	$	1,447	$	1,739
Selling, General and Administrative Expenses	1,645		717		1,953		737		3,598		1,454
Total Services from CONSOL Energy	$	2,330	$	1,589	$	2,714	$	1,604	$	5,045	$	3,193

Operating and Other Costs includes service costs for pension and insurance expenses. Selling, General and Administrative Expenses include charges for incentive compensation, an annual administrative support fee and reimbursement

for the provision of certain management and operating services provided by CONSOL Energy. Since November 28, 2017, certain administrative services historically incurred by the Partnership are now incurred by CONSOL Energy and the Partnership's portion is reimbursed to CONSOL Energy.

For the ~~period~~three months ended ~~March 31,~~June 30, 2018, ~~$2,134~~$1,976 of interest was incurred on the Affiliated Company Credit Agreement, of which ~~$1,951~~$1,784 is included in Interest Expense in the Consolidated Statements of Operations, and ~~$183~~$192 was capitalized and included in Property, Plant, and Equipment on the Consolidated Balance Sheets. For the six months ended June 30, 2018, $4,110 of interest was incurred on the Affiliated Company Credit Agreement, of which $3,735 is included in Interest Expense in the Consolidated Statements of Operations, and $375 was capitalized and included in Property, Plant, and Equipment on the Consolidated Balance Sheets. Interest is calculated based upon a fixed rate, determined quarterly, depending on the total net leverage ratio. For the ~~period~~three and six months ended ~~March 31,~~June 30, 2018, the weighted average interest rate was ~~4.25%.~~4.01% and 4.13%, respectively. See Note 7 - Long-Term Debt for more information.

At ~~March 31,~~June 30, 2018 and December 31, 2017, the Partnership had a net payable to CONSOL Energy in the amount of ~~$935~~$3,455 and $3,071, respectively. This payable includes reimbursements for business expenses, executive fees, stock-based compensation and other items under the Omnibus Agreement.

NOTE 13—LONG-TERM INCENTIVE PLAN:

Under the CONSOL Coal Resources LP 2015 Long-Term Incentive Plan (the “LTIP”), our general partner may issue long-term equity-based awards to directors, officers and employees of our general partner or its affiliates, or to any consultants, affiliates of our general partner or other individuals who perform services for us. These awards are intended to compensate the recipients thereof based on the performance of our common units and their continued service during the vesting period, as well as to align their long-term interests with those of our unitholders. We are responsible for the cost of awards granted under the LTIP and all determinations with respect to awards to be made under the LTIP will be made by the board of directors of our general partner or any committee thereof that may be established for such purpose or by any delegate of the board of directors or such committee, subject to applicable law, which we refer to as the plan administrator.

The LTIP limits the number of units that may be delivered pursuant to vested awards to 2,300,000 common units, subject to proportionate adjustment in the event of unit splits and similar events. Common units subject to awards that are canceled, forfeited, withheld to satisfy exercise prices or tax withholding obligations or otherwise terminated without delivery of the common units will be available for delivery pursuant to other awards.

The general partner has granted equity-based phantom units that vest over a period of a director’s continued service with the Partnership. The phantom units will be paid in common units or an amount of cash equal to the fair market value of a unit based on the vesting date. The awards may accelerate upon a change in control of the Partnership. Compensation expense is recognized on a straight-line basis over the requisite service period, which is generally the vesting term. The Partnership recognized ~~$360~~compensation expense of $510 and ~~$866 of compensation expense~~$840 for the three months ended ~~March 31,~~and $867 and $1,707 for the six months ended June 30, 2018 and ~~March 31,~~June 30, 2017 respectively, which is included in Selling, General and Administrative Expense in the Consolidated Statements of Operations. As of ~~March 31,~~June 30, 2018, there is ~~$2,978~~$2,398 of unearned compensation that will vest over a weighted average period of ~~1.60~~1.38 years. The total fair value of ~~restricted stock~~phantom units vested during the three months ended ~~March 31,~~June 30, 2018 and ~~March 31,~~June 30, 2017 was ~~$2,419~~$50 and $0, respectively. The total fair value of phantom units vested during the six months ended June 30, 2018 and June 30, 2017 was $2,468 and $1,134, respectively. The following represents the nonvested phantom units and their corresponding weighted average grant date fair value:


	Number of Units		Weighted Average Grant Date Fair Value per Unit		Number of Units		Weighted Average Grant Date Fair Value per Unit
Nonvested at December 31, 2017	401,409		$	14.87	401,409		$	14.87
Granted	18,807		$	15.95	18,807		$	15.95
Vested	(174,005	)	$	13.90	(176,643	)	$	13.97
Forfeited	(5,276	)	$	15.37	(9,928	)	$	15.27
Nonvested at March 31, 2018	240,935		$	15.65
Nonvested at June 30, 2018					233,645		$	15.62

NOTE 14—FINANCIAL INFORMATION FOR SUBSIDIARY GUARANTORS AND FINANCE SUBSIDIARY OF POSSIBLE FUTURE PUBLIC DEBT:

The Partnership filed a Registration Statement on Form S-3 (333-215962) with the SEC on March 10, 2017, which was declared effective by the SEC on March 14, 2017, ~~with the SEC~~ to register the offer and sale of various securities including debt securities. The registration statement registers guarantees of debt securities by CONSOL Operating and CONSOL Thermal Holdings (“Subsidiary Guarantors”). The Subsidiary Guarantors are 100% owned by the Partnership and any guarantees by the Subsidiary Guarantors will be full and unconditional and joint and several. In addition, the registration statement also includes

CONSOL Coal Finance, which was formed for the sole purpose of co-issuing future debt securities with the Partnership. CONSOL Coal Finance is wholly owned by the Partnership, has no assets or any liabilities and its activities will be limited to co-issuing debt securities and engaging in other activities incidental thereto. The Partnership does not have any other subsidiaries other than the Subsidiary Guarantors and CONSOL Coal Finance. In addition, the Partnership has no assets or operations independent of the Subsidiary Guarantors, and there are no significant restrictions upon the ability of the Subsidiary Guarantors to distribute funds to the Partnership by dividend or loan other than under the Credit Agreement described in these notes. In the event that more than one of the Subsidiary Guarantors guarantee public debt securities of the Partnership in the future, those guarantees will be full and unconditional and will constitute the joint and several obligations of the Subsidiary Guarantors. None of the assets of the Partnership, the Subsidiary Guarantors or CONSOL Coal Finance represent restricted net assets pursuant to Rule 4-08(e)(3) of Regulation S-X under the Securities Act of 1933, as amended.

NOTE 15—SUBSEQUENT EVENTS:

On ~~April~~July 25, 2018, the Board of Directors of our general partner declared a cash distribution to the Partnership’s unitholders for the quarter ended ~~March 31,~~June 30, 2018 of $0.5125 per common and subordinated unit. The cash distribution will be paid on ~~May~~August 15, 2018 to the unitholders of record at the close of business on ~~May~~August 8, 2018.

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Unless otherwise indicated, the following discussion and analysis of the financial condition and results of operations of our Partnership reflect a 25% undivided interest in the assets, liabilities and results of operations of the Pennsylvania Mining Complex. As used in the following discussion and analysis of the financial condition and results of operations of our Partnership, the terms “we,” “our,” “us,” or like terms refer to the Partnership with respect to its 25% undivided interest in the Pennsylvania Mining Complex’s combined assets, liabilities revenues and costs. All amounts except per unit or per ton are displayed in thousands.

Overview

We are a master limited partnership formed by CNX in 2015 to manage and further develop all of its active coal operations in Pennsylvania. Our primary strategy for growing our business and increasing distributions to our unitholders is to increase operating efficiencies to maximize realizations and make acquisitions that increase our distributable cash flow. The primary component of our growth strategy is based upon our expectation of future divestitures by CONSOL Energy to us of portions of its retained 75% undivided interest in the Pennsylvania Mining Complex. At ~~March 31,~~June 30, 2018, the Partnership’s assets include a 25% undivided interest in, and operational control over, CONSOL Energy’s Pennsylvania Mining Complex, which consists of three underground mines and related infrastructure that produce high-Btu bituminous ~~thermal~~ coal that is sold primarily to electric utilities in the eastern United States. We believe that our ability to efficiently produce and deliver large volumes of high-quality coal at competitive prices, the strategic location of our mines, and the industry experience of our management team position us as a leading producer of high-Btu thermal coal in the Northern Appalachian Basin and the eastern United States.

On September 30, 2016, the Partnership and its wholly owned subsidiary, CONSOL Thermal Holdings, entered into a Contribution Agreement (the “Contribution Agreement”) with CNX, CPCC and Conrhein ~~and together with CPCC, (the~~(collectively, the “Contributing Parties”), under which CONSOL Thermal Holdings completed the PA Mining Acquisition to acquire an undivided 6.25% of the Contributing Parties’ right, title and interest in and to the Pennsylvania Mining Complex (which represents an aggregate 5% undivided interest in and to the Pennsylvania Mining Complex). This acquisition was a transaction between entities under common control; therefore, the Partnership recorded the assets and liabilities of the acquired 5% of Pennsylvania Mining Complex at their carrying amounts on CNX’s financial statements at the date of the transaction. The difference between CNX’s net carrying amount and the total consideration paid to CNX was recorded as a capital transaction with CNX, which resulted in a reduction in partners’ capital. The Partnership recast its historical consolidated financial statements to retrospectively reflect ownership of the additional 5% (a total 25%) interest in the Pennsylvania Mining Complex as if the business was owned for all periods presented; however, the consolidated financial statements are not necessarily indicative of the results of operations that would have occurred if the Partnership had owned it during the periods reported.

How We Evaluate Our Operations

Our management team uses a variety of financial and operating metrics to analyze our performance. These metrics are significant factors in assessing our operating results and profitability. The metrics include: (i) coal production, sales volumes and average revenue per ton; (ii) cost of coal sold, a non-GAAP financial measure; (iii) cash cost of coal sold, a non-GAAP financial measure; (iv) average cash margin per ton, an operating ratio derived from non-GAAP financial measures; (v) adjusted EBITDA, a non-GAAP financial measure; and (vi) distributable cash flow, a non-GAAP financial measure.

Cost of coal sold, cash cost of coal sold, average cash margin per ton, adjusted EBITDA and distributable cash flow normalize the volatility contained within comparable GAAP measures by adjusting certain non-operating or non-cash

transactions. Each of these non-GAAP metrics are used as supplemental financial measures by management and by external users of our financial statements, such as investors, industry analysts, lenders and ratings agencies, to assess:

• our operating performance as compared to the operating performance of other companies in the coal industry, without regard to financing methods, historical cost basis or capital structure;

• the ability of our assets to generate sufficient cash flow to make distributions to our partners;

• our ability to incur and service debt and fund capital expenditures;

• the viability of acquisitions and other capital expenditure projects and the returns on investment of various investment opportunities; and

• the attractiveness of capital projects and acquisitions and the overall rates of return on alternative investment opportunities.

~~The~~These non-GAAP financial measures should not be considered an alternative to total costs, net income, operating cash flow, or any other measure of financial performance or liquidity presented in accordance with GAAP. These measures exclude some, but not all, items that affect net income or net cash, and these measures and the way we calculate them may vary from those of other companies. As a result, the items presented below may not be comparable to similarly titled measures of other companies.

Reconciliation of Non-GAAP Financial Measures

We evaluate our cost of coal sold and cash cost of coal sold on a cost per ton basis. Our cost of coal sold per ton represents our costs of coal sold divided by the tons of coal we sell. We define cost of coal sold as operating and other production costs related to produced tons sold, along with changes in coal inventory, both in volumes and carrying values. The cost of coal sold per ton includes items such as direct operating costs, royalty and production taxes, direct administration, and depreciation, depletion and amortization ~~costs.~~costs on production assets. Our costs exclude any indirect costs such as selling, general and administrative costs, freight expenses, interest expenses and other costs not directly attributable to the production of coal. The GAAP measure most directly comparable to cost of coal sold is total costs. The cash cost of coal sold includes cost of coal sold less depreciation, depletion and amortization cost on production assets. The GAAP measure most directly comparable to cash cost of coal sold is total costs.

We define average cash margin per ton as average coal revenue per ton, net of average cash cost of coal sold per ton. The GAAP measure most directly comparable to average cash margin per ton sold is total coal revenue.

We define adjusted EBITDA as (i) net income (loss) before net interest expense, depreciation, depletion and amortization, as adjusted for (ii) certain non-cash items, such as long-term incentive awards including phantom units under the CONSOL Coal Resources LP 2015 Long-Term Incentive Plan (“~~Unit Based~~Unit-Based Compensation”). The GAAP measure most directly comparable to adjusted EBITDA is net income.

We define distributable cash flow as (i) net income (loss) before net interest expense, depreciation, depletion and amortization, as adjusted for (ii) certain non-cash items, such as ~~Unit Based~~Unit-Based Compensation, less net cash interest paid and estimated maintenance capital expenditures, which is defined as those forecasted average capital expenditures required to maintain, over the long-term, the operating capacity of our capital assets. These estimated capital expenditures do not reflect the actual cash capital incurred in the period presented. Distributable cash flow will not reflect changes in working capital balances. The GAAP measures most directly comparable to distributable cash flow are net income and net cash provided by operating activities. We define distribution coverage ratio as a ratio of the distributable cash flow to the distributions, which is the $0.5125 per quarter distribution for all limited partner units, including common and subordinated units, issued for the periods presented.

The following table presents a reconciliation of cash cost of coal sold to total costs, the most directly comparable GAAP financial measure, on a historical basis for each of the periods indicated (in thousands).


	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017			2018			2017
Total Costs	$	72,544		$	69,214		$	78,681		$	70,998		$	151,225		$	140,212
Freight Expense	(4,472		)	(3,070		)	(4,361		)	(4,441		)	(8,833		)	(7,511		)
Selling, General and Administrative Expenses	(3,020		)	(3,283		)	(3,341		)	(3,652		)	(6,361		)	(6,935		)
Interest Expense	(1,951		)	(2,457		)	(1,784		)	(2,396		)	(3,735		)	(4,853		)
Other Costs (Non-Production)	(4,026		)	(1,493		)	(4,239		)	(934		)	(8,265		)	(2,427		)
Depreciation, Depletion and Amortization (Non-Production)	(540		)	(550		)	(543		)	(550		)	(1,083		)	(1,100		)
Cost of Coal Sold	$	58,535		$	58,361		$	64,413		$	59,025		$	122,948		$	117,386
Depreciation, Depletion and Amortization (Production)	$	(10,274	)	$	(9,971	)	(11,353		)	(9,727		)	$	(21,627	)	$	(19,698	)
Cash Cost of Coal Sold	$	48,261		$	48,390		$	53,060		$	49,298		$	101,321		$	97,688

The following table presents a reconciliation of average cash margin per ton to coal revenue, the most directly comparable GAAP financial measure for each of the periods indicated (in thousands, except per ton information).


	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017			2018			2017
Coal Revenue	$	87,752		$	79,112		$	92,674		$	75,927		$	180,426		$	155,039
Operating and Other Costs	52,287			49,883			57,299			50,232			109,586			100,115
Less: Other Costs (Non-Production)	(4,026		)	(1,493		)	(4,239		)	(934		)	(8,265		)	(2,427		)
Cash Cost of Coal Sold	48,261			48,390			53,060			49,298			101,321			97,688
Depreciation, Depletion and Amortization	10,814			10,521			11,896			10,277			22,710			20,798
Less: Depreciation, Depletion and Amortization (Non-Production)	(540		)	(550		)	(543		)	(550		)	(1,083		)	(1,100		)
Cost of Coal Sold	$	58,535		$	58,361		$	64,413		$	59,025		$	122,948		$	117,386
Total Tons Sold	1,656			1,690			1,958			1,697			3,614			3,387
Average Revenue Per Ton Sold	$	52.98		$	46.80		$	47.34		$	44.75		$	49.93		$	45.77
Average Cash Cost Per Ton Sold	29.21			28.75			26.99			29.08			28.01			28.91
Depreciation, Depletion and Amortization Per Ton Sold	6.13			5.77			5.91			5.71			6.02			5.74
Average Cost Per Ton Sold	35.34			34.52			32.90			34.79			34.03			34.65
Average Margin Per Ton Sold	17.64			12.28			14.44			9.96			15.90			11.12
Add: Total Depreciation, Depletion and Amortization Costs Per Ton Sold	6.13			5.77			5.91			5.71			6.02			5.74
Average Cash Margin Per Ton Sold	$	23.77		$	18.05		$	20.35		$	15.67		$	21.92		$	16.86

The following table presents a reconciliation of adjusted EBITDA to net income, the most directly comparable GAAP financial measure, on a historical basis for each of the periods indicated. The table also presents a reconciliation of distributable cash flow to net income and operating cash flows, the most directly comparable GAAP financial measures, on a historical basis for each of the periods indicated (in thousands).


	Three Months Ended March 31,				Three Months Ended June 30,						Six Months Ended June 30,
	2018		2017		2018			2017			2018			2017
Net Income	$	21,957	$	14,066	$	19,376		$	11,474		$	41,333		$	25,540
Plus:
Interest Expense	1,951		2,457		1,784			2,396			3,735			4,853
Depreciation, Depletion and Amortization	10,814		10,521		11,896			10,277			22,710			20,798
Unit Based Compensation	359		866
Unit-Based Compensation					508			841			867			1,707
Adjusted EBITDA	$	35,081	$	27,910	$	33,564		$	24,988		$	68,645		$	52,898
Less:
Cash Interest	828		2,161		2,130			2,539			2,958			4,700
Distributions to Preferred Units¹	—		1,851		—			1,851			—			3,702
Estimated Maintenance Capital Expenditures	8,963		8,989		9,085			8,976			18,048			17,965
Distributable Cash Flow	$	25,290	$	14,909	$	22,349		$	11,622		$	47,639		$	26,531

Net Cash Provided by Operating Activities	$	29,264	$	17,662	$	48,949		$	23,092		$	78,213		$	40,754
Plus:
Interest Expense	1,951		2,457		1,784			2,396			3,735			4,853
Other, Including Working Capital	3,866		7,791		(17,169		)	(500		)	(13,303		)	7,291
Adjusted EBITDA	$	35,081	$	27,910	$	33,564		$	24,988		$	68,645		$	52,898
Less:
Cash Interest	828		2,161		2,130			2,539			2,958			4,700
Distributions to Preferred Units¹	—		1,851		—			1,851			—			3,702
Estimated Maintenance Capital Expenditures	8,963		8,989		9,085			8,976			18,048			17,965
Distributable Cash Flow	$	25,290	$	14,909	$	22,349		$	11,622		$	47,639		$	26,531
Minimum Quarterly Distributions	$	14,346	$	12,228	$	14,348		$	12,228		$	28,694		$	24,456
Distribution Coverage Ratio	$	1.8	$	1.2	$	1.6		$	1.0		$	1.7		$	1.1

¹Distributions to Preferred Units represents income attributable to preferred units prior to conversion.

Results of Operations

Three Months Ended ~~March 31,~~June 30, 2018 Compared with the Three Months Ended ~~March 31,~~June 30, 2017

Total net income was ~~$21,957~~$19,376 for the three months ended ~~March 31,~~June 30, 2018 compared to ~~$14,066~~$11,474 for the three months ended ~~March 31,~~June 30, 2017. Our results of operations for each of these periods are presented in the table below. Variances are discussed following the table.


	For the Three Months Ended							For the Three Months Ended
	March 31,							June 30,
	2018		2017		Variance			2018		2017		Variance
	(in thousands)							(in thousands)
Revenue:
Coal Revenue	$	87,752	$	79,112	$	8,640		$	92,674	$	75,927	$	16,747
Freight Revenue	4,472		3,070		1,402			4,361		4,441		(80		)
Other Income	2,277		1,098		1,179			1,022		2,104		(1,082		)
Total Revenue and Other Income	94,501		83,280		11,221			98,057		82,472		15,585
Cost of Coal Sold:
Operating Costs	48,261		48,390		(129		)	53,060		49,298		3,762
Depreciation, Depletion and Amortization	10,274		9,971		303			11,353		9,727		1,626
Total Cost of Coal Sold	58,535		58,361		174			64,413		59,025		5,388
Other Costs:
Other Costs	4,026		1,493		2,533			4,239		934		3,305
Depreciation, Depletion and Amortization	540		550		(10		)	543		550		(7		)
Total Other Costs	4,566		2,043		2,523			4,782		1,484		3,298
Freight Expense	4,472		3,070		1,402			4,361		4,441		(80		)
Selling, General and Administrative Expenses	3,020		3,283		(263		)	3,341		3,652		(311		)
Interest Expense	1,951		2,457		(506		)	1,784		2,396		(612		)
Total Costs	72,544		69,214		3,330			78,681		70,998		7,683
Net Income	$	21,957	$	14,066	$	7,891		$	19,376	$	11,474	$	7,902
Adjusted EBITDA	$	35,081	$	27,910	$	7,171		$	33,564	$	24,988	$	8,576
Distributable Cash Flow	$	25,290	$	14,909	$	10,381		$	22,349	$	11,622	$	10,727
Distribution Coverage Ratio	1.8		1.2		0.6			1.6		1.0		0.6

Coal Production

The table below presents total tons produced from the Pennsylvania Mining Complex on our 25% undivided interest basis for the periods indicated:


	Three Months Ended March 31,				Three Months Ended June 30,
Mine	2018	2017	Variance		2018	2017	Variance
Bailey	953	774	179		863	785	78
Enlow Fork	504	675	(171	)	697	631	66
Harvey	218	278	(60	)	361	287	74
Total	1,675	1,727	(52	)	1,921	1,703	218

Coal production was ~~1,675~~1,921 tons for the three months ended ~~March 31,~~June 30, 2018 compared to ~~1,727~~1,703 tons for the three months ended ~~March 31,~~June 30, 2017. The Partnership’s coal production ~~decreased 52~~increased 218 tons due to adverse geological conditions at the Enlow Fork mine and operational delays associated with a longwall move at the Harvey Mine. The decrease was offset, in part, by an increase in production at the Bailey Mine to satisfy market demand.

Coal Operations

Coal revenue and cost components on a per unit basis for the three months ended ~~March 31,~~June 30, 2018 and 2017 are detailed in the table below. Our operations also include various costs such as selling, general and administrative, freight and other costs not included in our unit cost analysis because these costs are not directly associated with coal production.


	Three Months Ended March 31,							Three Months Ended June 30,
	2018		2017		Variance			2018		2017		Variance
Total Tons Sold (in thousands)	1,656		1,690		(34		)	1,958		1,697		261
Average Revenue Per Ton Sold	$	52.98	$	46.80	$	6.18		$	47.34	$	44.75	$	2.59

Average Cash Cost Per Ton Sold	$	29.21	$	28.75	$	0.46		$	26.99	$	29.08	$	(2.09	)
Depreciation, Depletion and Amortization Per Ton Sold (Non-Cash Cost)	6.13		5.77		0.36			5.91		5.71		0.2
Total Costs Per Ton Sold	$	35.34	$	34.52	$	0.82		$	32.90	$	34.79	$	(1.89	)
Average Margin Per Ton Sold	$	17.64	$	12.28	$	5.36		$	14.44	$	9.96	$	4.48
Add: Depreciation, Depletion and Amortization Costs Per Ton Sold	6.13		5.77		0.36			5.91		5.71		0.20
Average Cash Margin Per Ton Sold (1)	$	23.77	$	18.05	$	5.72		$	20.35	$	15.67	$	4.68

(1) Average cash margin per ton is an operating ratio derived from non-GAAP measures. See “– How We Evaluate Our Operations – Reconciliation of Non-GAAP Financial Measures” for a reconciliation of non-GAAP measures to the most directly comparable GAAP measures.

Revenue and Other Income

Coal revenue was ~~$87,752~~$92,674 for the three months ended ~~March 31,~~June 30, 2018 compared to ~~$79,112~~$75,927 for the three months ended ~~March 31,~~June 30, 2017. The ~~$8,640~~$16,747 increase was attributable to a ~~$6.18~~$2.59 per ton higher average revenue ~~partially offset by~~and a 34261 ton ~~decrease~~increase in tons sold. The ~~decrease~~increase in tons sold was primarily driven by ~~weather-related challenges that affected rail~~improved production from all mining operations across the Pennsylvania Mining Complex, which was supported by strong demand from our customers in both the domestic and ~~port logistics and limited further upside to shipment volumes.~~export markets. The higher average sales price per ton sold in the 2018 period was primarily driven by improved pricing under our netback contracts, which resulted from stronger PJM West power prices during the quarter as compared to the year-ago ~~quarter. Our revenue per ton sold also benefited from~~quarter, and by improved ~~pricing under our other (non-netback) domestic contracts and from continued strength~~realizations in the export ~~market~~s.markets. PJM West day-ahead power prices averaged 19% higher in the three months ended June 30, 2018 compared to the three months ended June 30, 2017, and prompt month prices for the API 2 index (the benchmark price reference for coal imported into northwest Europe) averaged 17% higher than during the year-ago quarter.

Freight revenue, which is completely offset in freight expense, is the amount billed to customers based on the weight of coal shipped and negotiated freight rates for rail transportation. Freight revenue ~~increased $1,402~~decreased $80 in the period-to-period comparison due to ~~increased~~decreased shipments to customers where we were contractually obligated to provide transportation services.

Other income is comprised of income generated by the Partnership not in the ordinary course of business. Other income was ~~$2,277~~$1,022 for the three months ended ~~March 31,~~June 30, 2018, compared to ~~$1,098~~$2,104 for the three months ended ~~March 31,~~June 30, 2017. The

$~~1,179~~1,082 period-to-period ~~increase~~decrease was primarily due to a $1,403 gain that occurred during the three months ended June 30, 2017 related to an agreement to avoid mining approximately 85 acres of reserves. This decrease was offset, in part, by an increase of ~~$1,302~~$295 in sales of externally purchased coal for blending purposes ~~only and a $76 gain from the sale of equipment during the three months ended March 31, 2018. These increases were partially offset by a $210 decrease in coal royalty income.~~only. The remaining variance is attributable to various transactions that occurred throughout both periods, none of which are individually material.

Cost of Coal Sold

Cost of coal sold is comprised of operating costs related to produced tons sold, along with changes in both volumes and carrying values of coal inventory. The costs of coal sold per ton include items such as direct operating costs, royalty and production taxes, direct administration expenses, and depreciation, depletion, and amortization ~~costs.~~costs on production assets. Total cost of coal sold was ~~$58,535~~$64,413 for the three months ended ~~March 31,~~June 30, 2018, or ~~$174~~$5,388 higher than the ~~$58,361~~$59,025 for the three months ended ~~March 31,~~June 30, 2017. Total costs per ton sold were ~~$35.34~~$32.90 per ton for the three months ended ~~March 31,~~June 30, 2018 compared to ~~$34.52~~$34.79 per ton for the three months ended ~~March 31,~~June 30, 2017. The increase in the total cost of coal sold was primarily driven by ~~higher royalty and~~an increase in production-related costs as more coal was mined to meet market demand, as well as an increase in mine development activity. However, the increased production ~~taxes due to a $6.18~~resulted in an overall decrease in the total cost per ton ~~higher average sales price.~~sold.

Total Other Costs

Total other costs is comprised of various costs that are not allocated to each individual mine and therefore are not included in unit costs. Total other costs increased ~~$2,523~~$3,298 for the three months ended ~~March 31,~~June 30, 2018 compared to the three months ended ~~March 31,~~June 30, 2017. This was primarily ~~due~~attributable to ~~a $1,330~~an increase in ~~the cost of~~current quarter costs related to externally purchased coal for blending purposes only, discretionary employee benefit expense, and ~~a $1,203 increase in~~ demurrage charges. ~~The remaining variance is attributable to various transactions that occurred throughout both periods, none of which are individually material.~~

Selling, General, and Administrative Expense

Selling, general, and administrative expenses remained materially consistent in the period-to-period comparison.

Interest Expense

Interest expense for the three months ended ~~March 31,~~June 30, 2018 was ~~$1,951,~~$1,784, which primarily relates to obligations under our Affiliated Company Credit Agreement. For the three months ended ~~March 31,~~June 30, 2017, ~~$2,457~~$2,396 of interest expense was incurred, primarily on the PNC Revolving Credit Facility. The decrease was primarily attributable to a lower average daily balance outstanding under the Affiliated Company Credit Agreement than had been drawn on the PNC Revolving Credit Facility in the previous ~~year, offset partially by a higher interest rate on the Affiliated Company Credit Agreement.~~year. For a detailed explanation of our liquidity and financing arrangements, please read Item 2. “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Capital Resources and Liquidity.”

Adjusted EBITDA

Adjusted EBITDA was ~~$35,081~~$33,564 for the three months ended ~~March 31,~~June 30, 2018 compared to ~~$27,910~~$24,988 for the three months ended ~~March 31,~~June 30, 2017. The ~~$7,171~~$8,576 increase was primarily a result of a ~~$6.18~~$2.59 per ton increase in the average sales price ~~offset in part, by~~and a ~~$0.46~~$2.09 per ton ~~increase~~decrease in the cash cost of coal sold, resulting in a ~~$9,472~~$9,163 increase in Adjusted EBITDA. ~~This~~In addition, an increase ~~was offset in part, by a 34 ton decrease in~~of 261 tons sold ~~resulting~~resulted in a ~~$614 decrease~~$4,090 increase in Adjusted EBITDA. The remaining variance is due to changes in other income and other costs as discussed above and various other transactions that occurred throughout both periods, none of which are individually material.

Distributable Cash Flow

Distributable cash flow was ~~$25,290~~$22,349 for the three months ended ~~March 31,~~June 30, 2018 compared to ~~$14,909~~$11,622 for the three months ended ~~March 31,~~June 30, 2017. The ~~$10,381~~$10,727 increase was primarily attributable to a ~~$7,171~~$8,576 increase in Adjusted EBITDA as discussed above, a $1,851 decrease in distributions to holders of the Class A Preferred Units, which were all converted to common units on October 2, 2017, and a ~~$1,333~~$409 decrease in cash interest paid, ~~and~~offset, in part, by a ~~$26 decrease~~$109 increase in Estimated Maintenance Capital Expenditures.

Six Months Ended June 30, 2018 Compared with the Six Months Ended June 30, 2017

Total net income was $41,333 for the six months ended June 30, 2018 compared to $25,540 for the six months ended June 30, 2017. Our results of operations for each of these periods are presented in the table below. Variances are discussed following the table.



	For the Six Months Ended
	June 30,
	2018		2017		Variance
	(in thousands)
Revenue:
Coal Revenue	$	180,426	$	155,039	25,387
Freight Revenue	8,833		7,511		1,322
Other Income	3,299		3,202		97
Total Revenue and Other Income	192,558		165,752		26,806
Cost of Coal Sold:
Operating Costs	101,321		97,688		3,633
Depreciation, Depletion and Amortization	21,627		19,698		1,929
Total Cost of Coal Sold	122,948		117,386		5,562
Other Costs:
Other Costs	8,265		2,427		5,838
Depreciation, Depletion and Amortization	1,083		1,100		(17		)
Total Other Costs	9,348		3,527		5,821
Freight Expense	8,833		7,511		1,322
Selling, General and Administrative Expenses	6,361		6,935		(574		)
Interest Expense	3,735		4,853		(1,118		)
Total Costs	151,225		140,212		11,013
Net Income	$	41,333	$	25,540	$	15,793
Adjusted EBITDA	$	68,645	$	52,898	$	15,747
Distributable Cash Flow	$	47,639	$	26,531	$	21,108
Distribution Coverage Ratio	1.7		1.1		0.6

Coal Production

The table below presents total tons produced from the Pennsylvania Mining Complex on our 25% undivided interest basis for the periods indicated:



	Six Months Ended June 30,
Mine	2018	2017	Variance
Bailey	1,816	1,559	257
Enlow Fork	1,201	1,306	(105	)
Harvey	579	565	14
Total	3,596	3,430	166

Coal production was 3,596 tons for the six months ended June 30, 2018 compared to 3,430 tons for the six months ended June 30, 2017. The Partnership’s coal production increased 166 tons to satisfy demand, offset, in part, by adverse geological conditions at the Enlow Fork mine.

Coal Operations

Coal revenue and cost components on a per unit basis for the six months ended June 30, 2018 and 2017 are detailed in the table below. Our operations also include various costs such as selling, general and administrative, freight and other costs not included in our unit cost analysis because these costs are not directly associated with coal production.



	Six Months Ended June 30,
	2018		2017		Variance
Total Tons Sold (in thousands)	3,614		3,387		227
Average Revenue Per Ton Sold	$	49.93	$	45.77	$	4.16

Average Cash Cost Per Ton Sold	$	28.01	$	28.91	$	(0.90	)
Depreciation, Depletion and Amortization Per Ton Sold (Non-Cash Cost)	6.02		5.74		0.28
Total Costs Per Ton Sold	$	34.03	$	34.65	$	(0.62	)
Average Margin Per Ton Sold	$	15.90	$	11.12	$	4.78
Add: Depreciation, Depletion and Amortization Costs Per Ton Sold	6.02		5.74		0.28
Average Cash Margin Per Ton Sold (1)	$	21.92	$	16.86	$	5.06

Revenue and Other Income

Coal revenue was $180,426 for the six months ended June 30, 2018 compared to $155,039 for the six months ended June 30, 2017. The $25,387 increase was attributable to a $4.16 per ton higher average revenue and a 227 increase in tons sold. The increase in tons sold was primarily driven by improved production from our Bailey Mine, which was supported by strong demand from our customers in both the domestic and export markets. The higher average sales price per ton sold in the 2018 period was primarily driven by improved pricing under our netback contracts, which resulted from stronger PJM West power prices during the first half of 2018 as compared to the first half of 2017, and by improved realizations in the export markets. PJM West day-ahead power prices averaged 35% higher for the six months ended June 30, 2018 compared to the six months ended June 30, 2017, and prompt month prices for the API 2 index (the benchmark price reference for coal imported into northwest Europe) averaged 11% higher than during the year-ago period.

Freight revenue, which is completely offset in freight expense, is the amount billed to customers based on the weight of coal shipped and negotiated freight rates for rail transportation. Freight revenue increased $1,322 in the period-to-period comparison due to increased shipments to customers where we were contractually obligated to provide transportation services.

Other income is comprised of income generated by the Partnership not in the ordinary course of business. Other income was $3,299 for the six months ended June 30, 2018, compared to $3,202 for the six months ended June 30, 2017. The $97 period-to-period increase was primarily due to an increase of $1,597 in sales of externally purchased coal for blending purposes only, offset partially by a $1,403 gain that occurred during the six months ended June 30, 2017 related to an agreement to avoid mining approximately 85 acres of reserves. The remaining variance is attributable to various transactions that occurred throughout both periods, none of which are individually material.

Cost of Coal Sold

Cost of coal sold is comprised of operating costs related to produced tons sold, along with changes in both volumes and carrying values of coal inventory. The costs of coal sold per ton include items such as direct operating costs, royalty and production taxes, direct administration expenses, and depreciation, depletion, and amortization costs on production assets. Total cost of coal sold was $122,948 for the six months ended June 30, 2018, or $5,562 higher than the $117,386 for the six months ended June 30, 2017. Total costs per ton sold were $34.03 per ton for the six months ended June 30, 2018 compared to $34.65 per ton for the six months ended June 30, 2017. The increase in the total cost of coal sold was primarily driven by an increase in production-related costs as more coal was mined to meet market demand, as well as an increase in mine development activity. However, the increased production resulted in an overall decrease in the total cost per ton sold.

Total Other Costs

Total other costs is comprised of various costs that are not allocated to each individual mine and therefore are not included in unit costs. Total other costs increased $5,821 for the six months ended June 30, 2018 compared to the six months ended June 30, 2017. The increase was primarily attributable to an increase in current year costs related to externally purchased coal for blending purposes only, discretionary employee benefit expense, and demurrage charges.

Selling, General, and Administrative Expense

Selling, general, and administrative expenses remained materially consistent in the period-to-period comparison.

Interest Expense

Interest expense for the six months ended June 30, 2018 was $3,735, which primarily relates to obligations under our Affiliated Company Credit Agreement. For the six months ended June 30, 2017, $4,853 of interest expense was incurred, primarily on the PNC Revolving Credit Facility. The decrease was primarily attributable to a lower average daily balance outstanding under the Affiliated Company Credit Agreement than had been drawn on the PNC Revolving Credit Facility in the previous year. For a detailed explanation of our liquidity and financing arrangements, please read Item 2. “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Capital Resources and Liquidity.”

Adjusted EBITDA

Adjusted EBITDA was $68,645 for the six months ended June 30, 2018 compared to $52,898 for the six months ended June 30, 2017. The $15,747 increase was primarily a result of a $4.16 per ton increase in the average sales price and a $0.90 per ton decrease in the cash cost of coal sold, resulting in a $18,287 increase in Adjusted EBITDA. In addition, an increase of 227 tons sold resulted in a $3,827 increase in Adjusted EBITDA. The remaining variance is due to changes in other income and other costs as discussed above and various other transactions that occurred throughout both periods, none of which are individually material.

Distributable Cash Flow

Distributable cash flow was $47,639 for the six months ended June 30, 2018 compared to $26,531 for the six months ended June 30, 2017. The $21,108 increase was primarily attributable to a $15,747 increase in Adjusted EBITDA as discussed above, a $3,702 decrease in distributions to holders of the Class A Preferred Units, which were all converted to common units on October 2, 2017, and a $1,742 decrease in cash interest paid, offset, in part, by a $83 increase in Estimated Maintenance Capital Expenditures.

Capital Resources and Liquidity

Liquidity and Financing Arrangements

We expect our ongoing sources of liquidity to include cash generated from operations, borrowings under our Affiliated Company Credit Agreement, and, if necessary, the issuance of additional equity or debt securities. We believe that cash generated from these sources will be sufficient to meet our short-term working capital requirements and our long-term capital expenditure requirements and to make quarterly cash distributions as declared by the board of directors of our general partner. The Partnership filed a universal shelf registration statement on Form S-3 (333-215962) with the SEC on March 10, 2017, ~~with the SEC,~~ which was declared effective by the SEC on March 14, 2017, for an aggregate amount of $750,000 to provide the Partnership with additional flexibility to access capital markets quickly.

We expect the cash flow generated from operations in 2018 to be improved compared to ~~2017. We~~2017, as we expect strong demand from the export and domestic thermal ~~domestic~~ markets. InAdditionally, in the first quarter of 2018, we took advantage of a strong leasing market and bought out longwall shields, terminating the operating leases and refinancing them as capital leases. The financing rates on the new capital leases are significantly below our weighted average cost of capital, and the transactions are immediately accretive to our cash flows. In aggregate, we expect an approximate $2,500 reduction in 2018 cash spending as a result of these refinancings. The financing charges on these capital leases are fixed and will insulate us from future increases in interest rates. Furthermore, through consistent cost control measures, we expect to provide adequate cash flows to meet our maintenance capital requirements. We started the ~~course~~coarse refuse disposal area project in 2017, which is expected to continue through 2021. Our 2018 capital needs are expected to be between $31,000 to $36,000, which is increased from 2017 levels due to additional expected capital expenditures related to the refuse disposal area project, as well as additional equipment maintenance ~~equipment~~ costs and other purchases.

From time to time we change our exposure to various countries depending on the economics and profitability of coal sales. Given that coal markets are global, we expect, if possible, to offset any adverse impact from tariffs that may be imposed by governments in the countries in which one or more of our end users are located, by reallocating our customer base to other countries or to the domestic US markets.

We expect to provide adequate cash flows and liquidity to meet reasonable increases in the cost of supplies that are passed on from our suppliers. We will also continue to seek alternate sources of supplies and replacement material to offset any unexpected increase in the cost of supplies.

Our Partnership Agreement requires that we distribute all of our available cash to our unitholders. As a result, we expect to rely primarily upon financing under the Affiliated Company Credit Agreement and the issuance of debt and equity securities to fund our acquisitions and expansion capital expenditures, if any.

Credit Facility (PNC Revolving Credit Facility and Affiliated Company Credit Agreement)

On July 7, 2015, the Partnership, as borrower, and certain subsidiaries of the Partnership, as guarantors, entered into the PNC Revolving Credit Facility for a $400,000 revolving credit facility with PNC, as administrative agent, and other lender parties thereto. On November 28, 2017, in connection with the separation, the Partnership paid all fees and other amounts outstanding, which aggregated to $200,583, under the PNC Revolving Credit Facility and terminated the PNC Revolving Credit Facility and the related loan documents.

by the Partnership’s subsidiaries and secured by substantially all of the assets of the Partnership and its subsidiaries pursuant to the security agreement and various mortgages.

Interest on outstanding obligations under our Affiliated Company Credit Agreement accrues at a fixed rate ranging from 3.75% to 4.75% depending on the total net leverage ratio. The unused portion of our Affiliated Company Credit Agreement is subject to a commitment fee of 0.50% per annum.

As of ~~March 31,~~June 30, 2018, the Partnership had ~~$187,000 thousand~~$160,500 of borrowings outstanding under the Affiliated Company Credit Agreement, leaving ~~$88,000 thousand~~$114,500 of unused capacity. Interest on outstanding borrowings under the Affiliated Company Credit Agreement at ~~March 31,~~June 30, 2018 was accrued at a rate of ~~4.25%~~4.00%.

The Affiliated Company Credit Agreement contains certain covenants and conditions that, among other things, limit the Partnership’s ability to: (i) incur or guarantee additional debt; (ii) make cash distributions (subject to certain limited exceptions); provided that we will be able to make cash distributions of available cash to partners so long as no event of default

is continuing or would result therefrom; (iii) incur certain liens or permit them to exist; (iv) make particular investments and loans; provided that we will be able to increase our ownership percentage of our undivided interest in the Pennsylvania Mining Complex and make investments in the Pennsylvania Mining Complex in accordance with our ratable ownership; (v) enter into certain types of transactions with affiliates; (vi) merge or consolidate with another company; and (vii) transfer, sell or otherwise dispose of assets. The Partnership is also subject to covenants that require the Partnership to maintain certain financial ratios. For example, the Partnership is obligated to maintain at the end of each fiscal quarter (a) maximum first lien gross leverage ratio of 2.75 to 1.00 and (b) a maximum total net leverage ratio of 3.25 to 1.00, each of which will be calculated on a consolidated basis for the Partnership and its restricted subsidiaries at the end of each fiscal quarter. At ~~March 31,~~June 30, 2018, the Partnership was in compliance with its debt covenants with the first lien gross leverage ratio ~~was 1.77~~at 1.45 to 1.00 and the total net leverage ratio ~~was 1.77~~at 1.45 to 1.00.

Receivables Financing Agreement

On November 30, 2017, (i) CONSOL Marine Terminals LLC, formerly known as CNX Marine Terminals LLC, as an originator of receivables, (ii) CPCC, as an originator of receivables and as initial servicer of the receivables for itself and the other Originators, each a wholly owned subsidiary of CONSOL Energy, and (iii) the SPV, a Delaware special purpose entity and wholly owned subsidiary of CONSOL Energy, as buyer, entered into the Purchase and Sale Agreement. Concurrently, (i) CONSOL Thermal Holdings, as sub-originator, and (ii) CPCC, as buyer and as initial servicer of the receivables for itself and CONSOL Thermal Holdings, entered into the Sub-Originator PSA. In addition, on that date, the SPV entered into the Receivables Financing Agreement by and among (i) the SPV, as borrower, (ii) CPCC, as initial servicer, (iii) PNC, as administrative agent, LC Bank and lender, and (iv) the additional persons from time to time party thereto as lenders. Together, the Purchase and Sale Agreement, the Sub-Originator PSA and the Receivables Financing Agreement establish the primary terms and conditions of the Securitization.

Loans under the Securitization will accrue interest at a reserve-adjusted LIBOR market index rate equal to the one-month Eurodollar rate. Loans and letters of credit under the Securitization also will accrue a program fee and a letter of credit participation fee, respectively, equal to 4.00% per annum. In addition, the SPV paid certain structuring fees to PNC Capital Markets LLC and will pay other customary fees to the lenders, including a fee on unused commitments equal to 0.60% per annum.

The SPV’s assets and credit are not available to satisfy the debts and obligations owed to the creditors of CONSOL Energy, CONSOL Thermal Holdings or any of the Originators. CONSOL Thermal Holdings, the Originators and CPCC as servicer are independently liable for their own customary representations, warranties, covenants and indemnities. In addition, CONSOL Energy has guaranteed the performance of the obligations of CONSOL Thermal Holdings, the Originators and CPCC as servicer, and will guarantee the obligations of any additional originators or successor servicer that may become party to the Securitization. However, neither CONSOL Energy nor its affiliates will guarantee collectability of receivables or the creditworthiness of obligors thereunder.

The agreements comprising the Securitization ~~contains~~contain various customary representations and warranties, covenants and default provisions which provide for the termination and acceleration of the commitments and loans under the Securitization in certain circumstances including,

As of ~~March 31,~~June 30, 2018, the Partnership, through CONSOL Thermal Holdings, had sold ~~$30,772~~$22,857 of trade receivables to CPCC. The Partnership has not derecognized the receivables due to its continued involvement in the collection efforts.

The Securitization expires on August 30, 2018. CONSOL expects to renew the Securitization with PNC Bank for a three-year term.

Cash Flows


	Three Months Ended March 31,									Six Months Ended June 30,
	2018			2017			Variance			2018			2017			Variance
	(in thousands)									(in thousands)
Cash flows provided by operating activities	$	29,264		$	17,662		$	11,602		$	78,213		$	40,754		$	37,459
Cash used in investing activities	$	(4,854	)	$	(2,030	)	$	(2,824	)	$	(12,014	)	$	(3,972	)	$	(8,042	)
Cash used in financing activities	$	(25,195	)	$	(18,883	)	$	(6,312	)	$	(67,086	)	$	(39,959	)	$	(27,127	)

~~Three~~Six Months Ended ~~March 31,~~June 30, 2018 Compared with the ~~Three~~Six Months Ended ~~March 31,~~June 30, 2017:

Cash flows provided by operating activities increased ~~$11,602~~$37,459 in the ~~three~~six months ended ~~March 31,~~June 30, 2018 compared to the ~~three~~six months ended ~~March 31,~~June 30, 2017 primarily due to an increase in net income for the reasons set forth above and a change in working capital.

Cash used in investing activities increased ~~$2,824~~$8,042 in the ~~three~~six months ended ~~March 31,~~June 30, 2018 compared to the ~~three~~six months ended ~~March 31,~~June 30, 2017 as a result of increased capital expenditures of ~~$2,899, partially offset by increased~~$6,707 and decreased proceeds from the sale of assets of ~~$75.~~$1,335. The increase in capital expenditures is due to the following items:


	Three Months Ended March 31,							Six Months Ended June 30,
	2018		2017		Variance			2018		2017		Variance
	(in thousands)							(in thousands)
Refuse Storage Area	$	1,999	$	71	$	1,928		$	4,410	$	667	$	3,743
Building and Infrastructure	1,600		1,329		271			4,206		3,184		1,022
Equipment Purchases and Rebuilds	1,123		389		734			2,845		1,253		1,592
Other	207		241		(34		)	718		368		350
Total Capital Expenditures	$	4,929	$	2,030	$	2,899		$	12,179	$	5,472	$	6,707

Cash flows used in financing activities increased by ~~$6,312~~$27,127 from ~~$18,883~~$39,959 for the ~~three~~six months ended ~~March 31,~~June 30, 2017 to ~~$25,195~~$67,086 for the ~~three~~six months ended ~~March 31,~~June 30, 2018. The increase was primarily due to ~~$9,583~~$36,083 of net payments made in the ~~three~~six months ended ~~March 31,~~June 30, 2018 under the Affiliated Company Credit Agreement, which was effective as of November 28, 2017. This increase was partially offset by ~~$4,000~~$11,000 of net payments that were made on the PNC Revolving Credit Facility during the ~~three~~six months ended ~~March 31,~~June 30, 2017. There was no activity on the PNC Revolving Credit Facility during the ~~three~~six months ended ~~March 31,~~June 30, 2018 due to its termination on November 28, 2017. In addition, payments on capitalized leases increased $1,359 in the period-to-period comparison as a result of the refinancing of the longwall shields at the Bailey and Harvey mines. The remaining increase is attributable to various transactions that occurred throughout both periods, none of which were individually material.

Off-Balance Sheet Arrangements

We do not maintain off-balance sheet transactions, arrangements, obligations or other relationships with unconsolidated entities or others that have or are reasonably likely to have a material current or future effect on our financial condition,

changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources which are not disclosed in the Notes to the Unaudited Consolidated Financial Statements in this Form 10-Q.

Contractual Obligations

The following is a summary of our significant contractual obligations at ~~March 31,~~June 30, 2018 (in thousands):


	Payments Due by Year										Payments Due by Year
	Less than 1 Year		1-3 Years		3-5 Years		More than 5 Years		Total		Less than 1 Year		1-3 Years		3-5 Years		More than 5 Years		Total
Long-Term Debt	$	—	$	—	$	187,000	$	—	$	187,000	$	—	$	—	$	160,500	$	—	$	160,500
Interest on Long-Term Debt	7,948		15,895		15,233		—		39,076		6,420		12,840		10,700		—		29,960
Capital (Finance) Lease Obligations	1,818		3,764		4		—		5,586		3,412		6,958		4		—		10,374
Interest on Capital (Finance) Lease Obligations	284		231		1		—		516		426		340		1		—		767
Operating Lease Obligations	6,073		10,781		6,660		2,314		25,828		6,179		10,633		5,612		2,096		24,520
Long-Term Liabilities - Employee Related (a)	1,725		3,601		3,781		7,122		16,229		1,733		3,637		1,050		3,704		10,124
Other Long-Term Liabilities (b)	35,971		952		1,174		7,949		46,046		32,169		1,226		1,017		7,443		41,855
Total Contractual Obligations	$	53,819	$	35,224	$	213,853	$	17,385	$	320,281	$	50,339	$	35,634	$	178,884	$	13,243	$	278,100

(a) Long-term liabilities - employee related include liabilities for work-related injuries and illnesses.

(b) Other long-term liabilities include mine reclamation and closure and other long-term liability costs.

FORWARD-LOOKING STATEMENTS

We are including the following cautionary statement in this Quarterly Report on Form 10-Q to make applicable and take advantage of the safe harbor provisions of the Private Securities Litigation Reform Act of 1995 for any forward-looking statements made by, or on behalf of us. With the exception of historical matters, the matters discussed in this Quarterly Report on Form 10-Q are forward-looking statements (as defined in Section 21E of the Exchange Act) that involve risks and uncertainties that could cause actual results to differ materially from projected results. Accordingly, investors should not place undue reliance on forward-looking statements as a prediction of actual results. The forward-looking statements may include projections and estimates concerning the timing and success of specific projects and our future production, revenues, income and capital spending. When we use the words “believe,” “continue,” “intend,” “expect,” “may,” “should,” “anticipate,” “could,” “estimate,” “plan,” “predict,” “project,” “will,” or their negatives, or other similar expressions, the statements which include those words are usually forward-looking statements. When we describe strategy that involves risks or uncertainties, we are making forward-looking statements. The forward-looking statements in this Quarterly Report on Form 10-Q speak only as of the date of this Quarterly Report on Form 10-Q; we disclaim any obligation to update these statements unless required by securities law, and we caution you not to rely on them unduly. We have based these forward-looking statements on our current expectations and assumptions about future events. While our management considers these expectations and assumptions to be reasonable, they are inherently subject to significant business, economic, competitive, regulatory and other risks, contingencies and uncertainties, most of which are difficult to predict and many of which are beyond our control. These risks, contingencies and uncertainties relate to, among other matters, the following:

changes in coal prices or the costs of mining or transporting coal;

uncertainty in estimating economically recoverable coal reserves and replacement of reserves;

our ability to develop our existing coal reserves, acquire additional reserves and successfully execute our mining plans;

changes in general economic conditions, both domestically and globally;

competitive conditions within the coal industry;

changes in the consumption patterns of coal-fired power plants and steelmakers and other factors affecting the demand for coal by coal-fired power plants and steelmakers;

the availability and price of coal to the consumer compared to the price of alternative and competing fuels;

competition from the same and alternative energy sources;

energy efficiency and technology trends;

our ability to successfully implement our business plan;

the price and availability of debt and equity financing;

operating hazards and other risks incidental to coal mining;

major equipment failures and difficulties in obtaining equipment, parts and raw materials;

availability, reliability and costs of transporting coal;

adverse or abnormal geologic conditions, which may be unforeseen;

natural disasters, weather-related delays, casualty losses and other matters beyond our control;

operating in a single geographic area;

interest rates;

our reliance on a few major customers;

labor availability, relations and other workforce factors;

defaults by CONSOL Energy under our operating agreement, employee services agreement and Affiliated Company Credit Agreement;

restrictions in our Affiliated Company Credit Agreement that may adversely affect our business;

changes in our tax status;

delays in the receipt of, failure to receive or revocation of necessary governmental permits;

the effect of existing and future laws and government regulations, including the enforcement and interpretation of environmental laws thereof;

the effect of new or expanded greenhouse gas regulations;

the effects of litigation;

conflicts of interest that may cause our general partner or CONSOL Energy to favor their own interest to our detriment;

the requirement that we distribute all of our available cash; and

other factors discussed in our 2017 Annual Report on Form 10-K under “Risk Factors,” as updated by any subsequent Quarterly Reports on Forms 10-Q, which are on file at the SEC.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

For quantitative and qualitative disclosures about market risk, see Item 7A, “Quantitative and Qualitative Disclosures About Market Risk,” of our Annual Report on Form 10-K for the year ended December 31, 2017. There have been no material changes to our exposures to market risk since December 31, 2017.

ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

Under the supervision and with the participation of the management of the Partnership’s general partner, including the Chief Executive Officer and the Chief Financial Officer of the general partner, an evaluation of the effectiveness of our disclosure controls and procedures pursuant to Rules 13a-15(e) under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), was conducted as of the end of the period covered by this report. Based upon this evaluation, the Chief Executive Officer and Chief Financial Officer of the Partnership’s general partner have concluded that the Partnership’s disclosure controls and procedures were effective as of the end of the period covered by this report.

Changes in Internal Control over Financial Reporting

There were no changes in our internal control over financial reporting that occurred during the fiscal quarter ended ~~March 31,~~June 30, 2018 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II: OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

Refer to paragraph one within Part 1, Item 1. Financial Statements, “Note 10. Commitments and Contingent Liabilities,” which is incorporated herein by reference.

ITEM 1A. RISK FACTORS

~~The following risk factor~~In addition to the other information set forth in this quarterly report, you should ~~be read in conjunction with our risk~~carefully consider the factors ~~described~~discussed in “Part I - Item 1A. Risk Factors” of our 2017 Form ~~10-K.~~10-K, as updated by any subsequent Form 10-Qs. These described risks are not the only risks we face. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial also may materially adversely affect our business, financial condition and/or operating results.

~~Our business could be materially and adversely affected by cybersecurity threats.~~

Our business could be materially and adversely affected by cybersecurity threats against the Partnership and our third party vendors and suppliers, as well as potential increased costs arising from maintaining effective cybersecurity controls and insurance coverage.

The threat of a cybersecurity attack poses a material risk to the Partnership. As a publicly traded coal mining business, we rely on information technology systems, including computer software, data hosting facilities, Internet sites and other hardware and platforms, some of which are hosted by third parties, to assist in conducting our coal mining business. Our technologies systems and networks, and those of our business associates, may become the target of cybersecurity attacks, including without limitation malicious software, attempts to gain unauthorized access to data and systems, and other electronic security breaches that could lead to disruptions in critical systems and materially and adversely affect us in a variety of ways, including the following:

unauthorized access to and potential disablement of proprietary or third party software and networks required to run our coal mining machinery and our day-to-day business operations, which could result in safety hazards, accidents, loss of production and/or increased operating costs;

unauthorized access to and release of confidential coal mining data, reserves information, strategic information or other sensitive or proprietary information, which could have a material adverse effect on our reputation, our ability to market our product or compete for business in the U.S. and global coal markets;

~~unauthorized access to and release of personal identifying information of employees and vendors, which could expose us to allegations that we did not sufficiently protect that information;~~

~~a cybersecurity attack on a vendor or service provider, which could result in supply chain disruptions and could delay or halt operations;~~

~~a cybersecurity attack on third-party transportation, processing or export facilities, which could delay or prevent us from transporting and marketing our production, resulting in a loss of revenues;~~

~~a cybersecurity attack could result in increased insurance and remediation costs, or expose us to litigation arising from data breaches, accidents or work stoppages; and~~

the ongoing and increasing threat and sophistication of cybersecurity attacks and any responsive regulations or required system enhancements could result in increased operating costs and/or capital expenditures.

The occurrence of any of the above events could damage our reputation and lead to financial losses from remedial actions, loss of business or potential liability, thereby potentially materially and adversely affecting our business, financial condition, results of operations and cash flows. Certain cyber incidents may remain undetected for an extended period. At this time, we have not uncovered any active or historic material cybersecurity threat to our systems, and none of our vendors, suppliers or other third party providers have informed us of any cybersecurity threat that would materially impact our business.

Recent action and the possibility of future action on trade by U.S. and foreign governments creates uncertainty in global markets, and may adversely affect our business, financial position and results of operations.

The U.S. government has indicated its intent to alter its approach to international trade policy and in some cases to renegotiate, or potentially terminate, certain existing bilateral or multi-lateral trade agreements and treaties with foreign countries, including the North American Free Trade Agreement (“~~NAFTA”).~~

In addition, the U.S. government has recently imposed tariffs on certain foreign goods, including steel and aluminum, and has indicated a willingness to impose tariffs on imports of other products. Related to this action, certain foreign governments, including China, have instituted retaliatory tariffs on certain U.S. goods, and have indicated a willingness to impose additional tariffs on U.S. products.

At this time, it remains unclear what the U.S. administration or foreign governments will or will not do with respect to recent or future tariffs, NAFTA or other international trade agreements and policies. A trade war or other governmental action related to tariffs or international trade agreements or policies has the potential to adversely impact our business. Our suppliers could face additional costs to produce coal mining machinery and replacement parts, which costs could in turn be passed on to us. It is also possible that foreign governments could impose tariffs on imports of U.S. coal in the future, which would adversely impact our ability to compete in those markets. The uncertainties and potential future actions arising out of the current global trading climate could have an adverse material impact on demand for our products, our costs, customers, suppliers and/or the U.S. economy, the seaborne U.S. coal trade or certain sectors thereof and, could accordingly result in an adverse material impact to our business.

ITEM 4. MINE SAFETY DISCLOSURES

The information concerning mine safety violations or other regulatory matters required by Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K (17 CFR 229.104) is included in Exhibit 95 to this Quarterly Report on Form 10-Q.

ITEM 6. EXHIBITS



Exhibits	Description	Method of Filing

31.1	Certification of Chief Executive Officer pursuant to Section 302 of Sarbanes-Oxley Act of 2002	Filed herewith

31.2	Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002	Filed herewith

32.1	Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.	Filed herewith

32.2	Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.	Filed herewith

95	Mine Safety and Health Administration Safety Data.	Filed herewith

101	Interactive Data File (Form 10-Q for the quarterly period ended ~~March 31,~~June 30, 2018, furnished in XBRL).	Filed herewith

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.

Dated: ~~May 3,~~August 2, 2018



	CONSOL Coal Resources LP

	By:		CONSOL Coal Resources GP LLC, its general partner
	By:		/s/ JAMES A. BROCK
			James A. Brock
			Chief Executive Officer, Chairman of the Board and Director (Duly Authorized Officer and Principal Executive Officer)

	By:		CONSOL Coal Resources GP LLC, its general partner
	By:		/s/ DAVID M. KHANI
			David M. Khani
			Chief Financial Officer and Director (Duly Authorized Officer and Principal Financial Officer)

	By:		CONSOL Coal Resources GP LLC, its general partner
	By:		/s/ JOHN M. ROTHKA
			John M. Rothka
			Chief Accounting Officer (Duly Authorized Officer and Principal Accounting Officer)

3437



	March 31, 2018				December 31, 2017
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Affiliated Company Credit Agreement - Related Party	$	187,000	$	187,000	$	196,583	$	196,583