Alliance Resource Partners 10Q 2019 Q2 Quarterly report

00010866002020-01-01arlp:IllinoisBasinSegmentMember2019-06-30

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

For the quarterly period ended June 30, 2019

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

For the transition period from ________________to________________

Commission File No.: 0-26823

ALLIANCE RESOURCE PARTNERS, L.P.

(Exact name of registrant as specified in its charter)

Delaware

73-1564280

(State or other jurisdiction of

incorporation or organization)

(IRS Employer Identification No.)

1717 South Boulder Avenue, Suite 400, Tulsa, Oklahoma 74119

(Address of principal executive offices and zip code)

(918) 295-7600

(Registrant's telephone number, including area code)

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

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted 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 such files). [X ] Yes [ ] No

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 .☒	Accelerated Filer ☐	Non-Accelerated Filer ☐	Smaller Reporting Company ☐
Emerging Growth Company ☐

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. [ ]

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

Securities registered pursuant to Section 12(b) of the Act:


Title of each class	Trading Symbol	Name of each exchange on which registered
Common units representing limited partner interests	ARLP	NASDAQ Global Select Market

As of August 5, 2019, 128,391,191 common units are outstanding.

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TABLE OF CONTENTS

PART I

FINANCIAL INFORMATION


		Page

ITEM 1.	Financial Statements (Unaudited)
	ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES
	Condensed Consolidated Balance Sheets as of June 30, 2019 and December 31, 2018	1
	Condensed Consolidated Statements of Income for the three and six months ended June 30, 2019 and 2018	2
	Condensed Consolidated Statements of Comprehensive Income for the three and six months ended June 30, 2019 and 2018	3
	Condensed Consolidated Statements of Cash Flows for the six months ended June 30, 2019 and 2018	4
	Notes to Condensed Consolidated Financial Statements	5
	1. Organization and Presentation	5
	2. New Accounting Standards	6
	3. Acquisition	7
	4. Contingencies	8
	5. Inventories	9
	6. Leases	9
	7. Fair Value Measurements	10
	8. Long-Term Debt	11
	9. Variable Interest Entities	12
	10. Investments	14
	11. Partners' Capital	15
	12. Revenue from Contracts with Customers	18
	13. Earnings per Limited Partner Unit	19
	14. Workers' Compensation and Pneumoconiosis	20
	15. Compensation Plans	20
	16. Components of Pension Plan Net Periodic Benefit Cost	22
	17. Segment Information	22
	18. Subsequent Events	25
ITEM 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	26
ITEM 3.	Quantitative and Qualitative Disclosures about Market Risk	40
ITEM 4.	Controls and Procedures	41
	Forward-Looking Statements	42

PART II
OTHER INFORMATION

ITEM 1.	Legal Proceedings	44
ITEM 1A.	Risk Factors	44
ITEM 2.	Unregistered Sales of Equity Securities and Use of Proceeds	44
ITEM 3.	Defaults Upon Senior Securities	45
ITEM 4.	Mine Safety Disclosures	45
ITEM 5.	Other Information	45
ITEM 6.	Exhibits	46

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PART I

FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands, except unit data)

(Unaudited)


	June 30,		December 31,
	2019		2018
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	55,215	$	244,150
Trade receivables		178,128		174,914
Other receivables		628		395
Inventories, net		84,661		59,206
Advance royalties, net		1,274		1,274
Prepaid expenses and other assets		11,592		20,747
Total current assets		331,498		500,686
PROPERTY, PLANT AND EQUIPMENT:
Property, plant and equipment, at cost		3,496,144		2,925,808
Less accumulated depreciation, depletion and amortization		(1,584,513)		(1,513,450)
Total property, plant and equipment, net		1,911,631		1,412,358
OTHER ASSETS:
Advance royalties, net		52,911		42,923
Equity method investments		28,672		161,309
Equity securities		—		122,094
Goodwill		136,399		136,399
Operating lease right-of-use assets		20,421		—
Other long-term assets		21,189		18,979
Total other assets		259,592		481,704
TOTAL ASSETS	$	2,502,721	$	2,394,748

LIABILITIES AND PARTNERS' CAPITAL
CURRENT LIABILITIES:
Accounts payable	$	108,116	$	96,397
Accrued taxes other than income taxes		17,507		16,762
Accrued payroll and related expenses		42,484		43,113
Accrued interest		5,154		5,022
Workers' compensation and pneumoconiosis benefits		11,270		11,137
Current finance lease obligations		38,214		46,722
Current operating lease obligations		5,554		—
Other current liabilities		18,734		19,718
Current maturities, long-term debt, net		78,144		92,000
Total current liabilities		325,177		330,871
LONG-TERM LIABILITIES:
Long-term debt, excluding current maturities, net		467,141		564,004
Pneumoconiosis benefits		73,607		68,828
Accrued pension benefit		40,841		43,135
Workers' compensation		45,422		41,669
Asset retirement obligations		132,414		127,655
Long-term finance lease obligations		2,549		10,595
Long-term operating lease obligations		14,806		—
Other liabilities		21,285		20,304
Total long-term liabilities		798,065		876,190
Total liabilities		1,123,242		1,207,061

PARTNERS' CAPITAL:
ARLP Partners' Capital:
Limited Partners - Common Unitholders 128,391,191 and 128,095,511 units outstanding, respectively		1,417,962		1,229,268
Accumulated other comprehensive loss		(50,573)		(46,871)
Total ARLP Partners' Capital		1,367,389		1,182,397
Noncontrolling interest		12,090		5,290
Total Partners' Capital		1,379,479		1,187,687
TOTAL LIABILITIES AND PARTNERS' CAPITAL	$	2,502,721	$	2,394,748

See notes to condensed consolidated financial statements.

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ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(In thousands, except unit and per unit data)

(Unaudited)


	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2019		2018		2019		2018
SALES AND OPERATING REVENUES:
Coal sales	$	461,310	$	475,925	$	937,326	$	899,535
Oil & gas royalties		11,892		—		22,285		—
Transportation revenues		32,630		27,532		62,868		47,317
Other revenues		11,222		12,680		21,177		26,407
Total revenues		517,054		516,137		1,043,656		973,259

EXPENSES:
Operating expenses (excluding depreciation, depletion and amortization)		314,273		311,201		617,001		588,439
Transportation expenses		32,630		27,532		62,868		47,317
Outside coal purchases		5,311		68		5,311		1,442
General and administrative		19,521		17,026		37,333		33,677
Depreciation, depletion and amortization		76,913		72,150		148,052		133,998
Settlement gain		—		—		—		(80,000)
Total operating expenses		448,648		427,977		870,565		724,873

INCOME FROM OPERATIONS		68,406		88,160		173,091		248,386

Interest expense (net of interest capitalized for the three and six months ended June 30, 2019 and 2018 of $238, $296, $492 and $561, respectively)		(10,711)		(9,955)		(22,133)		(20,813)
Interest income		138		24		229		89
Equity method investment income		550		4,839		874		8,575
Equity securities income		—		3,854		12,906		7,578
Acquisition gain		—		—		177,043		—
Other expense		(13)		(542)		(142)		(1,389)
INCOME BEFORE INCOME TAXES		58,370		86,380		341,868		242,426

INCOME TAX EXPENSE (BENEFIT)		186		3		80		(7)

NET INCOME		58,184		86,377		341,788		242,433

LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTEREST		(114)		(187)		(7,290)		(335)

NET INCOME ATTRIBUTABLE TO ARLP	$	58,070	$	86,190	$	334,498	$	242,098

NET INCOME ATTRIBUTABLE TO ARLP
GENERAL PARTNER	$	—	$	—	$	—	$	1,560
LIMITED PARTNERS	$	58,070	$	86,190	$	334,498	$	240,538

EARNINGS PER LIMITED PARTNER UNIT - BASIC AND DILUTED	$	0.44	$	0.64	$	2.57	$	1.80

WEIGHTED-AVERAGE NUMBER OF UNITS OUTSTANDING – BASIC AND DILUTED		128,391,191		131,279,910		128,271,158		131,050,836

See notes to condensed consolidated financial statements.

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ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(In thousands)

(Unaudited)


	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2019		2018		2019		2018

NET INCOME	$	58,184	$	86,377	$	341,788	$	242,433

OTHER COMPREHENSIVE INCOME (LOSS):

Defined benefit pension plan
Amortization of prior service cost (1)		46		47		93		94
Amortization of net actuarial loss (1)		982		969		1,961		1,938
Total defined benefit pension plan adjustments		1,028		1,016		2,054		2,032

Pneumoconiosis benefits
Net actuarial loss		—		—		(3,465)		—
Amortization of net actuarial loss (gain) (1)		(1,146)		—		(2,291)		1
Total pneumoconiosis benefits adjustments		(1,146)		—		(5,756)		1

OTHER COMPREHENSIVE INCOME (LOSS)		(118)		1,016		(3,702)		2,033

COMPREHENSIVE INCOME		58,066		87,393		338,086		244,466

Less: Comprehensive income attributable to noncontrolling interest		(114)		(187)		(7,290)		(335)

COMPREHENSIVE INCOME ATTRIBUTABLE TO ARLP	$	57,952	$	87,206	$	330,796	$	244,131

(1)	Amortization of prior service cost and net actuarial gain or loss is included in the computation of net periodic benefit cost (see Notes 14 and 16 for additional details).

See notes to condensed consolidated financial statements.

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ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

(Unaudited)


	Six Months Ended
	June 30,
	2019		2018

CASH FLOWS FROM OPERATING ACTIVITIES	$	301,703	$	373,244

CASH FLOWS FROM INVESTING ACTIVITIES:
Property, plant and equipment:
Capital expenditures		(165,627)		(120,646)
Increase in accounts payable and accrued liabilities		4,442		2,376
Proceeds from sale of property, plant and equipment		701		477
Contributions to equity method investments		—		(11,400)
Distributions received from investments in excess of cumulative earnings		2,358		1,191
Payment for acquisition of business, net of cash acquired		(175,060)		—
Escrow payment for Wing acquisition		(10,875)		—
Cash received from redemption of equity securities		134,288		—
Net cash used in investing activities		(209,773)		(128,002)

CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings under securitization facility		118,000		112,600
Payments under securitization facility		(135,000)		(123,500)
Proceeds from equipment financing		10,000		—
Payments on equipment financing		(253)		—
Borrowings under revolving credit facilities		90,000		70,000
Payments under revolving credit facilities		(195,000)		(100,000)
Payments on finance lease obligations		(16,554)		(14,952)
Payments for purchases of units under unit repurchase program		(5,251)		(7,639)
Net settlement of withholding taxes on issuance of units in deferred compensation plans		(7,817)		(2,081)
Cash contribution by General Partner		—		41
Cash contribution by affiliated entity		—		2,142
Cash obtained in Simplification Transactions		—		1,139
Distributions paid to Partners		(138,500)		(137,443)
Other		(490)		(1,080)
Net cash used in financing activities		(280,865)		(200,773)
NET CHANGE IN CASH AND CASH EQUIVALENTS		(188,935)		44,469
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD		244,150		6,756
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$	55,215	$	51,225

SUPPLEMENTAL CASH FLOW INFORMATION:
Cash paid for interest	$	20,748	$	19,934
Cash paid for income taxes	$	—	$	34

SUPPLEMENTAL NON-CASH ACTIVITY:
Accounts payable for purchase of property, plant and equipment	$	19,027	$	18,012
Assets acquired by finance lease	$	—	$	835
Right-of-use assets acquired by operating lease	$	25,179	$	—
Market value of common units issued under deferred compensation plans before tax withholding requirements	$	17,415	$	6,142
Acquisition of business:
Fair value of assets assumed	$	484,303	$	—
Previously held equity-method investments		(307,322)		—
Cash paid, net of cash acquired		(175,060)		—
Fair value of liabilities assumed	$	1,921	$	—

See notes to condensed consolidated financial statements.

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ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1.ORGANIZATION AND PRESENTATION

Significant Relationships Referenced in Notes to Condensed Consolidated Financial Statements

●

References to "we," "us," "our" or "ARLP Partnership" mean the business and operations of Alliance Resource Partners, L.P., the parent company, as well as its consolidated subsidiaries.

●

References to "ARLP" mean Alliance Resource Partners, L.P., individually as the parent company, and not on a consolidated basis.

●

References to "MGP" mean Alliance Resource Management GP, LLC, ARLP's general partner.

●

References to "Intermediate Partnership" mean Alliance Resource Operating Partners, L.P., the intermediate partnership of Alliance Resource Partners, L.P.

●

References to "Alliance Resource Properties" mean Alliance Resource Properties, LLC, the land-holding company for the mining operations of Alliance Resource Operating Partners, L.P.

●

References to "Alliance Coal" mean Alliance Coal, LLC, the holding company for the coal mining operations of Alliance Resource Operating Partners, L.P.

Organization

ARLP is a Delaware limited partnership listed on the NASDAQ Global Select Market under the ticker symbol "ARLP." ARLP was formed in May 1999 and completed its initial public offering on August 19, 1999 when it acquired substantially all of the coal production and marketing assets of Alliance Resource Holdings, Inc., a Delaware corporation, and its subsidiaries. We are managed by our general partner, MGP, a Delaware limited liability company which holds a non-economic general partner interest in ARLP.

AllDale I & II Acquisition

On January 3, 2019 (the " AllDale Acquisition Date"), we acquired all of the limited partner interests not owned by Cavalier Minerals JV, LLC ("Cavalier Minerals") in AllDale Minerals LP ("AllDale I") and AllDale Minerals II, LP ("AllDale II", and collectively with AllDale I, "AllDale I & II") and the general partner interests in AllDale I & II (the "AllDale Acquisition"). As a result of the AllDale Acquisition and our previous investments held through Cavalier Minerals, we now control approximately 43,000 net royalty acres in premier oil & gas resource plays. The AllDale Acquisition provides us with diversified exposure to industry leading operators and is consistent with our general business strategy to pursue accretive acquisitions. See Note 3 – Acquisition for more information.

Basis of Presentation

The accompanying condensed consolidated financial statements include the accounts and operations of the ARLP Partnership and present our financial position as of June 30, 2019 and December 31, 2018, the results of our operations and comprehensive income for the three and six months ended June 30, 2019 and 2018, and the cash flows for the six months ended June 30, 2019 and 2018. All intercompany transactions and accounts have been eliminated.

These condensed consolidated financial statements and notes are prepared pursuant to the rules and regulations of the Securities and Exchange Commission for interim reporting and do not include all of the information normally included with financial statements prepared in accordance with generally accepted accounting principles ("GAAP") of the United States. These financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2018 and particularly as it relates to the simplification transactions completed by the Partnership on May 31, 2018 ("Simplification Transactions").

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For the periods presented prior to the Simplification Transactions, MGP's previous interests in both Alliance Coal and the Intermediate Partnership are reported as part of the general partner's interest in the ARLP Partnership's condensed consolidated financial statements.

These condensed consolidated financial statements and notes are unaudited. However, in the opinion of management, these condensed consolidated financial statements reflect all normal recurring adjustments necessary for a fair presentation of the results for the periods presented. Results for interim periods are not necessarily indicative of results to be expected for the full year ending December 31, 2019.

Use of Estimates

The preparation of the ARLP Partnership's condensed consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts and disclosures in our condensed consolidated financial statements. Actual results could differ from those estimates.

Leases

We lease buildings and equipment under operating lease agreements that provide for the payment of minimum rentals. We also have noncancelable lease agreements with third parties for land and equipment under finance lease obligations. Some of our arrangements within these agreements have both lease and non-lease components, which are generally accounted for separately. We have elected a practical expedient to account for lease and non-lease components as a single lease component for leases of buildings and office equipment. Our leases have lease terms of one year to 20 years, some of which include automatic renewals up to ten years which are likely to be exercised, and some of which include options to terminate the lease within one year. We also hold numerous mineral reserve leases with both related parties as well as third parties, none of which are accounted for as an operating lease or as a finance lease.

We review each agreement to determine if an arrangement within the agreement contains a lease at the inception of an arrangement. Once an arrangement is determined to contain either an operating or finance lease with a term greater than 12 months, we recognize a lease liability for the obligation to make lease payments and a right-of-use asset for the right to use the underlying asset for the lease term based on the present value of lease payments over the lease term. The lease term includes all noncancelable periods defined in the lease as well as periods covered by options to extend the lease that we are reasonably certain to exercise. As an implicit borrowing rate cannot be determined under most of our leases, we use our incremental borrowing rate based on the information available at commencement date in determining the present value of lease payments.

Expenses related to leases determined to be operating leases will be recognized on a straight-line basis over the lease term including any reasonably assured renewal periods, while those determined to be finance leases will be recognized following a front-loaded expense profile in which interest and amortization are presented separately in the income statement. The determination of whether a lease is accounted for as a finance lease or an operating lease requires management to make estimates primarily about the fair value of the asset and its estimated economic useful life.

2.NEW ACCOUNTING STANDARDS

New Accounting Standards Issued and Adopted

In February 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2016-02, Leases (Topic 842) ("ASU 2016-02"). ASU 2016-02 requires lessees to record right-of-use assets and corresponding lease liabilities on the balance sheet and disclose key information about lease arrangements. Leases are now classified as either finance or operating, with the resulting classification affecting the pattern of expense recognition in the income statement. We elected to use the modified retrospective transition method which allows a cumulative effect adjustment on the balance sheet upon adoption. The adoption of the standard resulted in the recognition of approximately $25.0 million in additional net lease assets and respective lease liabilities as of January 1, 2019.

As part of our transition there are a number of practical expedients available in the new standard. We elected a package of practical expedients that, among other things, allows us to not reassess the lease classification of expired or existing leases. In addition to the package of practical expedients, we also elected to use a practical expedient allowing us to use hindsight in determining the lease term for existing leases.

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New Accounting Standards Issued and Not Yet Adopted

In June 2016, the FASB issued ASU 2016-13, Financial Instruments–Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments ("ASU 2016-13"). ASU 2016-13 changes the impairment model for most financial assets and certain other instruments to require the use of a new forward-looking "expected loss" model that generally will result in earlier recognition of allowances for losses. The new standard will require disclosure of significantly more information related to these items. ASU 2016-13 is effective for fiscal years beginning after December 15, 2019, and interim periods within those fiscal years, with early adoption permitted for the fiscal year beginning after December 15, 2018, including interim periods. We do not have a history of credit losses on our financial instruments, accordingly we do not anticipate ASU 2016-13 will have a material impact on our condensed consolidated financial statements.

3.ACQUISITION

On the AllDale Acquisition Date, we acquired all of the limited partner interests not owned by Cavalier Minerals in AllDale I & II and the general partner interests in AllDale I & II for $176.0 million, which was funded with cash on hand and borrowings under the Revolving Credit Facility discussed in Note 8 – Long-Term Debt. As a result of the AllDale Acquisition and our previous investments held through Cavalier Minerals, we now control approximately 43,000 net royalty acres strategically positioned in the core of the Anadarko (SCOOP/STACK), Permian (Delaware and Midland), Williston (Bakken) and Appalachian basins. The AllDale Acquisition provides us with diversified exposure to industry leading operators and is consistent with our general business strategy to pursue accretive acquisitions.

Because the underlying mineral interests held by AllDale I & II include royalty interests in producing properties, we have determined that the AllDale Acquisition should be accounted for as a business combination and the underlying assets and liabilities of AllDale I & II should be recorded at their AllDale Acquisition Date fair value on our condensed consolidated balance sheet. We consider our fair value measurements to be preliminary as we continue to obtain additional information from operators of the mineral interests about reserve and production quantities and projections.

The total fair value of the cash paid in the AllDale Acquisition and our previous investments were as follows:


	As of January 3, 2019
	(in thousands)

Cash	$	175,960
Previously held investments		307,322
Total	$	483,282

Prior to the AllDale Acquisition Date, we accounted for our investments in AllDale I & II, held through Cavalier Minerals, as equity method investments. The combined fair value of our equity method investments on the AllDale Acquisition Date was $307.3 million. We re-measured our equity method investments, which had an aggregate carrying value of $130.3 million immediately prior to the AllDale Acquisition. The re-measurement resulted in a gain of $177.0 million which is recorded in the Acquisition gain line item in our condensed consolidated statements of income.

The following table summarizes the fair value allocation of assets acquired and liabilities assumed as of the AllDale Acquisition Date:


	As of January 3, 2019
	(in thousands)

Cash and cash equivalents	$	900
Mineral interests in proved properties		159,617
Mineral interests in unproved properties		314,084
Receivables		10,602
Accounts payable		(1,921)
Net assets acquired	$	483,282

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Our previous equity method investments in AllDale I & II were held through Cavalier Minerals. Bluegrass Minerals continues to hold a 4% membership interest (the "Bluegrass Interest") as well as a profits interest in Cavalier Minerals as it did before the AllDale Acquisition. This Bluegrass Interest represents an indirect noncontrolling interest in AllDale I & II. The AllDale Acquisition Date fair value of the Bluegrass Interest was $12.3 million.

The fair value of our previous equity method investments, the mineral interests and the Bluegrass Interest were determined using an income approach primarily comprised of discounted cash flow models. The assumptions used in the discounted cash flow models include estimated production, projected cash flows, forward oil & gas prices and a risk adjusted discount rate. Certain assumptions used are not observable in active markets, therefore the fair value measurements represent Level 3 fair value measurements. AllDale I & II's carrying value of the receivables and accounts payable represent their fair value given their short-term nature.

The amounts of revenue and earnings, exclusive of the acquisition gain, of AllDale I & II included in our condensed consolidated statements of income since the AllDale Acquisition Date are as follows:


	Three Months Ended		Six Months Ended
	June 30,		June 30,
	2019		2019
	(in thousands)

Revenue	$	12,428	$	23,156
Net income		4,901		8,982

The following represents the pro forma revenues and net income for the three and six months ended June 30, 2018 as if AllDale I & II had been included in our consolidated results since January 1, 2018. These amounts have been calculated after applying our accounting policies. Pro forma information is not necessary for the three and six months ended June 30, 2019 as the AllDale Acquisition occurred at the beginning of the year. Additionally, our results have been adjusted to remove the effect of our past equity method investments in AllDale I & II.


	Three Months Ended		Six Months Ended
	June 30,		June 30,
	2018		2018
	(in thousands)
Total revenues
As reported	$	516,137	$	973,259
Pro forma		525,013		989,894

Net income
As reported	$	86,377	$	242,433
Pro forma		85,062		240,645

4.CONTINGENCIES

Various lawsuits, claims and regulatory proceedings incidental to our business are pending against the ARLP Partnership. We record accruals for potential losses related to these matters when, in management's opinion, such losses are probable and reasonably estimable. Based on known facts and circumstances, we believe the ultimate outcome of these outstanding lawsuits, claims and regulatory proceedings will not have a material adverse effect on our financial condition, results of operations or liquidity. However, if the results of these matters were different from management's current opinion and in amounts greater than our accruals, then they could have a material adverse effect.

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5.INVENTORIES

Inventories consist of the following:


	June 30,		December 31,
	2019		2018
	(in thousands)

Coal	$	46,387	$	20,929
Supplies (net of reserve for obsolescence of $5,306 and $5,453, respectively)		38,274		38,277
Total inventories, net	$	84,661	$	59,206

6.LEASES

The components of lease expense were as follows:


	Three Months Ended		Six Months Ended
	June 30,		June 30,
	2019		2019
	(in thousands)

Finance lease cost:
Amortization of right-of-use assets	$	4,496	$	9,017
Interest on lease liabilities		619		1,333
Operating lease cost		2,400		5,409
Short-term lease cost		106		296
Variable lease cost		343		675
Total lease cost	$	7,964	$	16,730

Supplemental cash flow information related to leases was as follows:


	Three Months Ended		Six Months Ended
	June 30,		June 30,
	2019		2019
	(in thousands)

Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows for operating leases	$	2,325	$	5,291
Operating cash flows for finance leases	$	619	$	1,333
Financing cash flows for finance leases	$	9,213	$	16,554

Right-of-use assets obtained in exchange for lease obligations:
Operating leases	$	—	$	25,179

Supplemental balance sheet information related to leases was as follows:


	June 30,		December 31,
	2019		2018
	(in thousands)
Finance leases:
Property and equipment finance lease assets, gross	$	140,717	$	141,019
Accumulated depreciation		(83,291)		(74,576)
Property and equipment finance lease assets, net	$	57,426	$	66,443

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	June 30,
	2019
Weighted average remaining lease term
Operating leases		11.8 years
Finance leases		0.9 years

Weighted average discount rate
Operating leases		6.0	%
Finance leases		5.2	%

Maturities of lease liabilities as of June 30, 2019 were as follows:


	Operating leases		Finance leases
	(in thousands)

2019	$	3,796	$	30,921
2020		3,788		8,748
2021		2,236		913
2022		2,172		913
2023		1,995		140
Thereafter		14,864		560
Total lease payments		28,851		42,195
Less imputed interest		(8,491)		(1,432)
Total	$	20,360	$	40,763

7.FAIR VALUE MEASUREMENTS

The following table summarizes our fair value measurements within the hierarchy:


	June 30, 2019						December 31, 2018
	Level 1		Level 2		Level 3		Level 1		Level 2		Level 3
	(in thousands)
Long-term debt	$	—	$	587,757	$	—	$	—	$	669,864	$	—
Total	$	—	$	587,757	$	—	$	—	$	669,864	$	—

The carrying amounts for cash equivalents, accounts receivable, accounts payable, accrued and other liabilities, due from affiliates and due to affiliates approximate fair value due to the short maturity of those instruments.

The estimated fair value of our long-term debt, including current maturities, is based on interest rates that we believe are currently available to us in active markets for issuance of debt with similar terms and remaining maturities (See Note 8 – Long-Term Debt). The fair value of debt, which is based upon these interest rates, is classified as a Level 2 measurement under the fair value hierarchy.

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8.LONG-TERM DEBT

Long-term debt consists of the following:


					Unamortized Discount and
	Principal				Debt Issuance Costs
	June 30,		December 31,		June 30,		December 31,
	2019		2018		2019		2018
	(in thousands)
Revolving credit facility	$	70,000	$	175,000	$	(4,126)	$	(5,203)
Senior notes		400,000		400,000		(5,336)		(5,793)
Securitization facility		75,000		92,000		—		—
Equipment financing		9,747		—		—		—
		554,747		667,000		(9,462)		(10,996)
Less current maturities		(78,144)		(92,000)		—		—
Total long-term debt	$	476,603	$	575,000	$	(9,462)	$	(10,996)

Credit Facility. On January 27, 2017, our Intermediate Partnership entered into a Fourth Amended and Restated Credit Agreement (the "Credit Agreement") with various financial institutions. The Credit Agreement provides for a $494.75 million revolving credit facility, including a sublimit of $125 million for the issuance of letters of credit and a sublimit of $15.0 million for swingline borrowings (the "Revolving Credit Facility"), with a termination date of May 23, 2021.

The Credit Agreement is guaranteed by all of the material direct and indirect subsidiaries of our Intermediate Partnership, and is secured by substantially all of the Intermediate Partnership's assets. Borrowings under the Revolving Credit Facility bear interest, at the option of the Intermediate Partnership, at either (i) the Base Rate at the greater of three benchmarks or (ii) a Eurodollar Rate, plus margins for (i) or (ii), as applicable, that fluctuate depending upon the ratio of Consolidated Debt to Consolidated Cash Flow (each as defined in the Credit Agreement). The Eurodollar Rate, with applicable margin, under the Revolving Credit Facility was 4.77% as of June 30, 2019. At June 30, 2019, we had $9.3 million of letters of credit outstanding with $415.5 million available for borrowing under the Revolving Credit Facility. We currently incur an annual commitment fee of 0.35% on the undrawn portion of the Revolving Credit Facility. We utilize the Revolving Credit Facility, as appropriate, for working capital requirements, capital expenditures and investments, scheduled debt payments and distribution payments.

The Credit Agreement contains various restrictions affecting our Intermediate Partnership and its subsidiaries including, among other things, restrictions on incurrence of additional indebtedness and liens, sale of assets, investments, mergers and consolidations and transactions with affiliates, in each case subject to various exceptions, and the payment of cash distributions by our Intermediate Partnership if such payment would result in a certain fixed charge coverage ratio (as defined in the Credit Agreement). The Credit Agreement requires the Intermediate Partnership to maintain (a) a debt to cash flow ratio of not more than 2.5 to 1.0 and (b) a cash flow to interest expense ratio of not less than 3.0 to 1.0, in each case, during the four most recently ended fiscal quarters. The debt to cash flow ratio and cash flow to interest expense ratio were 0.87 to 1.0 and 15.7 to 1.0, respectively, for the trailing twelve months ended June 30, 2019. We remain in compliance with the covenants of the Credit Agreement as of June 30, 2019.

Senior Notes. On April 24, 2017, the Intermediate Partnership and Alliance Resource Finance Corporation (as co-issuer), a wholly owned subsidiary of the Intermediate Partnership ("Alliance Finance"), issued an aggregate principal amount of $400.0 million of senior unsecured notes due 2025 ("Senior Notes") in a private placement to qualified institutional buyers. The Senior Notes have a term of eight years, maturing on May 1, 2025 (the "Term") and accrue interest at an annual rate of 7.5%. Interest is payable semi-annually in arrears on each May 1 and November 1. The indenture governing the Senior Notes contains customary terms, events of default and covenants relating to, among other things, the incurrence of debt, the payment of distributions or similar restricted payments, undertaking transactions with affiliates and limitations on asset sales. At any time prior to May 1, 2020, the issuers of the Senior Notes may redeem up to 35% of the aggregate principal amount of the Senior Notes with the net cash proceeds of one or more equity offerings at a redemption price equal to 107.5% of the principal amount redeemed, plus accrued and unpaid interest, if any, to the redemption date. The issuers of the Senior Notes may also redeem all or a part of the notes at any time on or after May 1, 2020, at redemption prices set forth in the indenture governing the Senior Notes. At any time prior to May 1, 2020, the

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issuers of the Senior Notes may redeem the Senior Notes at a redemption price equal to the principal amount of the Senior Notes plus a "make-whole" premium, plus accrued and unpaid interest, if any, to the redemption date.

Accounts Receivable Securitization. On December 5, 2014, certain direct and indirect wholly owned subsidiaries of our Intermediate Partnership entered into a $100.0 million accounts receivable securitization facility ("Securitization Facility"). Under the Securitization Facility, certain subsidiaries sell trade receivables on an ongoing basis to our Intermediate Partnership, which then sells the trade receivables to AROP Funding, LLC ("AROP Funding"), a wholly owned bankruptcy-remote special purpose subsidiary of our Intermediate Partnership, which in turn borrows on a revolving basis up to $100.0 million secured by the trade receivables. After the sale, Alliance Coal, as servicer of the assets, collects the receivables on behalf of AROP Funding. The Securitization Facility bears interest based on a Eurodollar Rate. It was renewed in January 2019 and matures in January 2020. At June 30, 2019, we had $75.0 million outstanding balance under the Securitization Facility.

Cavalier Credit Agreement. On October 6, 2015, Cavalier Minerals (see Note 9 – Variable Interest Entities) entered into a credit agreement (the "Cavalier Credit Agreement") with Mineral Lending, LLC ("Mineral Lending") for a $100.0 million line of credit (the "Cavalier Credit Facility"). The commitment under the Cavalier Credit Facility is reduced by any distributions received from Cavalier Minerals' investment in AllDale II. As of June 30, 2019, the commitment under the Cavalier Credit Facility was $67.5 million. Mineral Lending is an entity owned by (a) Alliance Resource Holdings II, Inc. ("ARH II"), an entity owned by Joseph W. Craft III, the Chairman, President and Chief Executive Officer of MGP ("Mr. Craft") and Kathleen S. Craft, (b) an entity owned by an individual who is an officer and director of ARH II ("ARH Officer") and (c) charitable foundations established by Mr. Craft and Kathleen S. Craft. There is no commitment fee under the facility. Mineral Lending's obligation to make the line of credit available terminates no later than October 6, 2019. Borrowings under the Cavalier Credit Facility bear interest at a one month LIBOR rate plus 6% with interest payable quarterly, and mature on September 30, 2024, at which time all amounts then outstanding are required to be repaid. The Cavalier Credit Agreement requires repayment of the principal balance beginning in 2018, in quarterly payments of an amount equal to the greater of $1.3 million initially, escalated to $2.5 million after two years, or fifty percent of Cavalier Minerals' excess cash flow. To secure payment of the facility, Cavalier Minerals pledged all of its partnership interests, owned or later acquired, in AllDale I & II. Cavalier Minerals may prepay the Cavalier Credit Facility at any time in whole or in part subject to terms and conditions described in the Cavalier Credit Agreement. As of June 30, 2019, Cavalier Minerals had not drawn on the Cavalier Credit Facility.

Equipment Financing. On May 17, 2019, the Intermediate Partnership entered into an equipment financing arrangement accounted for as debt, wherein the Intermediate Partnership received $10.0 million in exchange for conveying its interest in certain equipment owned by an indirect wholly-owned subsidiary of the Intermediate Partnership and entering into a master lease agreement for that equipment (the “Equipment Financing”). The Equipment Financing contains customary terms and events of default and provides for thirty-six monthly payments with an implicit interest rate of 6.25%, maturing on May 1, 2022. Upon maturity, the equipment will revert back to the Intermediate Partnership.

9.VARIABLE INTEREST ENTITIES

Cavalier Minerals

On November 10, 2014, our subsidiary, Alliance Minerals, and Bluegrass Minerals Management, LLC ("Bluegrass Minerals") entered into a limited liability company agreement (the "Cavalier Agreement") to create Cavalier Minerals, which was formed to indirectly acquire oil & gas mineral interests through its ownership in AllDale I & II. Alliance Minerals' ownership interest in Cavalier Minerals is 96%. Bluegrass Minerals owns a 4% membership interest in Cavalier Minerals and a profits interest which entitles it to receive distributions equal to 25% of all distributions (including in liquidation) after all members have recovered their investment. Distributions with respect to Bluegrass Minerals' profits interest will be offset by all distributions received by Bluegrass Minerals from the former general partners of AllDale I & II. Bluegrass Minerals was Cavalier Minerals' managing member prior to the AllDale Acquisition (see Note 3 – Acquisition). In conjunction with the AllDale Acquisition, we became the managing member in Cavalier Minerals. Total contributions to and cumulative distributions from Cavalier Minerals are as follows:

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	Alliance		Bluegrass
	Minerals		Minerals
	(in thousands)
Contributions	$	143,112	$	5,963
Distributions		62,870		2,619

We have concluded that Cavalier Minerals is a variable interest entity ("VIE") which we consolidate as the primary beneficiary because we are the managing member and a substantial equity owner in Cavalier Minerals. Bluegrass Minerals' equity ownership of Cavalier Minerals is accounted for as noncontrolling ownership interest in our condensed consolidated balance sheets. In addition, earnings attributable to Bluegrass Minerals are recognized as noncontrolling interest in our condensed consolidated statements of income.

AllDale I & II

As a result of the AllDale Acquisition, we now own 100% of the general partner interests and, including the limited partner interests we hold indirectly through our ownership in Cavalier Minerals, approximately 97% of the limited partner interests in AllDale I & II. See Note 3 – Acquisition for more information on the AllDale Acquisition. As the general partner of AllDale I & II, we are entitled to receive 20.0% of all distributions from AllDale I & II with the remaining 80.0% allocated to limited partners based upon ownership percentages.

Since AllDale I & II are structured as limited partnerships with the limited partners 1) not having the ability to remove the general partner and 2) not participating significantly in the operational decisions, we concluded that AllDale I & II are VIEs. We consolidate AllDale I & II as the primary beneficiary because we have the power to direct the activities that most significantly impact AllDale I & II's economic performance in addition to substantial equity ownership.

The following table presents the carrying amounts and classification of AllDale I & II's assets and liabilities included in our condensed consolidated balance sheets:


	June 30,
	2019
Assets (liabilities):	(in thousands)
Cash and cash equivalents	$	3,076
Trade receivables		9,253
Other receivables		335
Prepaid expenses and other assets		45
Total property, plant and equipment, net		463,961
Other long-term assets		107
Accounts payable		(313)
Due to affiliates		(17)
Accrued taxes other than income taxes		(54)
Other current liabilities		(404)

AllDale III

In February 2017, Alliance Minerals committed to directly invest $30.0 million in AllDale Minerals III, LP ("AllDale III") which was created for similar investment purposes as AllDale I & II. Alliance Minerals completed funding of this commitment in 2018. Alliance Minerals' limited partner interest in AllDale III at June 30, 2019 was 13.9%.

The AllDale III Partnership Agreement includes a 25% profits interest for the general partner, subject to a return hurdle equal to the greater of 125% of cumulative capital contributions and a 10% internal rate of return, and following an 80/20 "catch-up" provision for the general partner. AllDale III distributed to Alliance Minerals $0.6 million and $0.3 million during the three months ended June 30, 2019 and 2018, respectively, and $1.2 million and $0.7 million during the six months ended June 30, 2019 and 2018, respectively.

Since AllDale III is structured as a limited partnership with the limited partners 1) not having the ability to remove the general partner and 2) not participating significantly in the operational decisions, we concluded that AllDale III is a

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VIE. We are not the primary beneficiary of AllDale III as we do not have the power to direct the activities that most significantly impact AllDale III's economic performance. We account for our ownership interest in the income or loss of AllDale III as an equity method investment. We record equity income or loss based on AllDale III's distribution structure.

WKY CoalPlay

On November 17, 2014, SGP Land, LLC ("SGP Land"), an indirect, wholly owned subsidiary of ARH II, and two limited liability companies ("Craft Companies") owned by irrevocable trusts established by Mr. Craft, entered into a limited liability company agreement to form WKY CoalPlay, LLC ("WKY CoalPlay"). WKY CoalPlay was formed, in part, to purchase and lease coal reserves. WKY CoalPlay is managed by the ARH Officer discussed in Note 8 – Long-Term Debt, who is also a trustee of the irrevocable trusts owning the Craft Companies. In December 2014 and February 2015, we entered into various coal reserve leases with WKY CoalPlay. During the six months ended June 30, 2019, we paid $10.8 million of advanced royalties to WKY CoalPlay.

We have concluded that WKY CoalPlay is a VIE because of our ability to exercise options to acquire reserves under lease with WKY CoalPlay, which is not within the control of the equity holders and, if it occurs, could potentially limit the expected residual return to the owners of WKY CoalPlay. We do not have any economic or governance rights related to WKY CoalPlay and our options that provide us with a variable interest in WKY CoalPlay's reserve assets do not give us any rights that constitute power to direct the primary activities that most significantly impact WKY CoalPlay's economic performance. SGP Land has the sole ability to replace the manager of WKY CoalPlay at its discretion and therefore has power to direct the activities of WKY CoalPlay. Consequently, we concluded that SGP Land is the primary beneficiary of WKY CoalPlay.

10.INVESTMENTS

AllDale III

As discussed in Note 9 – Variable Interest Entities, we account for our ownership interest in the income or loss of AllDale III as an equity method investment. We record equity income or loss based on AllDale III's distribution structure. The changes in our equity method investment in AllDale III for each of the periods presented were as follows:


	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2019		2018		2019		2018
	(in thousands)
Beginning balance	$	28,770	$	25,249	$	28,974	$	14,182
Contributions		—		—		—		11,400
Equity method investment income		550		155		874		197
Distributions received		(648)		(278)		(1,176)		(653)
Ending balance	$	28,672	$	25,126	$	28,672	$	25,126

Kodiak

On July 19, 2017, Alliance Minerals purchased $100 million of Series A-1 Preferred Interests from Kodiak Gas Services, LLC ("Kodiak"), a privately-held company providing large-scale, high-utilization gas compression assets to customers operating primarily in the Permian Basin. This structured investment provided us with a quarterly cash or payment-in-kind return. We accounted for our ownership interests in Kodiak as equity securities without readily determinable fair values. On February 8, 2019, Kodiak redeemed our preferred interest for $135.0 million in cash resulting in an $11.5 million gain due to an early redemption premium. The gain is included in the Equity securities income line item. We no longer hold any ownership interests in Kodiak.

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11.PARTNERS' CAPITAL

Distributions

Distributions paid or declared during 2018 and 2019 were as follows:


Payment Date	Per Unit Cash Distribution		Total Cash Distribution
			(in thousands)

February 14, 2018	$	0.5100	$	68,396
May 15, 2018		0.5150		69,047
August 14, 2018		0.5200		69,239
November 14, 2018		0.5250		69,220
Total	$	2.0700	$	275,902

February 14, 2019	$	0.5300	$	69,011
May 15, 2019		0.5350		69,489
August 14, 2019 (1)		0.5400		—
Total	$	1.6050	$	138,500

(1)	On July 26, 2019, we declared this quarterly distribution payable on August 14, 2019 to all unitholders of record as of August 7, 2019.

Unit Repurchase Program

In May 2018, the MGP board of directors approved the establishment of a unit repurchase program authorizing us to repurchase and retire up to $100 million of ARLP common units. The program has no time limit and we may repurchase units from time to time in the open market or in other privately negotiated transactions. The unit repurchase program authorization does not obligate us to repurchase any dollar amount or number of units. During the six months ended June 30, 2019, we repurchased and retired 300,970 units for $5.3 million. Since inception of the program, we have repurchased and retired 3,985,045 units at an average unit price of $19.03 for an aggregate purchase price of $75.9 million. Total units repurchased includes the repurchase and retirement of 35 units representing fractional units as part of the Simplification Transactions which are not part of the unit repurchase program.

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Change in Partners' Capital

The following tables present the quarterly change in Partners' Capital for the six months ended June 30, 2019 and 2018:


				Accumulated
	Number of	Limited		Other
	Limited Partner	Partners'		Comprehensive		Noncontrolling		Total Partners’
	Units	Capital		Loss		Interest		Capital
	(in thousands, except unit data)
Balance at January 1, 2019	128,095,511	$	1,229,268	$	(46,871)	$	5,290	$	1,187,687
Comprehensive income:
Net income	—		276,428		—		7,176		283,604
Actuarially determined long-term liability adjustments	—		—		(3,584)		—		(3,584)
Total comprehensive income									280,020
Settlement of deferred compensation plans	596,650		(7,817)		—		—		(7,817)
Purchase of units under unit repurchase program	(300,970)		(5,251)		—		—		(5,251)
Common unit-based compensation	—		2,743		—		—		2,743
Distributions on deferred common unit-based compensation	—		(1,280)		—		—		(1,280)
Distributions from consolidated company to noncontrolling interest	—		—		—		(262)		(262)
Distributions to Partners	—		(67,731)		—		—		(67,731)
Balance at March 31, 2019	128,391,191		1,426,360		(50,455)		12,204		1,388,109
Comprehensive income:
Net income	—		58,070		—		114		58,184
Actuarially determined long-term liability adjustments	—		—		(118)		—		(118)
Total comprehensive income									58,066
Common unit-based compensation	—		3,021		—		—		3,021
Distributions on deferred common unit-based compensation	—		(799)		—		—		(799)
Distributions from consolidated company to noncontrolling interest	—		—		—		(228)		(228)
Distributions to Partners	—		(68,690)		—		—		(68,690)
Balance at June 30, 2019	128,391,191	$	1,417,962	$	(50,573)	$	12,090	$	1,379,479

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						Accumulated
	Number of	Limited		General		Other
	Limited Partner	Partners'		Partner's		Comprehensive		Noncontrolling		Total Partners’
	Units	Capital		Capital		Income (Loss)		Interest		Capital
	(in thousands, except unit data)
Balance at January 1, 2018	130,704,217	$	1,183,219	$	14,859	$	(51,940)	$	5,348	$	1,151,486
Comprehensive income:
Net income	—		154,348		1,560		—		148		156,056
Actuarially determined long-term liability adjustments	—		—		—		1,017		—		1,017
Total comprehensive income											157,073
Settlement of deferred compensation plans	199,039		(2,081)		—		—		—		(2,081)
Simplification Transactions fees	—		(1)		—		—		—		(1)
Common unit-based compensation	—		3,006		—		—		—		3,006
Distributions on deferred common unit-based compensation	—		(1,062)		—		—		—		(1,062)
General Partner contribution	—		—		41		—		—		41
Distributions from consolidated company to noncontrolling interest	—		—		—		—		(162)		(162)
Distributions to Partners	—		(66,660)		(674)		—		—		(67,334)
Balance at March 31, 2018	130,903,256		1,270,769		15,786		(50,923)		5,334		1,240,966
Comprehensive income:
Net income	—		86,190		—		—		187		86,377
Actuarially determined long-term liability adjustments	—		—		—		1,016		—		1,016
Total comprehensive income											87,393
Settlement of deferred compensation plans	—		(664)		—		—		—		(664)
Issuance of units to Owners of SGP in Simplification Transactions	1,322,388		14,742		(15,106)		—		—		(364)
Issuance of units to SGP related to Exchange Transaction	20,960		—		—		—		—		—
Simplification Transactions fees	—		(59)		—		—		—		(59)
Contribution of units and cash by affiliated entity	(467,018)		2,142		—		—		—		2,142
Purchase of units under unit repurchase program	(383,599)		(7,639)		—		—		—		(7,639)
Common unit-based compensation	—		2,897		—		—		—		2,897
Distributions on deferred common unit-based compensation	—		(910)		—		—		—		(910)
Distributions from consolidated company to noncontrolling interest	—		—		—		—		(194)		(194)
Distributions to Partners	—		(67,457)		(680)		—		—		(68,137)
Balance at June 30, 2018	131,395,987	$	1,300,011	$	—	$	(49,907)	$	5,327	$	1,255,431

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12.REVENUE FROM CONTRACTS WITH CUSTOMERS

The following table illustrates the disaggregation of our revenues by type, including a reconciliation to our segment presentation as presented in Note 17 – Segment Information, for the three and six months ended June 30, 2019 and 2018.


	Illinois						Other and
	Basin		Appalachia		Minerals		Corporate		Elimination		Consolidated
	(in thousands)
Three Months Ended June 30, 2019

Coal sales	$	301,981	$	157,951	$	—	$	5,551	$	(4,173)	$	461,310
Oil & gas royalties		—		—		11,892		—		—		11,892
Transportation revenues		31,287		1,343		—		—		—		32,630
Other revenues		2,405		950		536		10,439		(3,108)		11,222
Total revenues	$	335,673	$	160,244	$	12,428	$	15,990	$	(7,281)	$	517,054

Three Months Ended June 30, 2018

Coal sales	$	310,464	$	162,886	$	—	$	9,398	$	(6,823)	$	475,925
Transportation revenues		26,327		1,203		—		2		—		27,532
Other revenues		4,388		723		—		10,600		(3,031)		12,680
Total revenues	$	341,179	$	164,812	$	—	$	20,000	$	(9,854)	$	516,137

Six Months Ended June 30, 2019

Coal sales	$	619,251	$	315,404	$	—	$	10,841	$	(8,170)	$	937,326
Oil & gas royalties		—		—		22,285		—		—		22,285
Transportation revenues		60,525		2,343		—		—		—		62,868
Other revenues		5,293		1,901		871		19,311		(6,199)		21,177
Total revenues	$	685,069	$	319,648	$	23,156	$	30,152	$	(14,369)	$	1,043,656

Six Months Ended June 30, 2018

Coal sales	$	586,529	$	308,175	$	—	$	17,109	$	(12,278)	$	899,535
Transportation revenues		44,598		2,717		—		2		—		47,317
Other revenues		8,734		1,552		—		22,441		(6,320)		26,407
Total revenues	$	639,861	$	312,444	$	—	$	39,552	$	(18,598)	$	973,259

The following table illustrates the amount of our transaction price for all current coal supply contracts allocated to performance obligations that are unsatisfied or partially unsatisfied as of June 30, 2019 and disaggregated by segment and contract duration.


							2022 and
	2019		2020		2021		Thereafter		Total
	(in thousands)

Illinois Basin coal revenues	$	533,472	$	580,097	$	236,331	$	—	$	1,349,900
Appalachia coal revenues		354,869		303,517		130,316		434,700		1,223,402
Other and Corporate coal revenues		11,798		—		—		—		11,798
Elimination		(8,864)		—		—		—		(8,864)
Total coal revenues (1)	$	891,275	$	883,614	$	366,647	$	434,700	$	2,576,236

(1) Coal revenues consists of coal sales and transportation revenues.

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13.EARNINGS PER LIMITED PARTNER UNIT

We utilize the two-class method in calculating basic and diluted earnings per limited partner unit ("EPU"). Subsequent to the Simplification Transactions, net income attributable to ARLP is only allocated to limited partners and participating securities under deferred compensation plans. Prior to the Simplification Transactions, net income attributable to ARLP was allocated to MGP, limited partners and participating securities under deferred compensation plans in accordance with their respective ownership percentages of the ARLP Partnership, after giving effect to any special income or expense allocations.

Our participating securities under deferred compensation plans include rights to nonforfeitable distributions or distribution equivalents. Our participating securities are outstanding awards under our Long-Term Incentive Plan ("LTIP") and phantom units in notional accounts under our Supplemental Executive Retirement Plan ("SERP") and the MGP Amended and Restated Deferred Compensation Plan for Directors ("Directors' Deferred Compensation Plan").

As a result of the Simplification Transactions, MGP no longer holds economic interests in the Intermediate Partnership or Alliance Coal. We no longer make distributions or allocate income and losses to MGP in our calculation of EPU.

The following is a reconciliation of net income attributable to ARLP used for calculating basic and diluted earnings per unit and the weighted-average units used in computing EPU for the three and six months ended June 30, 2019 and 2018:


	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2019		2018		2019		2018
	(in thousands, except per unit data)
Net income attributable to ARLP	$	58,070	$	86,190	$	334,498	$	242,098
Adjustments:
General partner's equity ownership (1)		—		—		—		(1,560)

Limited partners' interest in net income attributable to ARLP		58,070		86,190		334,498		240,538

Less:
Distributions to participating securities		(1,122)		(1,261)		(2,227)		(2,532)
Undistributed earnings attributable to participating securities		—		(343)		(3,196)		(1,898)

Net income attributable to ARLP available to limited partners	$	56,948	$	84,586	$	329,075	$	236,108

Weighted-average limited partner units outstanding – basic and diluted		128,391		131,280		128,271		131,051

Earnings per limited partner unit - basic and diluted (2)	$	0.44	$	0.64	$	2.57	$	1.80

(1)

Amounts presented for periods subsequent to the first quarter of 2018 reflect the impact of the Simplification Transactions which ended net income allocations and quarterly cash distributions to MGP after May 31, 2018. Prior to the Simplification Transactions, MGP maintained a 1.0001% general partner interest in the Intermediate Partnership and a 0.001% managing member interest in Alliance Coal and thus received quarterly distributions and income and loss allocations during this time period.

(2)

Diluted EPU gives effect to all potentially dilutive common units outstanding during the period using the treasury stock method. Diluted EPU excludes all potentially dilutive units calculated under the treasury stock method if their effect is anti-dilutive. The combined total of LTIP, SERP and Directors' Deferred Compensation Plan units of 1,060 and 1,227 for the three and six months ended June 30, 2019, respectively, and 1,469 and 1,511 for the three and six months ended June 30, 2018, respectively, were considered anti-dilutive under the treasury stock method.

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14.WORKERS' COMPENSATION AND PNEUMOCONIOSIS

The changes in the workers' compensation liability, including current and long-term liability balances, for each of the periods presented were as follows:


	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2019		2018		2019		2018
	(in thousands)
Beginning balance	$	48,428	$	54,646	$	49,539	$	54,439
Accruals increase		2,247		285		4,208		2,926
Payments		(2,452)		(3,048)		(5,925)		(5,845)
Interest accretion		401		364		802		727
Valuation loss (1)		4,801		695		4,801		695
Ending balance	$	53,425	$	52,942	$	53,425	$	52,942

(1)

Our estimate of the liability for the present value of current workers′ compensation benefits is based on our actuarial calculations. Our actuarial calculations are based on a blend of actuarial projection methods and numerous assumptions including claims development patterns, mortality, medical costs and interest rates. We conducted a mid-year 2019 review of our actuarial assumptions which resulted in a valuation loss in 2019 due to unfavorable changes in claims development and a decrease in the discount rate from 3.89% to 3.06%. Our mid-year 2018 actuarial review resulted in a valuation loss in 2018 primarily attributable to unfavorable changes in claims development, offset in part by an increase in the discount rate used to calculate the estimated present value of future obligations from 3.22% to 3.82%.

We limit our exposure to traumatic injury claims by purchasing a high deductible insurance policy that starts paying benefits after deductibles for a claim have been met. The deductible level may vary by claim year. Our workers' compensation liability above is presented on a gross basis and does not include our expected receivables on our insurance policy. Our receivables for traumatic injury claims under this policy as of June 30, 2019 are $8.5 million and are included in Other long-term assets on our condensed consolidated balance sheet.

Certain of our mine operating entities are liable under state statutes and the Federal Coal Mine Health and Safety Act of 1969, as amended, to pay pneumoconiosis, or black lung, benefits to eligible employees and former employees and their dependents. Components of the net periodic benefit cost for each of the periods presented are as follows:


	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2019		2018		2019		2018
	(in thousands)
Service cost	$	646	$	632	$	1,291	$	1,262
Interest cost (1)		762		636		1,522		1,271
Net amortization (1)		(1,146)		—		(2,291)		1
Net periodic benefit cost	$	262	$	1,268	$	522	$	2,534

(1)	Interest cost and net amortization is included in the Other expense line item within our condensed consolidated statements of income.

15.COMPENSATION PLANS

Long-Term Incentive Plan

We maintain the LTIP for certain employees and officers of MGP and its affiliates who perform services for us. The LTIP awards are grants of non-vested "phantom" or notional units, also referred to as "restricted units", which upon satisfaction of time and performance-based vesting requirements, entitle the LTIP participant to receive ARLP common units. Annual grant levels and vesting provisions for designated participants are recommended by the Chairman, President and Chief Executive Officer of MGP, subject to review and approval of the compensation committee of the MGP board

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of directors (the "Compensation Committee"). Vesting of all grants outstanding is subject to the satisfaction of certain financial tests, which management currently believes is probable. Grants issued to LTIP participants are expected to cliff vest on January 1st of the third year following issuance of the grants. We account for forfeitures of non-vested LTIP grants as they occur. We will settle the non-vested LTIP grants by delivery of ARLP common units, except for the portion of the grants that will satisfy employee tax withholding obligations of LTIP participants. As provided under the distribution equivalent rights ("DERs") provisions of the LTIP and the terms of the LTIP awards, all non-vested grants include contingent rights to receive quarterly distributions in cash or, at the discretion of the Compensation Committee, phantom units in lieu of cash credited to a bookkeeping account with value, equal to the cash distributions we make to unitholders during the vesting period.

A summary of non-vested LTIP grants as of and for the six months ended June 30, 2019 is as follows:


	Number of units	Weighted average grant date fair value per unit		Intrinsic value
				(in thousands)

Non-vested grants at January 1, 2019	1,828,080	$	17.18	$	31,699
Granted	586,644		19.93
Vested (1)	(885,381)		12.38
Forfeited	(6,558)		21.06
Non-vested grants at June 30, 2019	1,522,785		21.01		25,857

(1)	During the six months ended June 30, 2019, we issued 596,650 unrestricted common units to the LTIP participants. The remaining vested units were settled in cash to satisfy tax withholding obligations of the LTIP participants.

LTIP expense was $2.7 million for each of the three months ended June 30, 2019 and 2018 and $5.1 million and $5.4 million for the six months ended June 30, 2019 and 2018, respectively. The total obligation associated with the LTIP as of June 30, 2019 was $15.0 million and is included in the partners' capital Limited partners-common unitholders line item in our condensed consolidated balance sheets. As of June 30, 2019, there was $17.0 million in total unrecognized compensation expense related to the non-vested LTIP grants that are expected to vest. That expense is expected to be recognized over a weighted-average period of 1.6 years.

After consideration of the January 1, 2019 vesting and subsequent issuance of 596,650 common units, approximately 1.9 million units remain available under the LTIP for issuance in the future, assuming all grants issued in 2019, 2018 and 2017 and currently outstanding are settled with common units without reduction for tax withholding, no future forfeitures occur and DERs continue being paid in cash versus additional phantom units.

Supplemental Executive Retirement Plan and Directors' Deferred Compensation Plan

We utilize the SERP to provide deferred compensation benefits for certain officers and key employees. All allocations made to participants under the SERP are made in the form of "phantom" ARLP units and SERP distributions will be settled in the form of ARLP common units. The SERP is administered by the Compensation Committee.

Our directors participate in the Directors' Deferred Compensation Plan. Pursuant to the Directors' Deferred Compensation Plan, for amounts deferred either automatically or at the election of the director, a notional account is established and credited with notional common units of ARLP, described in the Directors' Deferred Compensation Plan as "phantom" units. Distributions from the Directors' Deferred Compensation Plan will be settled in the form of ARLP common units.

For both the SERP and Directors' Deferred Compensation Plan, when quarterly cash distributions are made with respect to ARLP common units, an amount equal to such quarterly distribution is credited to each participant's notional account as additional phantom units. All grants of phantom units under the SERP and Directors' Deferred Compensation Plan vest immediately.

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A summary of SERP and Directors' Deferred Compensation Plan activity as of and for the six months ended June 30, 2019 is as follows:


	Number of units	Weighted average grant date fair value per unit		Intrinsic value
				(in thousands)

Phantom units outstanding as of January 1, 2019	635,837	$	27.34	$	11,025
Granted	34,320		18.84
Issued	(115,484)		25.20
Phantom units outstanding as of June 30, 2019	554,673		27.26		9,418

Total SERP and Directors' Deferred Compensation Plan expense was $0.4 million for each of the three months ended June 30, 2019 and 2018 and $0.7 million and $0.8 million for the six months ended June 30, 2019 and 2018, respectively. As of June 30, 2019, the total obligation associated with the SERP and Directors' Deferred Compensation Plan was $15.1 million and is included in the partners' capital Limited partners-common unitholders line item in our condensed consolidated balance sheets. During the six months ended June 30, 2019, we provided 115,484 ARLP common units to a director under the Directors' Deferred Compensation Plan.

16.COMPONENTS OF PENSION PLAN NET PERIODIC BENEFIT COSTS

Eligible employees at certain of our mining operations participate in a defined benefit plan (the "Pension Plan") that we sponsor. The Pension Plan is currently closed to new applicants and participants in the Pension Plan are no longer receiving benefit accruals for service. The benefit formula for the Pension Plan is a fixed dollar unit based on years of service. Components of the net periodic benefit cost for each of the periods presented are as follows:


	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2019		2018		2019		2018
	(in thousands)
Interest cost	$	1,216	$	1,116	$	2,432	$	2,232
Expected return on plan assets		(1,234)		(1,548)		(2,466)		(2,984)
Amortization of prior service cost		46		47		93		94
Amortization of net loss		982		969		1,961		1,938
Net periodic benefit cost (1)	$	1,010	$	584	$	2,020	$	1,280

(1)

Net periodic benefit cost for the Pension Plan is included in the Other expense line item within our condensed consolidated statements of income.

During the six months ended June 30, 2019, we made contribution payments of $1.2 million to the Pension Plan for the 2018 plan year and $1.1 million for the 2019 plan year. In July 2019, we made a contribution payment of $1.1 million for the 2019 plan year.

17.SEGMENT INFORMATION

We operate in the United States as a diversified natural resource company that generates income from the production and marketing of coal to major domestic and international utilities and industrial users as well as income from oil & gas mineral interests. We aggregate multiple operating segments into three reportable segments, Illinois Basin, Appalachia, and Minerals. We also have an "all other" category referred to as Other and Corporate. Our two coal reportable segments correspond to major coal producing regions in the eastern United States with similar economic characteristics including coal quality, geology, coal marketing opportunities, mining and transportation methods and regulatory issues. The two coal segments include eight mining complexes operating in Illinois, Indiana, Kentucky, Maryland and West Virginia and a coal loading terminal in Indiana on the Ohio River. The Minerals reportable segment aggregates our oil & gas mineral interests which are located primarily in the Anadarko (SCOOP/STACK), Permian (Delaware and Midland), Williston (Bakken) and Appalachian basins. We have no operations within our Minerals reportable segment other than receiving royalties for our oil & gas mineral interests.

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As a result of the AllDale Acquisition discussed in Note 3 – Acquisitions, we now control the underlying oil & gas mineral interests held by AllDale I & II. This control over the oil & gas mineral interests held by AllDale I & II reflects a strategic change in how we manage our business and how resources are allocated by our chief operating decision maker. Due to this strategic change, we have restructured our reportable segments in the first quarter of 2019 to include our oil & gas mineral interests within a new Minerals reportable segment. We have also included our Mt. Vernon Transfer Terminal, LLC ("Mt. Vernon") and Mid-America Carbonates, LLC ("MAC") in the Illinois Basin reportable segment rather than Other and Corporate to better align our Illinois Basin related activities. Prior periods have been recast to include our oil & gas minerals interests in the Minerals segment, and Mt. Vernon and MAC in the Illinois Basin segment.

The Illinois Basin reportable segment includes currently operating mining complexes (a) Webster County Coal, LLC's Dotiki mining complex, (b) Gibson County Coal, LLC's mining complex, which includes the Gibson North and Gibson South mines, (c) Warrior Coal, LLC's mining complex, (d) River View Coal, LLC's mining complex and (e) Hamilton County Coal, LLC's mining complex. The Illinois Basin reportable segment also includes our currently operating Mt. Vernon coal loading terminal in Indiana on the Ohio River. The Gibson North mine had been idled since the fourth quarter of 2015 in response to market conditions but resumed production in May 2018.

The Illinois Basin reportable segment also includes White County Coal, LLC's Pattiki mining complex, Hopkins County Coal, LLC's mining complex, which includes the Elk Creek mine, the Pleasant View surface mineable reserves and the Fies underground project, Sebree Mining, LLC's mining complex, which includes the Onton mine, Steamport, LLC and certain reserves, CR Services, LLC, CR Machine Shop, LLC, certain properties and equipment of Alliance Resource Properties, ARP Sebree, LLC, ARP Sebree South, LLC, UC Coal, LLC and its subsidiaries, UC Mining, LLC and UC Processing, LLC and Mid-America Carbonates, LLC ("MAC").

The Appalachia reportable segment includes currently operating mining complexes (a) Mettiki mining complex, (b) Tunnel Ridge, LLC mining complex and (c) MC Mining, LLC mining complex. The Mettiki mining complex includes Mettiki Coal (WV), LLC's Mountain View mine and Mettiki Coal, LLC's preparation plant. The Appalachia reportable segment also includes the Penn Ridge property and certain properties and equipment of Alliance Resource Properties.

The Minerals reportable segment includes AllDale I & II, Alliance Royalty, LLC, AllRoy GP, LLC, CavMM, LLC, and Alliance Minerals' equity interests in both AllDale III (Note 10 – Investments) and Cavalier Minerals.

Other and Corporate includes marketing and administrative activities, ASI and its subsidiary, Matrix Design Group, LLC and its subsidiaries Matrix Design International, LLC and Matrix Design Africa (PTY) LTD ("Matrix Design"), Alliance Design Group, LLC ("Alliance Design") (collectively, the Matrix Design entities and Alliance Design are referred to as the "Matrix Group"), ASI's ownership of aircraft, Alliance Coal's coal brokerage activity, Alliance Minerals' equity investment in Kodiak which was redeemed in February 2019 by Kodiak (see Note 10 – Investments), certain of Alliance Resource Properties' land and mineral interest activities, Pontiki Coal, LLC's prior workers' compensation and pneumoconiosis liabilities, Wildcat Insurance, LLC ("Wildcat Insurance"), which assists the ARLP Partnership with its insurance requirements, and AROP Funding and Alliance Finance (both discussed in Note 8 – Long-Term Debt).

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Reportable segment results as of and for the three and six months ended June 30, 2019 and 2018 are presented below.


	Illinois						Other and		Elimination
	Basin		Appalachia		Minerals		Corporate		(1)		Consolidated
	(in thousands)
Three Months Ended June 30, 2019

Revenues - Outside	$	331,500	$	160,244	$	12,428	$	12,882	$	—	$	517,054
Revenues - Intercompany		4,173		—		—		3,108		(7,281)		—
Total revenues (2)		335,673		160,244		12,428		15,990		(7,281)		517,054

Segment Adjusted EBITDA Expense (3)		208,309		105,122		1,765		9,442		(5,041)		319,597
Segment Adjusted EBITDA (4)		96,075		53,779		11,098		6,551		(2,240)		165,263
Capital expenditures		59,476		20,987		—		1,121		—		81,584

Three Months Ended June 30, 2018

Revenues - Outside	$	334,355	$	164,812	$	—	$	16,970	$	—	$	516,137
Revenues - Intercompany		6,824		—		—		3,030		(9,854)		—
Total revenues (2)		341,179		164,812		—		20,000		(9,854)		516,137

Segment Adjusted EBITDA Expense (3)		202,886		103,538		—		13,136		(7,749)		311,811
Segment Adjusted EBITDA (4)		111,967		60,069		4,652		10,717		(2,105)		185,300
Capital expenditures		46,555		21,445		—		1,121		—		69,121

Six Months Ended June 30, 2019

Revenues - Outside	$	676,899	$	319,648	$	23,156	$	23,953	$	—	$	1,043,656
Revenues - Intercompany		8,170		—		—		6,199		(14,369)		—
Total revenues (2)		685,069		319,648		23,156		30,152		(14,369)		1,043,656

Segment Adjusted EBITDA Expense (3)		405,731		204,871		3,592		18,148		(9,888)		622,454
Segment Adjusted EBITDA (4)		218,812		112,434		20,230		24,912		(4,481)		371,907
Total assets		1,407,019		483,265		516,503		460,353		(364,419)		2,502,721
Capital expenditures (5)		107,930		54,333		—		3,364		—		165,627

Six Months Ended June 30, 2018

Revenues - Outside	$	627,650	$	312,377	$	—	$	33,232	$	—	$	973,259
Revenues - Intercompany		12,211		67		—		6,320		(18,598)		—
Total revenues (2)		639,861		312,444		—		39,552		(18,598)		973,259

Segment Adjusted EBITDA Expense (3)		386,347		196,036		—		23,275		(14,388)		591,270
Segment Adjusted EBITDA (4)		208,917		113,690		8,240		23,853		(4,210)		350,490
Total assets		1,440,776		454,972		158,376		394,175		(182,465)		2,265,834
Capital expenditures		84,034		34,820		—		1,792		—		120,646

(1)

The elimination column represents the elimination of intercompany transactions and is primarily comprised of sales from the Matrix Group to our mining operations, coal sales and purchases between operations within different segments, sales of receivables to AROP Funding, financing between segments and insurance premiums paid to Wildcat Insurance.

(2)	Revenues included in the Other and Corporate column are primarily attributable to the Matrix Group revenues, administrative service revenues from affiliates, Wildcat Insurance revenues and brokerage coal sales.

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(3)	Segment Adjusted EBITDA Expense includes operating expenses, coal purchases and other income. Transportation expenses are excluded as these expenses are recognized in an amount equal to transportation revenues when title passes to the customer.

The following is a reconciliation of consolidated Segment Adjusted EBITDA Expense to Operating expenses (excluding depreciation, depletion and amortization):


	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2019		2018		2019		2018
	(in thousands)
Segment Adjusted EBITDA Expense	$	319,597	$	311,811	$	622,454	$	591,270
Outside coal purchases		(5,311)		(68)		(5,311)		(1,442)
Other expense		(13)		(542)		(142)		(1,389)
Operating expenses (excluding depreciation, depletion and amortization)	$	314,273	$	311,201	$	617,001	$	588,439

(4)

Segment Adjusted EBITDA is defined as net income attributable to ARLP before net interest expense, income taxes, depreciation, depletion and amortization, general and administrative expenses, settlement gain and acquisition gain. Management therefore is able to focus solely on the evaluation of segment operating profitability as it relates to our revenues and operating expenses, which are primarily controlled by our segments. Consolidated Segment Adjusted EBITDA is reconciled to net income as follows:


	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2019		2018		2019		2018
	(in thousands)
Consolidated Segment Adjusted EBITDA	$	165,263	$	185,300	$	371,907	$	350,490
General and administrative		(19,521)		(17,026)		(37,333)		(33,677)
Depreciation, depletion and amortization		(76,913)		(72,150)		(148,052)		(133,998)
Settlement gain		—		—		—		80,000
Interest expense, net		(10,573)		(9,931)		(21,904)		(20,724)
Acquisition gain		—		—		177,043		—
Income tax (expense) benefit		(186)		(3)		(80)		7
Acquisition gain attributable to noncontrolling interest		—		—		(7,083)		—
Net income attributable to ARLP	$	58,070	$	86,190	$	334,498	$	242,098
Noncontrolling interest		114		187		7,290		335
Net income	$	58,184	$	86,377	$	341,788	$	242,433

(5)	Capital Expenditures shown exclude the AllDale Acquisition on January 3, 2019 (Note 3 – Acquisitions) and the escrow payment made in connection with the Wing Acquisition (Note 18 – Subsequent Events).

18.SUBSEQUENT EVENTS

Other than those events described below and in Notes 11 and 16, there were no subsequent events.

Wing Acquisition

On June 21, 2019, ARLP entered into an agreement with Wing Resources LLC and Wing Resources II LLC (collectively, "Wing") to acquire certain mineral interests. The agreement provides for the acquisition of approximately 9,000 net royalty acres in the Midland Basin, with exposure to more than 400,000 gross acres, for a cash purchase price of $145 million (the "Wing Acquisition") before consideration of typical closing adjustments for due diligence and the net cash impact related to a May 1, 2019 effective date, among other adjustments. Upon entering into the agreement, we provided a cash deposit of $10.9 million, which was held in escrow and applied to the purchase price upon closing of the transaction. On August 2, 2019, ARLP closed on the Wing Acquisition using cash on hand and borrowings under our Revolving Credit Facility.

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

Significant relationships referenced in this management's discussion and analysis of financial condition and results of operations include the following:

●

References to "we," "us," "our" or "ARLP Partnership" mean the business and operations of Alliance Resource Partners, L.P., the parent company, as well as its consolidated subsidiaries.

●

References to "ARLP" mean Alliance Resource Partners, L.P., individually as the parent company, and not on a consolidated basis.

●

References to "MGP" mean Alliance Resource Management GP, LLC, ARLP's general partner.

●

References to "Intermediate Partnership" mean Alliance Resource Operating Partners, L.P., the intermediate partnership of Alliance Resource Partners, L.P.

●

References to "Alliance Resource Properties" mean Alliance Resource Properties, LLC, the land-holding company for the mining operations of Alliance Resource Operating Partners, L.P.

●

References to "Alliance Coal" mean Alliance Coal, LLC, the holding company for the mining operations of Alliance Resource Operating Partners, L.P.

Summary

We have three reportable segments, Illinois Basin, Appalachia and Minerals. We also have an "all other" category referred to as Other and Corporate. The two coal reportable segments correspond to major coal producing regions in the eastern United States with similar economic characteristics including coal quality, geology, coal marketing opportunities, mining and transportation methods and regulatory issues. The two coal mining segments include eight underground mining complexes in Illinois, Indiana, Kentucky, Maryland and West Virginia and a coal loading terminal in Indiana on the Ohio River. The Minerals segment includes our oil & gas mineral interests which are located primarily in the Anadarko (SCOOP/STACK), Permian (Delaware and Midland), Williston (Bakken) and Appalachian basins. We have no operations within our Minerals reportable segment other than receiving royalties for our oil & gas mineral interests.

On January 3, 2019 (the "AllDale Acquisition Date"), we acquired all of the limited partner interests not owned by Cavalier Minerals JV, LLC ("Cavalier Minerals") in AllDale Minerals LP ("AllDale I") and AllDale Minerals II, LP ("AllDale II", and collectively with AllDale I, "AllDale I & II") and the general partner interests in AllDale I & II for $176.0 million (the "AllDale Acquisition"). As a result of the AllDale Acquisition and our previous investments held through Cavalier Minerals, we now control approximately 43,000 net royalty acres in premier oil & gas resource plays. The AllDale Acquisition provides us with diversified exposure to industry leading operators and is consistent with our general business strategy to pursue accretive acquisitions. Please read “Item 1. Financial Statements (Unaudited) - Note 3 – Acquisition” of this Quarterly Report on Form 10-Q for more information on the AllDale Acquisition.

As a result of the AllDale Acquisition, we now control the underlying oil & gas mineral interests held by AllDale I & II. This control over the oil & gas mineral interests held by AllDale I & II reflects a strategic change in how we manage our business and how resources are allocated by our chief operating decision maker. Due to this strategic change we have restructured our reportable segments in the first quarter of 2019 to include our oil & gas mineral interests within a new Minerals reportable segment. We have also included our Mt. Vernon Transfer Terminal, LLC ("Mt. Vernon") and Mid-America Carbonates, LLC ("MAC") in the Illinois Basin reportable segment rather than Other and Corporate to better align our Illinois Basin related activities. Prior periods have been recast to include our oil & gas minerals interests in the Minerals segment, and Mt. Vernon and MAC in the Illinois Basin segment.

●

Illinois Basin reportable segment includes currently operating mining complexes (a) Webster County Coal, LLC's Dotiki mining complex ("Dotiki"), (b) Gibson County Coal, LLC's mining complex, which includes the Gibson

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North and Gibson South mines, (c) Warrior Coal, LLC's mining complex, (d) River View Coal, LLC's mining complex ("River View") and (e) Hamilton County Coal, LLC's mining complex ("Hamilton"). The Illinois Basin reportable segment also includes our currently operating Mt. Vernon coal loading terminal in Indiana on the Ohio River. The Gibson North mine had been idled since the fourth quarter of 2015 in response to market conditions but resumed production in May 2018.

The Illinois Basin reportable segment also includes MAC's manufacturing and sales (primarily to our mines) of rock dust, CR Services, LLC, CR Machine Shop, LLC, certain properties and equipment of Alliance Resource Properties, ARP Sebree, LLC, ARP Sebree South, LLC, UC Coal, LLC and its subsidiaries, UC Mining, LLC and UC Processing, LLC (collectively "UC Coal") and our mining complexes currently not operating: (a) White County Coal, LLC's Pattiki mining complex ("Pattiki"), (b) Hopkins County Coal, LLC's mining complex, which includes the Elk Creek mine, the Pleasant View surface mineable reserves and the Fies underground project and (c) Sebree Mining, LLC's mining complex, which includes the Onton mine, Steamport, LLC and certain reserves.

●

Appalachia reportable segment includes currently operating mining complexes (a) Mettiki mining complex ("Mettiki"), (b) Tunnel Ridge, LLC mining complex ("Tunnel Ridge"), and (c) MC Mining, LLC mining complex ("MC Mining"). Mettiki includes Mettiki Coal (WV), LLC's Mountain View mine and Mettiki Coal, LLC's preparation plant. The Appalachia reportable segment also includes the Penn Ridge property and certain properties and equipment of Alliance Resource Properties.

●

Minerals reportable segment includes AllDale I & II; Alliance Royalty, LLC; AllRoy GP, LLC; CavMM, LLC; and Alliance Minerals, LLC's ("Alliance Minerals") equity interests in AllDale Minerals III, LP ("AllDale III") and Cavalier Minerals. Please read "Item 1 - Financial Statements (Unaudited) - Note 10 – Investments" and "Note 9 – Variable Interest Entities" of this Quarterly Report on Form 10-Q for more information on Alliance Minerals and Cavalier Minerals.

●

Other and Corporate includes marketing and administrative activities, Alliance Service, Inc. ("ASI") and its subsidiary, Matrix Design Group, LLC and its subsidiaries Matrix Design International, LLC and Matrix Design Africa (PTY) LTD ("Matrix Design"), Alliance Design Group, LLC (collectively along with Matrix Design, the "Matrix Group"), ASI's ownership of aircraft, Alliance Coal's coal brokerage activity, Alliance Minerals' equity investment in Kodiak Gas Services, LLC ("Kodiak") which was redeemed in February 2019 by Kodiak (see Note 10 – Investments) certain of Alliance Resource Properties' land and mineral interest activities, Pontiki Coal, LLC's legacy workers' compensation and pneumoconiosis liabilities, Wildcat Insurance, LLC, which assists the ARLP Partnership with its insurance requirements, AROP Funding, LLC ("AROP Funding") and Alliance Resource Finance Corporation ("Alliance Finance"). Please read "Item 1. Financial Statements (Unaudited) – Note 8. Long-term Debt" "and Note 10. Investments" of this Quarterly Report on Form 10-Q for more information on AROP Funding and the Kodiak redemption, respectively.

Three Months Ended June 30, 2019 Compared to Three Months Ended June 30, 2018

We reported net income attributable to ARLP of $58.1 million for the three months ended June 30, 2019 ("2019 Quarter") compared to $86.2 million for the three months ended June 30, 2018 ("2018 Quarter"). The decrease of $28.1 million was primarily due to lower coal sales, higher total operating expenses and lower equity securities income in the 2019 Quarter. Total revenues increased slightly to $517.1 million in the 2019 Quarter compared to $516.1 million for the 2018 Quarter, as the addition of oil & gas royalties and increased transportation revenues were partially offset by reduced coal sales.


	Three Months Ended June 30,
	2019		2018		2019		2018
	(in thousands)				(per ton sold)
Tons sold		10,216		10,488		N/A		N/A
Tons produced		10,036		9,714		N/A		N/A
Coal sales	$	461,310	$	475,925	$	45.16	$	45.38
Coal - Segment Adjusted EBITDA Expense (1) (2)	$	317,832	$	311,811	$	31.11	$	29.73

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(1)	For a definition of Segment Adjusted EBITDA Expense and related reconciliation to comparable generally accepted accounting principles ("GAAP") financial measures, please see below under "—Reconciliation of non-GAAP "Segment Adjusted EBITDA Expense" to GAAP "Operating Expenses."

(2)	Coal - Segment Adjusted EBITDA Expense is defined as consolidated Segment Adjusted EBITDA Expense excluding our Minerals segment.

Coal sales. Coal sales decreased $14.6 million or 3.1% to $461.3 million for the 2019 Quarter from $475.9 million for the 2018 Quarter. The decrease was attributable to a volume variance of $12.3 million resulting from decreased tons sold and a price variance of $2.3 million due to lower average coal sales prices. Coal sales volumes declined 2.6% to 10.2 million tons as flooding and high water continued to delay approximately 500,000 tons of planned export shipments in the 2019 Quarter which we expect will be shipped in the second half of the year. Also in comparison, the 2018 Quarter benefited from the fulfillment of 1.4 million tons in shipments delayed during the first quarter of 2018. Production volumes increased 3.3% compared to the 2018 Quarter to 10.0 million tons, primarily due to increased production from the addition of two mining units at our River View mine, strong performance at our Tunnel Ridge mine and a full quarter of production from our Gibson North mine, which resumed operations in the 2018 Quarter. Coal sales price realizations declined slightly in the 2019 Quarter to $45.16 per ton sold, compared to $45.38 per ton sold during the 2018 Quarter.

Royalty revenues. As a result of the AllDale Acquisition on January 3, 2019, we obtained control of AllDale I & II and thus began consolidation of AllDale I & II in our financial statements. As a result of the consolidation, in the first quarter of 2019 we began recording royalty revenues from AllDale I & II. Prior to 2019, our investments in AllDale I & II were accounted for as equity method investments. AllDale I & II contributed royalty revenues of $11.9 million in the 2019 Quarter. Please read "Item 1. Financial Statements (Unaudited) - Note 3 – Acquisition" of this Quarterly Report on Form 10-Q for more information on the AllDale Acquisition.

Coal - Segment Adjusted EBITDA Expense. Segment Adjusted EBITDA Expense, excluding our Minerals segment, of $317.8 million for the 2019 Quarter remained comparable to the 2018 Quarter. On a per ton basis, Segment Adjusted EBITDA Expense, excluding our Minerals segment, increased to $31.11 per ton sold compared to $29.73 per ton sold in the 2018 Quarter due to a longwall move at our Hamilton mine, lower recoveries at our River View mine due to adverse geological conditions, higher coal inventory costs and sales of higher-cost, outside coal purchases, partially offset by reduced expenses per ton resulting from strong production at our Tunnel Ridge mine. In addition, other cost increases are discussed by category below:

●

Labor and benefit expenses per ton produced, excluding workers' compensation, increased 6.3% to $9.83 per ton in the 2019 Quarter from $9.25 per ton in the 2018 Quarter. The increase of $0.58 per ton was primarily due to additional labor expenses at our River View mine in addition to the impact of a longwall move at our Hamilton mine in the 2019 Quarter; and

●

Workers' compensation expenses per ton produced increased to $0.82 per ton in the 2019 Quarter from $0.45 per ton in the 2018 Quarter. The increase of $0.37 per ton produced resulted from the impact of lower discount rates and adverse claims experience on mid-year actuarial workers' compensation accrual adjustments.

Segment Adjusted EBITDA Expense increases above were partially offset by the following decreases:

●

Material and supplies expenses per ton produced decreased 1.9% to $11.24 per ton in the 2019 Quarter from $11.46 per ton in the 2018 Quarter. The decrease of $0.22 per ton produced resulted primarily from decreases of $0.11 per ton for power and fuel used in the mining process and $0.10 per ton in longwall subsidence expense; and

●

Production taxes and royalty expenses incurred as a percentage of coal sales prices and volumes decreased $0.56 per produced ton sold in the 2019 Quarter compared to the 2018 Quarter primarily as a result of a favorable state production mix and a lower federal excise tax rate in 2019.

General and administrative. General and administrative expenses for the 2019 Quarter increased to $19.5 million compared to $17.0 million in the 2018 Quarter. The increase of $2.5 million was primarily due to higher professional services resulting from the AllDale Acquisition and increased benefit accruals.

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Depreciation, depletion and amortization. Depreciation, depletion and amortization expense increased to $76.9 million in the 2019 Quarter from $72.2 million in the 2018 Quarter. The increase of $4.7 million resulted primarily from production from our AllDale I & II oil & gas mineral interests.

Equity method investment income. Equity method investment income decreased to $0.6 million in the 2019 Quarter from $4.8 million in the 2018 Quarter as a result of the AllDale Acquisition and related consolidation of AllDale I & II in 2019. Prior to 2019, our investments in AllDale I & II were accounted for as equity method investments.

Equity securities income. Equity securities income decreased $3.9 million compared to the 2018 Quarter as we did not recognize equity securities income in the 2019 Quarter due to the redemption of our preferred interest in Kodiak in the first quarter of 2019.

Transportation revenues and expenses. Transportation revenues and expenses were $32.6 million and $27.5 million for the 2019 and 2018 Quarters, respectively. The increase of $5.1 million was primarily attributable to an increase in average third-party transportation rates in the 2019 Quarter resulting from higher shipping costs for coal exported to international markets, partially offset by decreased tonnage for which we arrange third-party transportation at certain mines. The cost of third-party transportation services are passed through to our customers and we recognize transportation revenue equal to transportation expense when title to the coal passes to the customer.

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Segment Adjusted EBITDA. Our 2019 Quarter Segment Adjusted EBITDA decreased $20.0 million, or 10.8%, to $165.3 million from the 2018 Quarter Segment Adjusted EBITDA of $185.3 million. Segment Adjusted EBITDA, tons sold, coal sales, other revenues, royalty revenues, BOE volume and Segment Adjusted EBITDA Expense by segment are as follows:


	Three Months Ended
	June 30,
	2019		2018		Increase (Decrease)
	(in thousands)
Segment Adjusted EBITDA
Coal - Illinois Basin	$	96,075	$	111,967	$	(15,892)	(14.2)	%
Coal - Appalachia		53,779		60,069		(6,290)	(10.5)	%
Minerals		11,098		4,652		6,446	(1)
Other and Corporate		6,551		10,717		(4,166)	(38.9)	%
Elimination		(2,240)		(2,105)		(135)	(6.4)	%
Total Segment Adjusted EBITDA (2)	$	165,263	$	185,300	$	(20,037)	(10.8)	%

Tons sold
Coal - Illinois Basin		7,567		7,820		(253)	(3.2)	%
Coal - Appalachia		2,649		2,666		(17)	(0.6)	%
Other and Corporate		142		222		(80)	(36.0)	%
Elimination		(142)		(220)		78	35.5	%
Total tons sold		10,216		10,488		(272)	(2.6)	%

Coal sales
Coal - Illinois Basin	$	301,981	$	310,464	$	(8,483)	(2.7)	%
Coal - Appalachia		157,951		162,886		(4,935)	(3.0)	%
Other and Corporate		5,551		9,398		(3,847)	(40.9)	%
Elimination		(4,173)		(6,823)		2,650	38.8	%
Total coal sales	$	461,310	$	475,925	$	(14,615)	(3.1)	%

Other revenues
Coal - Illinois Basin	$	2,405	$	4,388	$	(1,983)	(45.2)	%
Coal - Appalachia		950		723		227	31.4	%
Minerals		536		—		536	(1)
Other and Corporate		10,439		10,600		(161)	(1.5)	%
Elimination		(3,108)		(3,031)		(77)	(2.5)	%
Total other sales and operating revenues	$	11,222	$	12,680	$	(1,458)	(11.5)	%

Royalty revenues and BOE volume
Volume - BOE (3)		274		—		274	(1)
Oil & gas royalties	$	11,892	$	—	$	11,892	(1)

Segment Adjusted EBITDA Expense
Coal - Illinois Basin	$	208,309	$	202,886	$	5,423	2.7	%
Coal - Appalachia		105,122		103,538		1,584	1.5	%
Minerals		1,765		—		1,765	(1)
Other and Corporate		9,442		13,136		(3,694)	(28.1)	%
Elimination		(5,041)		(7,749)		2,708	34.9	%
Total Segment Adjusted EBITDA Expense (2)	$	319,597	$	311,811	$	7,786	2.5	%

(1)	Percentage change not meaningful.

(2)	For a definition of Segment Adjusted EBITDA and related reconciliation to comparable GAAP financial measures, please see below under "—Reconciliation of non-GAAP "Segment Adjusted EBITDA" to GAAP "net income."

(3)	Barrels of oil equivalent ("BOE") is calculated on a 6:1 basis (6,000 cubic feet of natural gas to one barrel of oil).

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Illinois Basin – Segment Adjusted EBITDA decreased 14.2% to $96.1 million in the 2019 Quarter from $112.0 million in the 2018 Quarter. The decrease of $15.9 million was primarily attributable to lower coal sales, which decreased 2.7% to $302.0 million in the 2019 Quarter from $310.5 million in the 2018 Quarter, and increased operating expenses. The decrease of $8.5 million in coal sales reflects decreased coal sales volumes partially offset by higher price realizations. Tons sold in the 2019 Quarter decreased 3.2% compared to the 2018 Quarter as a result of lower volumes at our Hamilton and Gibson South mines due to reduced export sales, as well as significant fulfillments in the 2018 Quarter of delayed first quarter 2018 shipments, partially offset by increased domestic sales volumes from our Gibson North and River View mines. Segment Adjusted EBITDA Expense increased 2.7% to $208.3 million in the 2019 Quarter from $202.9 million in the 2018 Quarter due to higher expenses per ton. Segment Adjusted EBITDA Expense per ton increased $1.59 per ton sold to $27.53 from $25.94 per ton sold in the 2018 Quarter, primarily due to a longwall move at our Hamilton mine, as well as reduced recoveries and per ton cost increases for labor and materials and supplies expenses at our River View mine during the 2019 Quarter in addition to certain cost increases described above under "–Coal - Segment Adjusted EBITDA Expense."

Appalachia – Segment Adjusted EBITDA decreased 10.5% to $53.8 million for the 2019 Quarter from $60.1 million in the 2018 Quarter. The decrease of $6.3 million was primarily attributable to lower coal sales, which decreased 3.0% to $158.0 million in the 2019 Quarter from $162.9 million in the 2018 Quarter. The decrease of $4.9 million in coal sales resulted primarily from lower coal sale prices, which decreased 2.4% compared to the 2018 Quarter due to decreased export price realizations and export volumes at our Mettiki mine, partially offset by increased domestic prices from our MC Mining operation. Segment Adjusted EBITDA Expense increased slightly to $105.1 million in the 2019 Quarter from $103.5 million in the 2018 Quarter due to higher expenses per ton. Segment Adjusted EBITDA Expense per ton increased $0.84 per ton sold to $39.68 compared to $38.84 per ton sold in the 2018 Quarter, primarily due to reduced recoveries at our Mettiki and MC Mining mines and sales of higher cost outside coal purchases, as well as certain cost increases described above under "–Coal - Segment Adjusted EBITDA Expense," partially offset by strong production at our Tunnel Ridge mine during the 2019 Quarter.

Minerals – Segment Adjusted EBITDA increased to $11.1 million for the 2019 Quarter from $4.7 million in the 2018 Quarter. The increase of $6.4 million primarily resulted from the AllDale Acquisition in 2019.

Other and Corporate – Segment Adjusted EBITDA decreased by $4.1 million to $6.6 million in the 2019 Quarter compared to $10.7 million in the 2018 Quarter. The decrease was primarily attributable to lower equity securities income as a result of the redemption of our preferred interest in Kodiak in the first quarter of 2019 and decreased coal brokerage activity.

Six Months Ended June 30, 2019 Compared to Six Months Ended June 30, 2018

We reported net income attributable to ARLP of $334.5 million for the six months ended June 30, 2019 ("2019 Period") compared to $242.1 million for the six months ended June 30, 2018 ("2018 Period"). The increase of $92.4 million was primarily due to higher revenues and gains related to the AllDale Acquisition and the redemption of our preferred equity interest in Kodiak. Increased coal sales volumes, improved coal sales prices and the addition of royalty revenues in the 2019 Period drove total revenues higher to $1.04 billion compared to $0.97 billion in the 2018 Period.


	Six Months Ended June 30,
	2019		2018		2019		2018
	(in thousands)				(per ton sold)
Tons sold		20,537		19,886		N/A		N/A
Tons produced		21,359		20,196		N/A		N/A
Coal sales	$	937,326	$	899,535	$	45.64	$	45.23
Coal - Segment Adjusted EBITDA Expense (1) (2)	$	618,862	$	591,270	$	30.13	$	29.73

(1)	For a definition of Segment Adjusted EBITDA Expense and related reconciliation to comparable GAAP financial measures, please see below under "—Reconciliation of non-GAAP "Segment Adjusted EBITDA Expense" to GAAP "Operating Expenses."

(2)	Coal - Segment Adjusted EBITDA Expense is defined as consolidated Segment Adjusted EBITDA Expense excluding our Minerals segment.

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Coal sales. Coal sales increased $37.8 million or 4.2% to $937.3 million for the 2019 Period from $899.5 million for the 2018 Period. The increase was attributable to a volume variance of $29.5 million resulting from increased tons sold and a price variance of $8.3 million due to higher average coal sales prices. For the 2019 Period, a strong performance at our Tunnel Ridge mine, increased volumes from our River View mine due to the additional two production units previously mentioned and the resumption of operations in the 2018 Period at our Gibson North mine drove coal sales volumes up by 3.3% to 20.5 million tons and production volumes higher by 5.8% to 21.4 million tons, both as compared to the 2018 Period. Total coal sales volumes benefited from increased domestic shipments offset in part by a reduction in export volumes as flooding and high water continued to delay approximately 500,000 tons of planned export shipments in the 2019 Period, which we expect will be shipped in the second half of the year. Coal sales price realizations increased 0.9% to $45.64 per ton sold in the 2019 Period, compared to $45.23 per ton sold during the 2018 Period.

Royalty revenues. AllDale I & II contributed royalty revenues of $22.3 million in the 2019 Period. Please read "Item 1. Financial Statements (Unaudited) - Note 3 – Acquisition" of this Quarterly Report on Form 10-Q for more information on the AllDale Acquisition.

Coal - Segment Adjusted EBITDA Expense. Segment Adjusted EBITDA Expense, excluding our Minerals segment, increased 4.7% to $618.9 million for the 2019 Period from $591.3 million for the 2018 Period primarily as a result of increased coal sales volumes. On a per ton basis, Segment Adjusted EBITDA Expense, excluding our Minerals segment, increased to $30.13 per ton sold compared to $29.73 per ton sold in the 2018 Period due to a longwall move in the 2019 Period at our Hamilton mine and lower recoveries and mining conditions at certain mines in addition to other cost increases, which are discussed by category below:

●

Labor and benefit expenses per ton produced, excluding workers' compensation, increased 4.4% to $9.35 per ton in the 2019 Period from $8.96 per ton in the 2018 Period. The increase of $0.39 per ton was primarily due to additional labor expenses at our River View mine in addition to the impact of a longwall move at our Hamilton mine in the 2019 Period and other production variances previously discussed;

●

Workers' compensation expenses per ton produced increased to $0.55 per ton in the 2019 Period from $0.45 per ton in the 2018 Period. The increase of $0.10 per ton produced resulted from increased workers' compensation expense due to the impact of lower discount rates and adverse claims experience on mid-year actuarial adjustments; and

●

Material and supplies expenses per ton produced increased 2.0% to $11.12 per ton in the 2019 Period from $10.90 per ton in the 2018 Period. The increase of $0.22 per ton produced resulted primarily from increases of $0.25 per ton in longwall subsidence expense and $0.21 per ton for roof support, partially offset by a decrease of $0.18 per ton for power and fuel used in the mining process.

Segment Adjusted EBITDA Expense increases above were partially offset by the following decrease:

●

Production taxes and royalty expenses incurred as a percentage of coal sales prices and volumes decreased $0.69 per produced ton sold in the 2019 Period compared to the 2018 Period primarily as a result of a favorable state production mix and a lower federal excise tax rate in 2019.

General and administrative. General and administrative expenses for the 2019 Period increased to $37.3 million compared to $33.7 million in the 2018 Period. The increase of $3.6 million was due to higher professional services primarily resulting from the AllDale Acquisition and increased benefit accruals.

Depreciation, depletion and amortization. Depreciation, depletion and amortization expense increased to $148.1 million in the 2019 Period from $134.0 million in the 2018 Period. The increase of $14.1 million resulted primarily from increased coal sales volumes mentioned above and depletion beginning in the 2019 Period, attributable to production from our AllDale I & II oil & gas mineral interests.

Settlement gain. During the 2018 Period, we finalized an agreement with a customer and certain of its affiliates to settle litigation we initiated in 2015. The agreement provided for a $93.0 million cash payment to us in the 2018 Period, future conditional coal supply commitments, continued export transloading capacity for our Appalachian mines and the acquisition of certain coal reserves near our Tunnel Ridge operation. A settlement gain of $80.0 million was recorded in

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the 2018 Period reflecting the cash payment received net of $13.0 million of combined legal fees paid and associated incentive compensation accruals.

Equity method investment income. Equity method investment income decreased to $0.9 million in the 2019 Period from $8.6 million in the 2018 Period as a result of the AllDale Acquisition and related consolidation of AllDale I & II in the 2019 Period. Prior to 2019, our investments in AllDale I & II were accounted for as equity method investments.

Acquisition gain. We were required to re-measure Cavalier Minerals' equity method investments in AllDale I & II to fair value as a result of the AllDale Acquisition. The re-measurement resulted in a gain of $177.0 million in the 2019 Period.

Transportation revenues and expenses. Transportation revenues and expenses were $62.9 million and $47.3 million for the 2019 and 2018 Periods, respectively. The increase of $15.6 million was primarily attributable to an increase in average third-party transportation rates in the 2019 Period resulting from higher shipping costs for coal exported to international markets, partially offset by decreased tonnage for which we arrange third-party transportation at certain mines. The cost of third-party transportation services are passed through to our customers and we recognize transportation revenue equal to transportation expense when title to the coal passes to the customer.

Net income attributable to noncontrolling interest. Net income attributable to noncontrolling interest increased to $7.3 million in the 2019 Period from $0.3 million in the 2018 Period as a result of allocating $7.1 million of the acquisition gain discussed above to noncontrolling interest related to Bluegrass Minerals' equity interest in Cavalier Minerals.

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Segment Adjusted EBITDA. Our 2019 Period Segment Adjusted EBITDA increased $21.4 million, or 6.1%, to $371.9 million from the 2018 Period Segment Adjusted EBITDA of $350.5 million. Segment Adjusted EBITDA, tons sold, coal sales, other revenues, royalty revenues, BOE volume and Segment Adjusted EBITDA Expense by segment are as follows:


	Six Months Ended
	June 30,
	2019		2018		Increase (Decrease)
	(in thousands)
Segment Adjusted EBITDA
Coal - Illinois Basin	$	218,812	$	208,917	$	9,895	4.7	%
Coal - Appalachia		112,434		113,690		(1,256)	(1.1)	%
Minerals		20,230		8,240		11,990	(1)
Other and Corporate		24,912		23,853		1,059	4.4	%
Elimination		(4,481)		(4,210)		(271)	(6.4)	%
Total Segment Adjusted EBITDA (2)	$	371,907	$	350,490	$	21,417	6.1	%

Tons sold
Coal - Illinois Basin		15,240		14,828		412	2.8	%
Coal - Appalachia		5,297		5,056		241	4.8	%
Other and Corporate		278		403		(125)	(31.0)	%
Elimination		(278)		(401)		123	30.7	%
Total tons sold		20,537		19,886		651	3.3	%

Coal sales
Coal - Illinois Basin	$	619,251	$	586,529	$	32,722	5.6	%
Coal - Appalachia		315,404		308,175		7,229	2.3	%
Other and Corporate		10,841		17,109		(6,268)	(36.6)	%
Elimination		(8,170)		(12,278)		4,108	33.5	%
Total coal sales	$	937,326	$	899,535	$	37,791	4.2	%

Other revenues
Coal - Illinois Basin	$	5,293	$	8,734	$	(3,441)	(39.4)	%
Coal - Appalachia		1,901		1,552		349	22.5	%
Minerals		871		—		871	(1)
Other and Corporate		19,311		22,441		(3,130)	(13.9)	%
Elimination		(6,199)		(6,320)		121	1.9	%
Total other sales and operating revenues	$	21,177	$	26,407	$	(5,230)	(19.8)	%

Royalty revenues and BOE volume
Volume - BOE (3)		526		—		526	(1)
Oil & gas royalties	$	22,285	$	—	$	22,285	(1)

Segment Adjusted EBITDA Expense
Coal - Illinois Basin	$	405,731	$	386,347	$	19,384	5.0	%
Coal - Appalachia		204,871		196,036		8,835	4.5	%
Minerals		3,592		—		3,592	(1)
Other and Corporate		18,148		23,275		(5,127)	(22.0)	%
Elimination		(9,888)		(14,388)		4,500	31.3	%
Total Segment Adjusted EBITDA Expense	$	622,454	$	591,270	$	31,184	5.3	%

(1)	Percentage change not meaningful.

(2)	For a definition of Segment Adjusted EBITDA and related reconciliation to comparable GAAP financial measures, please see below under "—Reconciliation of non-GAAP "Segment Adjusted EBITDA" to GAAP "net income."

(3)	Barrels of oil equivalent ("BOE") is calculated on a 6:1 basis (6,000 cubic feet of natural gas to one barrel of oil).

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Illinois Basin – Segment Adjusted EBITDA increased 4.7% to $218.8 million in the 2019 Period from $208.9 million in the 2018 Period. The increase of $9.9 million was primarily attributable to higher coal sales, which increased 5.6% to $619.3 million in the 2019 Period from $586.5 million in the 2018 Period, partially offset by increased operating expenses and lower operating revenues from our Mt. Vernon transloading facility. The increase of $32.8 million in coal sales reflects higher coal sales volumes and prices. The resumption of operations at our Gibson North mine in the 2018 Period and the addition of two production units at the River View mine in the second half of 2018 drove Illinois Basin coal sales volumes in the 2019 Period higher by 2.8% to 15.2 million tons compared to 14.8 million tons sold in the 2018 Period. Coal sales volumes also benefited from increased domestic shipments, offset in part by a reduction in export volumes due to weather disruptions throughout the first half of 2019, which also reduced transloading tonnage running through our Mt. Vernon facility. Coal sales price per ton sold in the 2019 Period increased 2.7% due to higher export sales prices compared to the 2018 Period. Segment Adjusted EBITDA Expense increased 5.0% to $405.7 million in the 2019 Period from $386.3 million in the 2018 Period due to increased sales volumes and higher expenses per ton. Segment Adjusted EBITDA Expense per ton increased $0.56 per ton sold to $26.62 from $26.06 per ton sold in the 2018 Period, primarily due to a longwall move at our Hamilton mine and reduced recoveries at our River View mine during the 2019 Period, as well as certain per ton cost increases described above under "–Coal - Segment Adjusted EBITDA Expense."

Appalachia – Segment Adjusted EBITDA decreased 1.1% to $112.4 million for the 2019 Period from $113.7 million in the 2018 Period. The decrease of $1.3 million was primarily attributable to reduced coal sales prices and increased operating expenses, partially offset by higher coal sales volumes. Coal sales, which increased 2.3% to $315.4 million in the 2019 Period from $308.2 million in the 2018 Period resulted from higher coal sales volumes of 5.3 million tons sold in the 2019 Period, compared to 5.1 million tons sold in the 2018 Period, as a result of a strong performance at our Tunnel Ridge longwall operation, partially offset by lower coal sales prices. Segment Adjusted EBITDA Expense increased 4.5% to $204.9 million in the 2019 Period from $196.0 million in the 2018 Period due to increased sales volumes. Segment Adjusted EBITDA Expense per ton decreased slightly to $38.68 per ton compared to $38.77 per ton sold in the 2018 Period reflecting the strong production and sales performance at our Tunnel Ridge mine and certain cost variances described above under "–Coal - Segment Adjusted EBITDA Expense."

Minerals – Segment Adjusted EBITDA increased to $20.2 million for the 2019 Period from $8.2 million in the 2018 Period. The increase of $12.0 million primarily resulted from the AllDale Acquisition in the 2019 Period.

Other and Corporate – Segment Adjusted EBITDA increased by $1.0 million to $24.9 million in the 2019 Period compared to $23.9 million in the 2018 Period. The increase was primarily attributable to higher equity securities income in the 2019 Period as a result of the redemption of our preferred interest in Kodiak, which included an $11.5 million gain due to an early redemption premium, partially offset by reduced mining technology product sales from Matrix Group.

Reconciliation of non-GAAP "Segment Adjusted EBITDA" to GAAP "net income" and reconciliation of non-GAAP "Segment Adjusted EBITDA Expense" to GAAP "Operating Expenses"

Segment Adjusted EBITDA (a non-GAAP financial measure) is defined as net income attributable to ARLP before net interest expense, income taxes, depreciation, depletion and amortization, general and administrative expenses, settlement gain and acquisition gain. Segment Adjusted EBITDA is a key component of consolidated EBITDA, which is used as a supplemental financial measure by management and by external users of our financial statements such as investors, commercial banks, research analysts and others. We believe that the presentation of EBITDA provides useful information to investors regarding our performance and results of operations because EBITDA, when used in conjunction with related GAAP financial measures, (i) provides additional information about our core operating performance and ability to generate and distribute cash flow, (ii) provides investors with the financial analytical framework upon which we base financial, operational, compensation and planning decisions and (iii) presents a measurement that investors, rating agencies and debt holders have indicated is useful in assessing us and our results of operations.

Segment Adjusted EBITDA is also used as a supplemental financial measure by our management for reasons similar to those stated in the previous explanation of EBITDA. In addition, the exclusion of corporate general and administrative expenses from consolidated Segment Adjusted EBITDA allows management to focus solely on the evaluation of segment operating profitability as it relates to our revenues and operating expenses, which are primarily controlled by our segments.

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The following is a reconciliation of consolidated Segment Adjusted EBITDA to net income, the most comparable GAAP financial measure:


	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2019		2018		2019		2018
	(in thousands)
Consolidated Segment Adjusted EBITDA	$	165,263	$	185,300	$	371,907	$	350,490
General and administrative		(19,521)		(17,026)		(37,333)		(33,677)
Depreciation, depletion and amortization		(76,913)		(72,150)		(148,052)		(133,998)
Settlement gain		—		—		—		80,000
Interest expense, net		(10,573)		(9,931)		(21,904)		(20,724)
Acquisition gain		—		—		177,043		—
Income tax (expense) benefit		(186)		(3)		(80)		7
Acquisition gain attributable to noncontrolling interest		—		—		(7,083)		—
Net income attributable to ARLP	$	58,070	$	86,190	$	334,498	$	242,098
Noncontrolling interest		114		187		7,290		335
Net income	$	58,184	$	86,377	$	341,788	$	242,433

Segment Adjusted EBITDA Expense (a non-GAAP financial measure) includes operating expenses, coal purchases and other income. Transportation expenses are excluded as these expenses are passed through to our customers and, consequently, we do not realize any gain or loss on transportation revenues. Segment Adjusted EBITDA Expense is used as a supplemental financial measure by our management to assess the operating performance of our segments. Segment Adjusted EBITDA Expense is a key component of Segment Adjusted EBITDA in addition to coal sales, royalty revenues and other sales and operating revenues. The exclusion of corporate general and administrative expenses from Segment Adjusted EBITDA Expense allows management to focus solely on the evaluation of segment operating performance as it primarily relates to our operating expenses.

The following is a reconciliation of consolidated Segment Adjusted EBITDA Expense to operating expense, the most comparable GAAP financial measure:


	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2019		2018		2019		2018
	(in thousands)
Segment Adjusted EBITDA Expense	$	319,597	$	311,811	$	622,454	$	591,270
Outside coal purchases		(5,311)		(68)		(5,311)		(1,442)
Other expense		(13)		(542)		(142)		(1,389)
Operating expenses (excluding depreciation, depletion and amortization)	$	314,273	$	311,201	$	617,001	$	588,439

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Liquidity and Capital Resources

Liquidity

We have historically satisfied our working capital requirements and funded our capital expenditures, investments and debt service obligations with cash generated from operations, cash provided by the issuance of debt or equity, borrowings under credit and securitization facilities and other financing transactions. We believe that existing cash balances, future cash flows from operations and investments, borrowings under credit facilities and cash provided from the issuance of debt or equity will be sufficient to meet our working capital requirements, capital expenditures and additional investments, debt payments, commitments and distribution payments. Nevertheless, our ability to satisfy our working capital requirements, to fund planned capital expenditures, to service our debt obligations or to pay distributions will depend upon our future operating performance and access to and cost of financing sources, which will be affected by prevailing economic conditions generally and in the coal and oil & gas industries specifically, as well as other financial and business factors, some of which are beyond our control. Based on our recent operating results, current cash position, current unitholder distributions, anticipated future cash flows and sources of financing that we expect to have available, we do not anticipate any constraints to our liquidity at this time. However, to the extent operating cash flow or access to and cost of financing sources are materially different than expected, future liquidity may be adversely affected. Please read "Item 1A. Risk Factors" in our Annual Report on Form 10-K for the year ended December 31, 2018.

In May 2018, the MGP board of directors approved the establishment of a unit repurchase program authorizing us to repurchase up to $100 million of ARLP common units. The program has no time limit and we may repurchase units from time to time in the open market or in other privately negotiated transactions. The unit repurchase program authorization does not obligate us to repurchase any dollar amount or number of units. Please read "Part II - Item 2. Unregistered Sales of Equity Securities and Use of Proceeds" of this Quarterly Report on Form 10-Q for more information on unit repurchase program.

On January 3, 2019, we acquired all of the limited partner interests in AllDale I & II not owned by Cavalier Minerals and the general partner interests in AllDale I & II for $176.0 million, which was funded with cash on hand and borrowings under our revolving credit facility. On February 8, 2019, Kodiak redeemed our preferred equity interest for $135.0 million in cash. On August 2, 2019, we closed on the Wing Acquisition using cash on hand and borrowings under our revolving credit facility. For more information on these transactions, please read "Item 1. Financial Statements (Unaudited) – Note 3. Acquisition", "– Note 10. Investments" and "– Note 18. Subsequent Events" of this Quarterly Report on Form 10-Q.

Mine Development Project

We have begun development activity for MC Mining's Excel Mine No. 5 and currently anticipate deploying total capital of approximately $35.0 million to $40.0 million during 2019 with an additional $5.0 million to $10.0 million during the first half of 2020, which we expect to fund with cash from operations or borrowings under our credit facilities. We anticipate the new mine will enable us to access an additional 15 million tons of coal reserves with an expected mine life of approximately 12 years assuming the current level of production at MC Mining's Excel Mine No. 4 continues at the new mine. We expect the development plan for the new Excel Mine No. 5 will provide a seamless transition from the current MC Mining operation as its reserves deplete in 2020.

Cash Flows

Cash provided by operating activities was $301.7 million for the 2019 Period compared to $373.2 million for the 2018 Period. The decrease in cash provided by operating activities was primarily due to $93 million received in the 2018 Period for a one-time settlement related to litigation with a customer and certain of its affiliates initiated in 2015. The decrease also resulted from unfavorable working capital changes related to inventories, and payroll and related benefit accruals. The decreases were partially offset by a favorable working capital change related to accounts payable.

Net cash used in investing activities was $209.8 million for the 2019 Period compared to $128.0 million for the 2018 Period. The increase in cash used in investing activities was primarily attributable to the AllDale Acquisition, an escrow payment for the Wing Acquisition and increased capital expenditures for mine infrastructure and equipment at

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various mines. This increase was partially offset by cash received from the redemption of our equity securities in the 2019 Period and equity method investment contributions in the 2018 Period.

Net cash used in financing activities was $280.9 million for the 2019 Period compared to $200.8 million for the 2018 Period. The increase in cash used in financing activities was primarily attributable to increased overall net payments on the securitization and revolving credit facilities and an increase in withholding taxes on issuance of units primarily under our long-term incentive plan in the 2019 Period compared to the 2018 Period. These increases were partially offset by proceeds received in connection with equipment financing in the 2019 Period.

Capital Expenditures

Capital expenditures increased to $165.6 million in the 2019 Period from $120.7 million in the 2018 Period. See our discussion of "Cash Flows" above concerning the increase in capital expenditures.

We currently project average estimated annual maintenance capital expenditures over the five-year period beginning in January 2019 of approximately $5.57 per ton produced. Our anticipated total capital expenditures (including investments) for the year ending December 31, 2019 are estimated in a range of $345.0 million to $375.0 million, which includes expenditures for maintenance capital at various mines. Management anticipates funding remaining 2019 capital requirements with cash and cash equivalents ($55.2 million as of June 30, 2019), cash flows from operations and investments, borrowings under revolving credit and securitization facilities and cash provided from the issuance of debt or equity. We will continue to have significant capital requirements over the long-term, which may require us to incur debt or seek additional equity capital. The availability and cost of additional capital will depend upon prevailing market conditions, the market price of our common units and several other factors over which we have limited control, as well as our financial condition and results of operations.

Debt Obligations

Credit Agreement. On January 27, 2017, our Intermediate Partnership entered into a Fourth Amended and Restated Credit Agreement (the "Credit Agreement") with various financial institutions. The Credit Agreement provides for a $494.75 million revolving credit facility, including a sublimit of $125 million for the issuance of letters of credit and a sublimit of $15.0 million for swingline borrowings (the "Revolving Credit Facility"), with a termination date of May 23, 2021.

Senior Notes. On April 24, 2017, the Intermediate Partnership and Alliance Resource Finance Corporation (as co-issuer), a wholly owned subsidiary of the Intermediate Partnership ("Alliance Finance"), issued an aggregate principal amount of $400.0 million of senior unsecured notes due 2025 ("Senior Notes") in a private placement to qualified

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institutional buyers. The Senior Notes have a term of eight years, maturing on May 1, 2025 (the "Term") and accrue interest at an annual rate of 7.5%. Interest is payable semi-annually in arrears on each May 1 and November 1. The indenture governing the Senior Notes contains customary terms, events of default and covenants relating to, among other things, the incurrence of debt, the payment of distributions or similar restricted payments, undertaking transactions with affiliates and limitations on asset sales. At any time prior to May 1, 2020, the issuers of the Senior Notes may redeem up to 35% of the aggregate principal amount of the Senior Notes with the net cash proceeds of one or more equity offerings at a redemption price equal to 107.5% of the principal amount redeemed, plus accrued and unpaid interest, if any, to the redemption date. The issuers of the Senior Notes may also redeem all or a part of the notes at any time on or after May 1, 2020, at redemption prices set forth in the indenture governing the Senior Notes. At any time prior to May 1, 2020, the issuers of the Senior Notes may redeem the Senior Notes at a redemption price equal to the principal amount of the Senior Notes plus a "make-whole" premium, plus accrued and unpaid interest, if any, to the redemption date.

Accounts Receivable Securitization. On December 5, 2014, certain direct and indirect wholly owned subsidiaries of our Intermediate Partnership entered into a $100.0 million accounts receivable securitization facility ("Securitization Facility"). Under the Securitization Facility, certain subsidiaries sell trade receivables on an ongoing basis to our Intermediate Partnership, which then sells the trade receivables to AROP Funding, LLC ("AROP Funding"), a wholly owned bankruptcy-remote special purpose subsidiary of our Intermediate Partnership, which in turn borrows on a revolving basis up to $100.0 million secured by the trade receivables. After the sale, Alliance Coal, as servicer of the assets, collects the receivables on behalf of AROP Funding. The Securitization Facility bears interest based on a Eurodollar Rate. It was renewed in January 2019 and matures in January 2020. At June 30, 2019, we had $75.0 million outstanding balance under the Securitization Facility.

Cavalier Credit Agreement. On October 6, 2015, Cavalier Minerals (see Note 9 – Variable Interest Entities) entered into a credit agreement (the "Cavalier Credit Agreement") with Mineral Lending, LLC ("Mineral Lending") for a $100.0 million line of credit (the "Cavalier Credit Facility"). The commitment under the Cavalier Credit Facility is reduced by any distributions received from Cavalier Minerals' investment in AllDale II. As of June 30, 2019, the commitment under the Cavalier Credit Facility was $67.5 million. Mineral Lending is an entity owned by (a) Alliance Resource Holdings II, Inc. ("ARH II"), an entity owned by Joseph W. Craft III, the Chairman, President and Executive Officer of MGP ("Mr. Craft") and Kathleen S. Craft, (b) an entity owned by an individual who is an officer and director of ARH II and (c) charitable foundations established by Mr. Craft and Kathleen S. Craft. There is no commitment fee under the facility. Mineral Lending's obligation to make the line of credit available terminates no later than October 6, 2019. Borrowings under the Cavalier Credit Facility bear interest at a one month LIBOR rate plus 6% with interest payable quarterly, and mature on September 30, 2024, at which time all amounts then outstanding are required to be repaid. The Cavalier Credit Agreement requires repayment of the principal balance beginning in 2018, in quarterly payments of an amount equal to the greater of $1.3 million initially, escalated to $2.5 million after two years, or fifty percent of Cavalier Minerals' excess cash flow. To secure payment of the facility, Cavalier Minerals pledged all of its partnership interests, owned or later acquired, in AllDale I & II. Cavalier Minerals may prepay the Cavalier Credit Facility at any time in whole or in part subject to terms and conditions described in the Cavalier Credit Agreement. As of June 30, 2019, Cavalier Minerals had not drawn on the Cavalier Credit Facility.

Equipment Financing. On May 17, 2019, the Intermediate Partnership entered into an equipment financing arrangement accounted for as debt, wherein the Intermediate Partnership received $10.0 million in exchange for conveying its interest in certain equipment owned by an indirect wholly-owned subsidiary of the Intermediate Partnership and entering into a master lease agreement for that equipment (the “Equipment Financing”). The Equipment Financing contains customary terms and events of default and provides for thirty-six monthly payments with an implicit interest rate of 6.25%, maturing on May 1, 2022. Upon maturity, the equipment will revert back to the Intermediate Partnership.

Other. We also have an agreement with a bank to provide additional letters of credit in an amount of $5.0 million to maintain surety bonds to secure certain asset retirement obligations and our obligations for workers' compensation benefits. At June 30, 2019, we had $5.0 million in letters of credit outstanding under this agreement.

Related-Party Transactions

We have related-party transactions with MGP, ARH II and their respective affiliates. These related-party transactions relate principally to mineral leases with charitable foundations established by Mr. Craft and Kathleen S. Craft and agreements relating to the use of aircraft. We also have transactions with (a) WKY CoalPlay, LLC ("WKY CoalPlay") regarding three mineral leases, (b) Bluegrass Minerals Management, LLC ("Bluegrass Minerals") through its

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noncontrolling ownership interest in Cavalier Minerals and (c) AllDale III to support its acquisition of oil & gas mineral interests. For more information regarding WKY CoalPlay, Bluegrass Minerals and AllDale III, please read "Item 1. Financial Statements (Unaudited) – Note 9. Variable Interest Entities" and "– Note 10. Investments" of this Quarterly Report on Form 10-Q. Please read our Annual Report on Form 10-K for the year ended December 31, 2018, "Item 8. Financial Statements and Supplementary Data – Note 18. Related-Party Transactions" for additional information concerning related-party transactions.

Prior to the AllDale Acquisition and Kodiak redemption, we also had transactions with AllDale I & II to support their acquisition of oil & gas mineral interests, and Kodiak to support its gas compression services. For more information regarding the AllDale Acquisition and Kodiak redemption, please read "Item 1. Financial Statements (Unaudited) – Note 3. Acquisition" and "– Note 10. Investments" of this Quarterly Report on Form 10-Q.

New Accounting Standards

See "Item 1. Financial Statements (Unaudited) – Note 2. New Accounting Standards" of this Quarterly Report on Form 10-Q for a discussion of new accounting standards.

ITEM 3.

QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Commodity Price Risk

We have significant long-term coal supply agreements. Most of the long-term coal supply agreements are subject to price adjustment provisions, which periodically permit an increase or decrease in the contract price typically to reflect changes in specified indices or changes in production costs resulting from regulatory changes, or both.

Our results of operations are highly dependent upon the prices we receive for our coal. The short-term coal contracts favored by some of our customers leave us more exposed to risks of declining price periods. Also, a significant decline in oil and natural gas prices would have a significant impact on our royalty revenues.

We have exposure to coal, oil and natural gas sales prices and price risk for supplies that are used directly or indirectly in the normal course of coal and oil & gas production such as steel, electricity and other supplies. We manage our risk for these items through strategic sourcing contracts for normal quantities required by our operations. Historically, we have not utilized any commodity price-hedges or other derivatives related to either our sales price or supply cost risks.

Credit Risk

Most of our coal is sold to United States electric utilities or into the international markets through brokered transactions. Therefore, our credit risk is primarily with domestic electric power generators and reputable global brokerage firms. Our policy is to independently evaluate each customer's creditworthiness prior to entering into transactions and to constantly monitor outstanding accounts receivable against established credit limits. When deemed appropriate by our credit management department, we will take steps to reduce our credit exposure to customers that do not meet our credit standards or whose credit has deteriorated. These steps may include obtaining letters of credit or cash collateral, requiring prepayment for shipments or establishing customer trust accounts held for our benefit in the event of a failure to pay.

Exchange Rate Risk

Almost all of our transactions are denominated in United States dollars, and as a result, we do not have material exposure to currency exchange-rate risks. However, because coal is sold internationally in United States dollars, general economic conditions in foreign markets and changes in foreign currency exchange rates may provide our foreign competitors with a competitive advantage. If our competitors' currencies decline against the United States dollar or against foreign purchasers' local currencies, those competitors may be able to offer lower prices for coal to these purchasers. Furthermore, if the currencies of overseas purchasers were to significantly decline in value in comparison to the United States dollar, those purchasers may seek decreased prices for the coal we sell to them. Consequently, currency fluctuations could adversely affect the competitiveness of our coal in international markets.

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Interest Rate Risk

Borrowings under the Revolving Credit Facility, Securitization Facility and Cavalier Credit Agreement are at variable rates and, as a result, we have interest rate exposure. Historically, our earnings have not been materially affected by changes in interest rates and we have not utilized interest rate derivative instruments related to our outstanding debt. We had $70.0 million in borrowings under the Revolving Credit Facility and $75.0 million in borrowings under the Securitization Facility at June 30, 2019. A one percentage point increase in the interest rates related to the Revolving Facility and Securitization Facility would result in an annualized increase in interest expense of $1.5 million, based on borrowing levels at June 30, 2019.

There were no other changes in our quantitative and qualitative disclosures about market risk as set forth in our Annual Report on Form 10-K for the year ended December 31, 2018.

ITEM 4.CONTROLS AND PROCEDURES

We maintain controls and procedures designed to provide reasonable assurance that information required to be disclosed in the reports we file with the Securities and Exchange Commission ("SEC") is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC and that such information is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow for timely decisions regarding required disclosure. As required by Rule 13a-15(b) of the Securities Exchange Act of 1934, as amended (the "Exchange Act"), we have evaluated, under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rule 13a-15(e) or Rule 15d-15(e) of the Exchange Act) as of June 30, 2019. Based on this evaluation, our Chief Executive Officer and Chief Financial Officer concluded that these controls and procedures are effective as of June 30, 2019.

During the quarterly period ended June 30, 2019, other than the changes that have resulted or may result from the AllDale Acquisition as discussed below, there have not been any changes in our internal control over financial reporting (as defined in Rule 13a-15(f) under the Exchange Act) identified in connection with this evaluation that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

On January 3, 2019 (the "AllDale Acquisition Date"), we acquired all of the limited partner interests in AllDale Minerals, LP and AllDale Minerals II, LP (collectively, "AllDale I & II") not owned by Cavalier Minerals JV, LLC and the general partner interests in AllDale I & II (the "AllDale Acquisition") as described in "Item 1. Financial Statements (Unaudited) – Note 3. Acquisition" of this Quarterly Report on Form 10-Q. As a result of the AllDale Acquisition, we now own 100% of the general partner interests and, including the limited partner interests we hold indirectly through our ownership in Cavalier Minerals, approximately 97% of the limited partner interests in AllDale I & II. In addition, we assumed control and began accounting for AllDale I & II on a consolidated basis. At this time, we continue to evaluate the business and internal controls and processes of AllDale I & II and are making various changes to their management and organizational structures based on our business plan. We are in the process of implementing our internal control structure over the acquired businesses. We expect to complete the evaluation and integration of the internal controls and processes of AllDale I & II in the first quarter of 2020.

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FORWARD-LOOKING STATEMENTS

Certain statements and information in this Quarterly Report on Form 10-Q may constitute "forward-looking statements." These statements are based on our beliefs as well as assumptions made by, and information currently available to, us. When used in this document, the words "anticipate," "believe," "continue," "estimate," "expect," "forecast," "may," "project," "will," and similar expressions identify forward-looking statements. Without limiting the foregoing, all statements relating to our future outlook, anticipated capital expenditures, future cash flows and borrowings and sources of funding are forward-looking statements. These statements reflect our current views with respect to future events and are subject to numerous assumptions that we believe are reasonable, but are open to a wide range of uncertainties and business risks, and actual results may differ materially from those discussed in these statements. Among the factors that could cause actual results to differ from those in the forward-looking statements are:

●

changes in coal prices, which could affect our operating results and cash flows;

●

changes in competition in domestic and international coal markets and our ability to respond to such changes;

●

legislation, regulations, and court decisions and interpretations thereof, both domestic and foreign, including those relating to the environment and the release of greenhouse gases, mining, miner health and safety and health care;

●

deregulation of the electric utility industry or the effects of any adverse change in the coal industry, electric utility industry, or general economic conditions;

●

risks associated with the expansion of our operations and properties;

●

our ability to identify and complete acquisitions;

●

dependence on significant customer contracts, including renewing existing contracts upon expiration;

●

adjustments made in price, volume or terms to existing coal supply agreements;

●

changing global economic conditions or in industries in which our customers operate;

●

recent action and the possibility of future action on trade made by United States and foreign governments;

●

the effect of new tariffs and other trade measures;

●

liquidity constraints, including those resulting from any future unavailability of financing;

●

customer bankruptcies, cancellations or breaches to existing contracts, or other failures to perform;

●

customer delays, failure to take coal under contracts or defaults in making payments;

●

fluctuations in coal demand, prices and availability;

●

changes in oil & gas prices, which could, among other things, affect our investments in oil & gas mineral interests;

●

our productivity levels and margins earned on our coal sales;

●

decline in or change in the coal industry's share of electricity generation, including as a result of environmental concerns related to coal mining and combustion and the cost and perceived benefits of other sources of electricity, such as natural gas, nuclear energy and renewable fuels;

●

changes in raw material costs;

●

changes in the availability of skilled labor;

●

our ability to maintain satisfactory relations with our employees;

●

increases in labor costs including costs of health insurance and taxes resulting from the Affordable Care Act, adverse changes in work rules, or cash payments or projections associated with post-mine reclamation and workers' compensation claims;

●

increases in transportation costs and risk of transportation delays or interruptions;

●

operational interruptions due to geologic, permitting, labor, weather-related or other factors;

●

risks associated with major mine-related accidents, mine fires, mine floods or other interruptions;

●

results of litigation, including claims not yet asserted;

●

foreign currency fluctuations that could adversely affect the competitiveness of our coal abroad;

●

difficulty maintaining our surety bonds for mine reclamation as well as workers' compensation and black lung benefits;

●

difficulty in making accurate assumptions and projections regarding post-mine reclamation as well as pension, black lung benefits and other post-retirement benefit liabilities;

●

uncertainties in estimating and replacing our coal reserves;

●

uncertainties in estimating and replacing our oil & gas reserves;

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●

uncertainties in the amount of oil & gas production due to the level of drilling and completion activity by the operators of our oil & gas properties;

●

a loss or reduction of benefits from certain tax deductions and credits;

●

difficulty obtaining commercial property insurance, and risks associated with our participation in the commercial insurance property program;

●

difficulty in making accurate assumptions and projections regarding future revenues and costs associated with equity investments in companies we do not control; and

●

other factors, including those discussed in "Item 1A. Risk Factors" and "Item 3. Legal Proceedings" in our Annual Report on Form 10-K for the year ended December 31, 2018.

If one or more of these or other risks or uncertainties materialize, or should underlying assumptions prove incorrect, our actual results may differ materially from those described in any forward-looking statement. When considering forward-looking statements, you should also keep in mind the risk factors described in "Item 1A. Risk Factors" below. These risk factors could also cause our actual results to differ materially from those contained in any forward-looking statement. We disclaim any obligation to update the above list or to announce publicly the result of any revisions to any of the forward-looking statements to reflect future events or developments.

You should consider the information above when reading or considering any forward-looking statements contained in:

●

this Quarterly Report on Form 10-Q;

●

other reports filed by us with the SEC;

●

our press releases;

●

our website http://www.arlp.com; and

●

written or oral statements made by us or any of our officers or other authorized persons acting on our behalf.

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PART II

OTHER INFORMATION

ITEM 1.LEGAL PROCEEDINGS

The information in Note 4. Contingencies to the Unaudited Condensed Consolidated Financial Statements included in "Part I. Item 1. Financial Statements (Unaudited)" of this Quarterly Report on Form 10-Q herein is hereby incorporated by reference. See also "Item 3. Legal Proceedings" of our Annual Report on Form 10-K for the year ended December 31, 2018.

ITEM 1A.RISK FACTORS

In addition to the other information set forth in this Quarterly Report on Form 10-Q, you should carefully consider the risk factor set forth below and the risk factors discussed in Part I, Item 1A "Risk Factors" in our Annual Report on Form 10-K for the year ended December 31, 2018 which could materially affect our business, financial condition or future results. The risks described in our Annual Report on Form 10-K and this Quarterly Report on Form 10-Q are not our only risks. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial based on current knowledge and factual circumstances, if such knowledge or facts change, also may materially adversely affect our business, financial condition and/or operating results in the future.

The tax treatment of publicly traded partnerships or an investment in our units could be subject to potential legislative, judicial or administrative changes or differing interpretations, possibly applied on a retroactive basis.

The present United States federal income tax treatment of publicly traded partnerships, including us, or an investment in our common units, may be modified by administrative, legislative or judicial changes or differing interpretations at any time. From time to time, members of Congress have proposed and considered substantive changes to the existing United States federal income tax laws that would affect publicly traded partnerships including elimination of partnership tax treatment for certain publicly traded partnerships. Any modification to the United States federal income tax laws may be applied retroactively and could make it more difficult or impossible for us to meet the exception for certain publicly traded partnerships to be treated as partnerships for United States federal income tax purposes. For example, recently enacted legislation repealed Section 199 of the Code, which, prior to its repeal, entitled our unitholders to a deduction equal to a specified percentage of our qualified production activities income that was allocated to such unitholder. In addition, the “Clean Energy for America Act”, which is similar to legislation that was commonly proposed during the Obama Administration, was introduced in the Senate on May 2, 2019. If enacted, this proposal would, among other things, repeal the qualifying income exception within Section 7704(d)(1)(E) of the Code upon which we rely for our status as a partnership for United States federal income tax purposes.

In addition, the Treasury Department has issued, and in the future may issue, regulations interpreting those laws that affect publicly traded partnerships. There can be no assurance that there will not be further changes to United States federal income tax laws or the Treasury Department’s interpretation of such income tax laws in a manner that could impact our ability to qualify as a publicly traded partnership in the future. We are unable to predict whether any changes or other proposals will ultimately be enacted. Any future legislative changes could negatively impact the value of an investment in our common units. You are urged to consult with your own tax advisor with respect to the status of regulatory or administrative developments and proposals and their potential effect on your investment in our common units.

ITEM 2.UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

On May 31, 2018, ARLP announced that the MGP board of directors approved the establishment of a unit repurchase program authorizing ARLP to repurchase up to $100 million of its outstanding limited partner common units. The unit repurchase program is intended to enhance ARLP’s ability to achieve its goal of creating long-term value for its unitholders and provides another means, along with quarterly cash distributions, of returning cash to unitholders. The program has no time limit and ARLP may repurchase units from time to time in the open market or in other privately negotiated transactions. The unit repurchase program authorization does not obligate ARLP to repurchase any dollar amount or number of units, and repurchases may be commenced or suspended from time to time without prior notice.

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During the three months ended June 30, 2019, we did not repurchase and retire any units. Since inception of the program, we have repurchased and retired 3,985,010 units at an average unit price of $19.03 for an aggregate purchase price of $75.8 million. The remaining authorized amount for unit repurchases under this program was $24.2 million.

ITEM 3.DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4.MINE SAFETY DISCLOSURES

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 95.1 to this Quarterly Report on Form 10-Q.

ITEM 5.OTHER INFORMATION

None.

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ITEM 6.EXHIBITS


		Incorporated by Reference
Exhibit Number	Exhibit Description	Form	SEC File No. and Film No.	Exhibit	Filing Date	Filed Herewith*

3.1	Fourth Amended and Restated Agreement of Limited Partnership of Alliance Resource Partners, L.P.	8-K	000-26823 17990766	3.2	07/28/2017

3.2	Amendment No. 1 to Fourth Amended and Restated Agreement of Limited Partnership of Alliance Resource Partners, L.P.	10-K	000-26823 18634634	3.9	02/23/2018

3.3	Amendment No. 2 to Fourth Amended and Restated Agreement of Limited Partnership of Alliance Resource Partners, L.P.	8-K	000-26823 18883834	3.3	06/06/2018

3.4	Amendment No. 3 to Fourth Amended and Restated Agreement of Limited Partnership of Alliance Resource Partners, L.P.	8-K	000-26823 18883834	3.4	06/06/2018

3.5	Amended and Restated Agreement of Limited Partnership of Alliance Resource Operating Partners, L.P.	10-K	000-26823 583595	3.2	03/29/2000

3.6	Amendment No. 1 to Amended and Restated Agreement of Limited Partnership of Alliance Resource Operating Partners, L.P.	8-K	000-26823 18883834	3.5	06/06/2018

3.7	Amended and Restated Certificate of Limited Partnership of Alliance Resource Partners, L.P.	8-K	000-26823 17990766	3.6	07/28/2017

3.8	Certificate of Limited Partnership of Alliance Resource Operating Partners, L.P.	S-1/A	333-78845 99669102	3.8	07/23/1999

3.9	Certificate of Formation of Alliance Resource Management GP, LLC	S-1/A	333-78845 99669102	3.7	07/23/1999

3.10	Third Amended and Restated Operating Agreement of Alliance Resource Management GP, LLC	8-K	000-26823 18883834	3.7	06/06/2018

3.11	Certificate of Formation of MGP II, LLC	8-K	000-26823 17990766	3.5	07/28/2017

3.12	Amended and Restated Operating Agreement of MGP II, LLC	8-K	000-26823 17990766	3.4	07/28/2017

Table of Contents


		Incorporated by Reference
Exhibit Number	Exhibit Description	Form	SEC File No. and Film No.	Exhibit	Filing Date	Filed Herewith*

10.1	Purchase and Sale Agreement by and between Wing Resources LLC, and Wing Resources II LLC, as sellers, and Alliance Resource Partners, L.P., as buyer, dated as of June 21, 2019

31.1	Certification of Joseph W. Craft III, President and Chief Executive Officer of Alliance Resource Management GP, LLC, the general partner of Alliance Resource Partners, L.P., dated August 5, 2019, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

31.2	Certification of Brian L. Cantrell, Senior Vice President and Chief Financial Officer of Alliance Resource Management GP, LLC, the general partner of Alliance Resource Partners, L.P., dated August 5, 2019, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

32.1	Certification of Joseph W. Craft III, President and Chief Executive Officer of Alliance Resource Management GP, LLC, the general partner of Alliance Resource Partners, L.P., dated August 5, 2019, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

32.2	Certification of Brian L. Cantrell, Senior Vice President and Chief Financial Officer of Alliance Resource Management GP, LLC, the general partner of Alliance Resource Partners, L.P., dated August 5, 2019, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

95.1	Federal Mine Safety and Health Act Information

101	Interactive Data File (Form 10-Q for the quarter ended June 30, 2019 filed in Inline XBRL).

* Or furnished, in the case of Exhibits 32.1 and 32.2.

Table of Contents

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized, in Tulsa, Oklahoma, on August 5, 2019.


	ALLIANCE RESOURCE PARTNERS, L.P.

	By:	Alliance Resource Management GP, LLC
		its general partner

		/s/ Joseph W. Craft, III
		Joseph W. Craft, III
		President, Chief Executive Officer
		and Chairman, duly authorized to sign on behalf of the registrant.


		/s/ Robert J. Fouch
		Robert J. Fouch
		Vice President, Controller and
		Chief Accounting Officer

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Alliance Resource Partners (ARLP) 10-Q2019 Q2 Quarterly report

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