Item 2. Management’s Discussion and Analysis
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 "Mr. Craft" mean Joseph W. Craft III, the Chairman, President and Chief Executive Officer of MGP.
● References to "Intermediate Partnership" mean Alliance Resource Operating Partners, L.P., the intermediate partnership of Alliance Resource Partners, L.P.
● References to "Alliance Coal" mean Alliance Coal, LLC, an indirect wholly owned subsidiary of ARLP.
● References to "Alliance Minerals" mean Alliance Minerals, LLC, an indirect wholly owned subsidiary of ARLP.
● References to "Alliance Resource Properties" mean Alliance Resource Properties, LLC, an indirect wholly owned subsidiary of ARLP.
Summary
We are a diversified natural resource company that generates operating and royalty income from the production and marketing of coal to major domestic utilities, industrial users and international customers, as well as royalty income from oil & gas mineral interests located in strategic producing regions across the United States. In addition, we continue to position ourselves as a reliable energy partner for the future as we pursue opportunities that support the advancement of energy and related infrastructure. We intend to pursue strategic investments that leverage our core competencies and relationships with electric utilities, industrial customers, and federal and state governments.
We are currently the largest coal producer in the eastern United States with seven operating underground mining complexes near many of the major eastern utility generating plants and on major coal hauling railroads in Illinois, Indiana, Kentucky, Maryland, Pennsylvania, and West Virginia, as well as a coal-loading terminal in Indiana on the Ohio River. Two of our mines also have loading facilities located on the Ohio River.
In addition to our mining operations, Alliance Resource Properties owns or leases substantially all of our measured, indicated and inferred coal mineral resources and the majority of our proved and probable coal mineral reserves in the Illinois and Appalachia Basins that are (a) leased to our internal mining complexes or (b) near our coal mining operations but not yet leased.
We currently own oil & gas mineral interests in approximately 65,000 net royalty acres in premier oil & gas producing regions of the United States, primarily in the Permian (Delaware and Midland), Anadarko (SCOOP/STACK), and Williston (Bakken) basins, providing us with diversified exposure to industry-leading operators consistent with our general strategy to grow our oil & gas mineral interest business.
We have invested in energy and infrastructure opportunities including our investments in Francis Renewable Energy, LLC ("Francis"), Infinitum Electric, Inc. ("Infinitum"), NGP Energy Transition, L.P. ("NGP ET IV"), and Ascend Elements, Inc. ("Ascend") which are in the businesses of, respectively, electric vehicle charging stations, electric motor manufacturing, private equity investments in renewable energy, the electrification of our economy or the efficient use of energy, and the manufacturing and recycling of sustainable, engineered battery materials for electric vehicles.
On January 27, 2023, we entered into a one-year collaborative agreement with a third party effective January 1, 2023, committing up to $35.0 million for the acquisition of oil & gas mineral interests in the Midland and Delaware basins (the "Acquisition Agreement").
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On February 22, 2023, we acquired mineral interests in approximately 2,682 oil & gas net royalty acres in the Delaware Basin from JC Resources, LP ("JC Resources"), a related-party entity owned by Mr. Craft (the "JC Resources Acquisition").
For more information about the Acquisition Agreement and the JC Resources Acquisition, please read "Item 1. Financial Statements (Unaudited)—Note 2 – Acquisitions" of this Quarterly Report on Form 10-Q.
On August 22, 2023, we purchased $25.0 million of Series D Preferred Stock from Ascend, a U.S. based manufacturer and recycler of sustainable, engineered battery materials for electric vehicles.
On September 8, 2023, we purchased $24.6 million of Series E Preferred Stock from Infinitum, a U.S. based startup developer and manufacturer of electric motors featuring printed circuit board stators.
For more information about the Ascend and Infinitum investments, please read "Item 1. Financial Statements (Unaudited)—Note 9 – Equity Investments" of this Quarterly Report on Form 10-Q.
We have four reportable segments, Illinois Basin Coal Operations, Appalachia Coal Operations, Oil & Gas Royalties and Coal Royalties. We also have an "all other" category referred to as Other, Corporate and Elimination. Our two coal operations 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. Our Oil & Gas Royalties reportable segment includes our oil & gas mineral interests. Our Coal Royalties reportable segment includes coal mineral reserves and resources owned or leased by Alliance Resource Properties, which are either (a) leased to our mining complexes or (b) near our coal mining operations but not yet leased.
● Illinois Basin Coal Operations reportable segment includes (a) the Gibson County Coal mining complex, (b) the Warrior mining complex, (c) the River View mining complex and (d) the Hamilton mining complex. The segment also includes our Mt. Vernon coal-loading terminal on the Ohio River in Indiana, Mid-America Carbonates, LLC and other support services, and our non-operating mining complexes.
● Appalachia Coal Operations reportable segment includes (a) the Mettiki mining complex, (b) the Tunnel Ridge mining complex and (c) the MC Mining mining complex.
● Oil & Gas Royalties reportable segment includes oil & gas mineral interests held by AR Midland and AllDale I & II and includes Alliance Minerals' equity method investment in AllDale III. Please read "Item 1. Financial Statements (Unaudited) — Note 9 – Equity Investments" of this Quarterly Report on Form 10-Q for more information on AllDale III.
● Coal Royalties reportable segment includes coal mineral reserves and resources owned or leased by Alliance Resource Properties. Approximately two-thirds of the coal sold by our Coal Operations' mines is leased from our Coal Royalties entities.
● Other, Corporate and Elimination includes marketing and administrative activities, Matrix Design Group, LLC ("Matrix Design"), its subsidiaries and Alliance Design Group, LLC, our investments in Francis, Infinitum, NGP ET IV, and Ascend, Wildcat Insurance, LLC, which assists the ARLP Partnership with its insurance requirements, AROP Funding, LLC ("AROP Funding") and Alliance Resource Finance Corporation ("Alliance Finance"), and other miscellaneous activities. The eliminations included in Other, Corporate and Elimination primarily represent the intercompany coal royalty transactions described above between our Coal Royalties reportable segment and our coal operations' mines. Please read "Item 1. Financial Statements (Unaudited)—Note 9 – Equity Investments" and —Note 6 – Long-Term Debt" of this Quarterly Report on Form 10-Q for more information on our investments in Francis, Infinitum, Ascend, and NGP ET IV as well as AROP Funding and Alliance Finance.
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Three Months Ended September 30, 2023 Compared to Three Months Ended September 30, 2022
Three Months Ended September 30,
2023
2022 (1)
2023
2022 (1)
(in thousands)
(per ton / per BOE sold)
Coal - Tons sold
8,456
9,185
N/A
N/A
Coal - Tons produced
8,356
8,988
N/A
N/A
Coal - Coal sales
$
549,123
$
550,563
$
64.94
$
59.94
Coal - Segment Adjusted EBITDA Expense (2) (3)
$
348,290
$
332,503
$
41.19
$
36.20
Oil & Gas Royalties - BOE sold
772
602
N/A
N/A
Oil & Gas Royalties - Royalties (4)
$
34,125
$
38,695
$
44.19
$
64.27
Coal Royalties - Tons sold
4,993
5,654
N/A
N/A
Coal Royalties - Intercompany royalties
$
16,763
$
16,708
$
3.36
$
2.96
(1) Recast for the JC Resources Acquisition. For more information, please read "Item 1. Financial Statements (Unaudited)—Note 1 – Organization and Presentation" of this Quarterly Report on Form 10-Q.
(2) 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 GAAP 'Operating Expenses' to non-GAAP 'Segment Adjusted EBITDA Expense.'"
(3) Beginning in 2023, we redefined Coal - Segment Adjusted EBITDA Expense to reflect the activity of Alliance Coal, which is the holding company for our coal mining operations. We have retrospectively adjusted Coal - Segment Adjusted EBITDA Expense in prior periods to be on the same basis.
(4) Average sales price per BOE is defined as oil & gas royalty revenues excluding lease bonus revenue divided by total BOE sold.
Total Revenues . Total revenues for the three months ended September 30, 2023 ("2023 Quarter") increased slightly to $636.5 million compared to $632.5 million for the quarter ended September 30, 2022 (the "2022 Quarter") primarily as a result of higher transportation and other revenues, partially offset by lower oil & gas royalties.
Total operating expenses . Total operating expenses increased to $471.1 million in the 2023 Quarter, compared to $451.3 million in the 2022 Quarter, due primarily to the sale of higher cost purchased coal and increased per ton costs on certain expense items discussed in more detail below.
Net income attributable to ARLP . Net income attributable to ARLP for 2023 Quarter was $153.7 million, or $1.18 per basic and diluted limited partner unit, compared to $167.7 million, or $1.25 per basic and diluted limited partner unit, for the 2022 Quarter as a result of increased total operating expenses and equity method investment losses in the 2023 Quarter, partially offset by increased revenues, higher interest income and lower income tax expense.
Coal sales . Coal sales remained consistent at $549.1 million for the 2023 Quarter compared to $550.6 million for the 2022 Quarter. The slight decrease was attributable to lower tons sold, which reduced coal sales by $43.7 million, partially offset by the benefit of higher average coal sales prices, which contributed $42.3 million in additional coal sales. Tons sold decreased by 7.9% primarily due to decreased sales volumes in Appalachia as a result of lock outages, customer plant maintenance, reduced operating units at MC Mining and unique geologic conditions that delayed development of a new district at our Mettiki longwall operation. Improved domestic pricing, partially offset by lower export price realizations, drove coal sales prices higher by 8.3% in the 2023 Quarter to $64.94 per ton sold, compared to $59.94 per ton sold during the 2022 Quarter.
Coal - Segment Adjusted EBITDA Expense . Segment Adjusted EBITDA Expense for our coal operations increased 4.7% to $348.3 million, as a result of higher per ton costs. Segment Adjusted EBITDA Expense per ton sold for our coal operations increased 13.8% to $41.19 per ton sold in the 2023 Quarter compared to $36.20 per ton in the 2022 Quarter, primarily due to lower volumes and certain cost increases, which are discussed below by category:
● Labor and benefit expenses per ton produced, excluding workers' compensation, increased 17.5% to $12.37 per ton in the 2023 Quarter from $10.53 per ton in the 2022 Quarter. The increase of $1.84 per ton was primarily due to higher direct labor costs at several mines.
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● Material and supplies expenses per ton produced increased 5.7% to $13.93 per ton in the 2023 Quarter from $13.18 per ton in the 2022 Quarter. The increase of $0.75 per ton produced primarily reflects increases of $0.54 per ton for roof support, $0.26 per ton for ventilation related expenses and $0.17 per ton for power and fuel. These increases were partially offset by decreases of $0.26 per ton in longwall subsidence expense, $0.17 per ton for outside expenses and $0.16 per ton for contract labor used in the mining process .
● Maintenance expenses per ton produced increased 35.4% to $4.86 per ton in the 2023 Quarter from $3.59 per ton in the 2022 Quarter. The increase of $1.27 per ton produced was primarily as a result of reduced production volumes and inflationary cost pressures.
● Production taxes and royalty expenses per ton incurred as a percentage of coal sales prices increased $0.83 per produced ton sold in the 2023 Quarter compared to the 2022 Quarter primarily as a result of higher price realizations, increased excise taxes per ton resulting from a reduced mix of export shipments, higher federal black lung excise tax as a result of the tax rate increasing effective October 1, 2022 and an unfavorable mix of tons sold mined in states with severance taxes.
● We had outside coal purchases of $11.5 million to meet contractual commitments in the 2023 Quarter as a result of unique geological conditions that delayed development of a new district at our Mettiki longwall operation compared to no sales of outside coal purchases in the 2022 Quarter. Thus, costs per ton in the 2023 Quarter increased as our cost of outside coal purchases are generally higher on a per ton basis than our produced coal.
Oil & gas royalties. Oil & gas royalty revenues decreased to $34.1 million in the 2023 Quarter compared to $38.7 million for the 2022 Quarter. The decrease of $4.6 million was primarily due to lower average sales price per BOE, which decreased by 31.2%, partially offset by higher BOE volumes.
Other revenues . Other revenues principally comprised Matrix Design sales, Mt. Vernon transloading revenues, oil & gas lease bonus revenues and other miscellaneous sales and revenue activities. Other revenues increased to $18.3 million in the 2023 Quarter from $14.7 million in the 2022 Quarter. The increase of $3.6 million was primarily due to increased transloading revenues and sales of mining technology products by our Matrix Design subsidiary as well as higher revenues from other miscellaneous sales activities.
Depreciation, depletion and amortization. Depreciation, depletion and amortization expense decreased to $65.4 million for the 2023 Quarter compared to $70.7 million for the 2022 Quarter primarily as a result of reduced coal sales volumes.
Equity method investment income (loss) . We had an equity method investment loss of $1.8 million in the 2023 Quarter compared to equity method investment income of $2.1 million in the 2022 Quarter. The change was primarily due to losses attributable to our investment in Francis, partially offset by income from our AllDale III investment.
Income tax expense. Income tax expense decreased to $3.4 million for the 2023 Quarter compared to $6.6 million for the 2022 Quarter primarily as a result of reduced income from our oil & gas mineral interests.
Transportation revenues and expenses . Transportation revenues and expenses were $35.0 million and $28.5 million for the 2023 and 2022 Quarters, respectively. The increase of $6.5 million was primarily attributable to increased third-party transportation rates in the 2023 Quarter, partially offset by reduced coal shipments for which we arrange third-party transportation. Transportation revenues are recognized when title to the coal passes to the customer and recognized in an amount equal to the corresponding transportation expenses.
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Segment Adjusted EBITDA. Our 2023 Quarter Segment Adjusted EBITDA decreased $27.5 million to $247.7 million from the 2022 Quarter Segment Adjusted EBITDA of $275.2 million.
Three Months Ended
September 30,
2023
2022 (1)
Increase (Decrease)
(in thousands)
Segment Adjusted EBITDA
Illinois Basin Coal Operations
$
132,428
$
120,760
$
11,668
9.7
%
Appalachia Coal Operations
74,832
102,012
(27,180)
(26.6)
%
Oil & Gas Royalties
31,366
39,429
(8,063)
(20.4)
%
Coal Royalties
9,912
11,163
(1,251)
(11.2)
%
Other, Corporate and Elimination (2)
(881)
1,792
(2,673)
(149.2)
%
Total Segment Adjusted EBITDA (3)
$
247,657
$
275,156
$
(27,499)
(10.0)
%
Coal - Tons sold
Illinois Basin Coal Operations
6,049
6,109
(60)
(1.0)
%
Appalachia Coal Operations
2,407
3,076
(669)
(21.7)
%
Total tons sold
8,456
9,185
(729)
(7.9)
%
Coal sales
Illinois Basin Coal Operations
$
342,744
$
314,271
$
28,473
9.1
%
Appalachia Coal Operations
206,379
236,292
(29,913)
(12.7)
%
Total coal sales
$
549,123
$
550,563
$
(1,440)
(0.3)
%
Other revenues
Illinois Basin Coal Operations
$
2,897
$
1,455
$
1,442
99.1
%
Appalachia Coal Operations
449
392
57
14.5
%
Oil & Gas Royalties
2,186
2,918
(732)
(25.1)
%
Other, Corporate and Elimination
12,777
9,890
2,887
29.2
%
Total other revenues
$
18,309
$
14,655
$
3,654
24.9
%
Segment Adjusted EBITDA Expense
Illinois Basin Coal Operations
$
213,209
$
194,967
$
18,242
9.4
%
Appalachia Coal Operations
131,997
134,672
(2,675)
(2.0)
%
Oil & Gas Royalties
3,873
3,926
(53)
(1.3)
%
Coal Royalties
6,851
5,545
1,306
23.6
%
Other, Corporate and Elimination (2)
(5,524)
(8,609)
3,085
35.8
%
Total Segment Adjusted EBITDA Expense (3)
$
350,406
$
330,501
$
19,905
6.0
%
Oil & Gas Royalties
Volume - BOE (4)
772
602
170
28.2
%
Oil & gas royalties
$
34,125
$
38,695
$
(4,570)
(11.8)
%
Coal Royalties
Volume - Tons sold (5)
4,993
5,654
(661)
(11.7)
%
Intercompany coal royalties
$
16,763
$
16,708
$
55
0.3
%
(1) Recast for the JC Resources Acquisition. For more information, please read "Item 1. Financial Statements (Unaudited)—Note 1 – Organization and Presentation" of this Quarterly Report on Form 10-Q.
(2) Other, Corporate and Elimination includes the elimination of intercompany coal royalty revenues and expenses between our Coal Royalties Segment and our Coal Operations Segments in addition to the expenses for the other miscellaneous activities included in this category.
(3) For definitions of Segment Adjusted EBITDA and Segment Adjusted EBITDA Expense and related reconciliations to their respective comparable GAAP financial measures, please see below under "—Reconciliation of GAAP 'net
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income' to non-GAAP 'Segment Adjusted EBITDA' and reconciliation of GAAP 'Operating Expenses' to non-GAAP 'Segment Adjusted EBITDA Expense.'"
(4) Barrels of oil equivalent ("BOE") is calculated on a 6:1 basis (6,000 cubic feet of natural gas to one barrel).
(5) Represents tons sold by our Coal Operations Segments that were produced from coal reserves leased from our Coal Royalties Segment.
Illinois Basin Coal Operations – Segment Adjusted EBITDA increased 9.7% to $132.4 million in the 2023 Quarter from $120.8 million in the 2022 Quarter. The increase of $11.6 million was primarily attributable to higher coal sales, which increased 9.1% to $342.7 million in the 2023 Quarter from $314.3 million in the 2022 Quarter, partially offset by increased operating expenses. The increase in coal sales reflects higher coal sales price realizations of $56.66 per ton sold in the 2023 Quarter compared to $51.44 per ton sold in the 2022 Quarter due to improved domestic pricing, partially offset by lower export price realizations. Segment Adjusted EBITDA Expense increased 9.4% to $213.2 million in the 2023 Quarter from $195.0 million in the 2022 Quarter primarily as a result of higher operating expenses per ton. Segment Adjusted EBITDA Expense per ton increased by 10.5% compared to the 2022 Quarter resulting from increased sales-related expenses due to higher price realizations and higher labor-related, roof support and maintenance costs due to days lost by a sizable roof fall in July and a longwall move in August at our Hamilton mine.
Appalachia Coal Operations – Segment Adjusted EBITDA decreased 26.6% to $74.8 million for the 2023 Quarter from $102.0 million in the 2022 Quarter. The decrease of $27.2 million was primarily attributable to lower coal sales, which decreased 12.7% to $206.4 million in the 2023 Quarter from $236.3 million in the 2022 Quarter. Tons sold decreased by 21.7% compared to the 2022 Quarter as a result of reduced volumes across the region primarily from lock outages, customer plant maintenance, reduced operating units at MC Mining and unique geologic conditions that delayed development of a new district at our Mettiki longwall operation. Improved domestic pricing, partially offset by lower export price realizations, drove coal sales prices higher by 11.6% as compared to the 2022 Quarter. Segment Adjusted EBITDA Expense decreased 2.0% to $132.0 million in the 2023 Quarter from $134.7 million in the 2022 Quarter due to reduced sales volumes, partially offset by higher per ton operating expenses. Segment Adjusted EBITDA Expense per ton increased by 25.3% compared to the 2022 Quarter due primarily to lower production volumes, purchased coal and increased labor-related, roof support, maintenance and selling expenses per ton.
Oil & Gas Royalties – Segment Adjusted EBITDA decreased to $31.4 million in the 2023 Quarter compared to $39.4 million in the 2022 Quarter. The decrease primarily resulted from lower price realizations, which decreased by 31.2%, partially offset by record oil & gas volumes, which increased 28.2% to 772 MBOE sold in the 2023 Quarter. Higher volumes during the 2023 Quarter resulted from increased drilling and completion activities on our interests and the acquisition of additional oil & gas mineral interests.
Coal Royalties – Segment Adjusted EBITDA was $9.9 million for the 2023 Quarter, representing a decrease of $1.3 million compared to the 2022 Quarter, as a result of lower royalty tons sold and increased selling expenses, partially offset by higher average royalty rates per ton received from the Partnership's mining subsidiaries.
Nine Months Ended September 30, 2023 Compared to Nine Months Ended September 30, 2022
Nine Months Ended September 30,
2023
2022 (1)
2023
2022 (1)
(in thousands)
(per ton / per BOE sold)
Coal - Tons sold
25,829
26,280
N/A
N/A
Coal - Tons produced
26,997
27,044
N/A
N/A
Coal - Coal sales
$
1,688,238
$
1,470,730
$
65.36
$
55.96
Coal - Segment Adjusted EBITDA Expense (2) (3)
$
1,021,191
$
907,969
$
39.54
$
34.55
Oil & Gas Royalties - BOE sold
2,296
1,690
N/A
N/A
Oil & Gas Royalties - Royalties (4)
$
101,709
$
111,378
$
44.29
$
65.92
Coal Royalties - Tons sold
15,168
16,475
N/A
N/A
Coal Royalties - Intercompany royalties
$
48,843
$
46,400
$
3.22
$
2.82
(1) Recast for the JC Resources Acquisition. For more information, please read "Item 1. Financial Statements (Unaudited)—Note 1 – Organization and Presentation" of this Quarterly Report on Form 10-Q.
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(2) 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 GAAP 'Operating Expenses' to non-GAAP 'Segment Adjusted EBITDA Expense.'"
(3) Beginning in 2023, we redefined Coal - Segment Adjusted EBITDA Expense to reflect the activity of Alliance Coal, which is the holding company for our coal mining operations. We have retrospectively adjusted Coal - Segment Adjusted EBITDA Expense in prior periods to be on the same basis.
(4) Average sales price per BOE is defined as oil & gas royalty revenues excluding lease bonus revenue divided by total BOE sold.
Total Revenues . Total revenues for the nine months ended September 30, 2023 ("2023 Period") increased 13.1% to $1.94 billion compared to $1.72 billion for the nine months ended September 30, 2022 ("2022 Period") primarily as a result of higher coal sales. Coal sales prices and coal sales revenues during the 2023 Period were higher by 16.8% and 14.8%, respectively, compared to the 2022 Period.
Total operating expenses . Total operating expenses increased to $1.38 billion in the 2023 Period, compared to $1.27 billion in the 2022 Period, due primarily to higher per ton costs on certain expense items discussed in more detail below and sale of higher cost purchased coal.
Net income attributable to ARLP . Increased revenues and lower income tax expense were partially offset by higher total operating expenses in the 2023 Period, resulting in higher net income attributable to ARLP for the 2023 Period of $514.7 million, or $3.93 per basic and diluted limited partner unit, compared to $369.3 million, or $2.76 per basic and diluted limited partner unit, for the 2022 Period.
Coal sales . Coal sales increased $217.5 million to $1.69 billion for the 2023 Period compared to $1.47 billion for the 2022 Period. The increase reflects the benefit of higher average coal sales prices, which contributed $242.7 million in additional coal sales, partially offset by lower tons sold, which reduced coal sales by $25.2 million. Higher price realizations in domestic markets drove coal sales prices higher by 16.8% in the 2023 Period to $65.36 per ton sold, compared to $55.96 per ton sold during the 2022 Period.
Coal - Segment Adjusted EBITDA Expense . Segment Adjusted EBITDA Expense for our coal operations increased 12.5% to $1.02 billion, as a result of higher per ton costs. On a per ton basis, Segment Adjusted EBITDA Expense for our coal operations increased 14.4% to $39.54 per ton sold in the 2023 Period compared to $34.55 per ton in the 2022 Period, primarily due to certain cost increases, which are discussed below by category:
● Labor and benefit expenses per ton produced, excluding workers' compensation, increased 16.7% to $11.81 per ton in the 2023 Period from $10.12 per ton in the 2022 Period. The increase of $1.69 per ton was primarily due to higher incentive benefits and direct labor costs at several mines.
● Workers' compensation expenses per ton produced increased to $0.56 per ton in the 2023 Period from $0.27 per ton in the 2022 Period. The increase of $0.29 per ton produced primarily reflects a favorable mid-year workers' compensation accrual adjustment in the 2022 Period due to an increase in the discount rate.
● Material and supplies expenses per ton produced increased 3.7% to $13.57 per ton in the 2023 Period from $13.08 per ton in the 2022 Period. The increase of $0.49 per ton produced primarily reflects increases of $0.26 per ton for ventilation related expenses, $0.14 per ton for various preparation plant expenses and $0.14 per ton for power and fuel, partially offset by a decrease of $0.15 per ton for roof support.
● Maintenance expenses per ton produced increased 27.7% to $4.43 per ton in the 2023 Period from $3.47 per ton in the 2022 Period. The increase of $0.96 per ton produced was primarily as a result of inflationary cost pressures.
● Production taxes and royalty expenses per ton incurred as a percentage of coal sales prices and volumes increased $0.94 per produced ton sold in the 2023 Period compared to the 2022 Period primarily as a result of higher price realizations, increased excise taxes per ton resulting from a reduced mix of export shipments and higher federal black lung excise tax as a result of the tax rate increasing effective October 1, 2022, partially offset by a favorable mix of tons sold mined in states without severance taxes.
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● Outside coal purchases increased $15.6 million in the 2023 Period as a result of increased sales of purchased coal to meet contractual commitments at our Mettiki longwall operation which experienced unique geological conditions that delayed development of a new district. Purchased coal generally costs more on a per ton basis than our produced coal.
Oil & gas royalties. Oil & gas royalty revenues decreased to $101.7 million in the 2023 Period compared to $111.4 million for the 2022 Period. The decrease of $9.7 million was primarily due to lower average sales price per BOE, which decreased by 32.8%, partially offset by higher BOE volumes.
Other revenues . Other revenues principally comprised Matrix Design sales, Mt. Vernon transloading revenues, oil & gas lease bonus revenues and other miscellaneous sales and revenue activities. Other revenues increased to $55.6 million in the 2023 Period from $40.3 million in the 2022 Period. The increase of $15.3 million was primarily due to increased transloading revenues and sales of mining technology products by our Matrix Design subsidiary as well as higher revenues from other miscellaneous sales activities.
Income tax expense. Income tax expense decreased to $11.6 million for the 2023 Period compared to $55.6 million for the 2022 Period primarily as a result of our recognition of a one-time non-cash income tax charge of $37.3 million during the 2022 Period when Alliance Minerals elected to be treated as a taxable entity for federal and state income tax purposes.
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Segment Adjusted EBITDA. Our 2023 Period Segment Adjusted EBITDA increased 12.7% to $809.0 million from the 2022 Period Segment Adjusted EBITDA of $717.7 million.
Nine Months Ended
September 30,
2023
2022 (1)
Increase (Decrease)
(in thousands)
Segment Adjusted EBITDA
Illinois Basin Coal Operations
$
383,987
$
296,327
$
87,660
29.6
%
Appalachia Coal Operations
300,955
277,492
23,463
8.5
%
Oil & Gas Royalties
90,461
107,902
(17,441)
(16.2)
%
Coal Royalties
31,007
30,638
369
1.2
%
Other, Corporate and Elimination (2)
2,560
5,317
(2,757)
(51.9)
%
Total Segment Adjusted EBITDA (3)
$
808,970
$
717,676
$
91,294
12.7
%
Coal - Tons sold
Illinois Basin Coal Operations
18,305
17,822
483
2.7
%
Appalachia Coal Operations
7,524
8,458
(934)
(11.0)
%
Total tons sold
25,829
26,280
(451)
(1.7)
%
Coal sales
Illinois Basin Coal Operations
$
1,011,467
$
858,565
$
152,902
17.8
%
Appalachia Coal Operations
676,771
612,165
64,606
10.6
%
Total coal sales
$
1,688,238
$
1,470,730
$
217,508
14.8
%
Other revenues
Illinois Basin Coal Operations
$
7,466
$
5,014
$
2,452
48.9
%
Appalachia Coal Operations
1,299
1,083
216
19.9
%
Oil & Gas Royalties
3,551
3,711
(160)
(4.3)
%
Other, Corporate and Elimination
43,287
30,540
12,747
41.7
%
Total other revenues
$
55,603
$
40,348
$
15,255
37.8
%
Segment Adjusted EBITDA Expense
Illinois Basin Coal Operations
$
634,944
$
567,253
$
67,691
11.9
%
Appalachia Coal Operations
377,115
335,756
41,359
12.3
%
Oil & Gas Royalties
11,859
10,785
1,074
10.0
%
Coal Royalties
17,836
15,762
2,074
13.2
%
Other, Corporate and Elimination (2)
(13,618)
(21,177)
7,559
35.7
%
Total Segment Adjusted EBITDA Expense (3)
$
1,028,136
$
908,379
$
119,757
13.2
%
Oil & Gas Royalties
Volume - BOE (4)
2,296
1,690
606
35.9
%
Oil & gas royalties
$
101,709
$
111,378
$
(9,669)
(8.7)
%
Coal Royalties
Volume - Tons sold (5)
15,168
16,475
(1,307)
(7.9)
%
Intercompany coal royalties
$
48,843
$
46,400
$
2,443
5.3
%
(1) Recast for the JC Resources Acquisition. For more information, please read "Item 1. Financial Statements (Unaudited)—Note 1 – Organization and Presentation" of this Quarterly Report on Form 10-Q.
(2) Other, Corporate and Elimination includes the elimination of intercompany coal royalty revenues and expenses between our Coal Royalties Segment and our Coal Operations Segments in addition to the expenses for the other miscellaneous activities included in this category.
(3) For definitions of Segment Adjusted EBITDA and Segment Adjusted EBITDA Expense and related reconciliations to their respective comparable GAAP financial measures, please see below under "—Reconciliation of GAAP 'net
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income' to non-GAAP 'Segment Adjusted EBITDA' and reconciliation of GAAP 'Operating Expenses' to non-GAAP 'Segment Adjusted EBITDA Expense.'"
(4) Barrels of oil equivalent ("BOE") is calculated on a 6:1 basis (6,000 cubic feet of natural gas to one barrel).
(5) Represents tons sold by our Coal Operations Segments that were produced from coal reserves leased from our Coal Royalties Segment.
Illinois Basin Coal Operations – Segment Adjusted EBITDA increased 29.6% to $384.0 million in the 2023 Period from $296.3 million in the 2022 Period. The increase of $87.7 million was primarily attributable to higher coal sales, which increased 17.8% to $1.01 billion in the 2023 Period from $858.6 million in the 2022 Period, partially offset by increased operating expenses. The increase in coal sales reflects higher coal sales price per ton, which increased by 14.7% compared to the 2022 Period reflecting increased domestic prices, and increased tons sold, which rose 2.7% in the 2023 Period as a result of increased sales volumes at the Warrior and Gibson South mines. Segment Adjusted EBITDA Expense increased 11.9% to $634.9 million in the 2023 Period from $567.3 million in the 2022 Period primarily as a result of increased sales volumes and higher operating expenses per ton. Segment Adjusted EBITDA Expense per ton increased $2.86 per ton sold to $34.69 from $31.83 per ton sold in the 2022 Period primarily as a result of inflationary pressures on numerous expense items, including labor-related expenses, maintenance costs and increased sales-related expenses due to higher price realizations.
Appalachia Coal Operations – Segment Adjusted EBITDA increased 8.5% to $301.0 million for the 2023 Period from $277.5 million in the 2022 Period. The increase of $23.5 million was primarily attributable to higher coal sales, which increased 10.6% to $676.8 million in the 2023 Period from $612.2 million in the 2022 Period, due to increased prices, partially offset by reduced sales volumes. Coal sales prices increased by 24.3% compared to the 2022 Period primarily due to increased domestic price realizations in the region. Coal sales volumes decreased 11.0% compared to the 2022 Period as a result of reduced export sales from our Tunnel Ridge operation and lower production across the region due to lock outages, customer plant maintenance, reduced operating units at MC Mining, and unique geologic conditions that delayed development of a new district at our Mettiki longwall operation. Segment Adjusted EBITDA Expense increased 12.3% to $377.1 million in the 2023 Period from $335.8 million in the 2022 Period due to higher per ton operating expenses, partially offset by lower volumes. Segment Adjusted EBITDA Expense per ton increased 26.2% to $50.12 compared to $39.70 per ton sold in the 2022 Period, as a result of lower volumes previously discussed, purchased coal and inflationary pressures on certain expense items, most notably labor-related expenses and materials and maintenance costs, and increased sales-related expenses due to higher price realizations.
Oil & Gas Royalties – Segment Adjusted EBITDA decreased to $90.5 million for the 2023 Period from $107.9 million in the 2022 Period. The decrease of $17.4 million was primarily due to lower average sales price per BOE, which decreased 32.8% to $44.29 per BOE, partially offset by increased volumes in the 2023 Period, which increased by 35.9%. Higher BOE volumes during the 2023 Period resulted from increased drilling and completion activities on our properties and additional volumes from oil & gas mineral interest acquisitions.
Coal Royalties – Segment Adjusted EBITDA increased 1.2% to $31.0 million for the 2023 Period from $30.6 million in the 2022 Period. The slight increase was a result of higher average royalty rates per ton, partially offset by reduced royalty tons sold.
Reconciliation of GAAP "net income" to non-GAAP "Segment Adjusted EBITDA" and reconciliation of GAAP "Operating Expenses" to non-GAAP "Segment Adjusted EBITDA Expense"
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 and general and administrative expenses. 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.
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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.
The following is a reconciliation of net income, the most comparable GAAP financial measure, to consolidated Segment Adjusted EBITDA:
Three Months Ended
Nine Months Ended
September 30,
September 30,
2023
2022
2023
2022
(in thousands)
Net income
$
155,351
$
168,072
$
519,334
$
370,296
Noncontrolling interest
(1,652)
(364)
(4,660)
(977)
Net income attributable to ARLP
$
153,699
$
167,708
$
514,674
$
369,319
General and administrative
20,097
21,360
61,312
62,462
Depreciation, depletion and amortization
65,393
70,669
199,582
202,499
Interest expense, net
5,067
8,819
21,761
27,750
Income tax expense
3,401
6,600
11,641
55,646
Consolidated Segment Adjusted EBITDA
$
247,657
$
275,156
$
808,970
$
717,676
Segment Adjusted EBITDA Expense (a non-GAAP financial measure) includes operating expenses, coal purchases, if applicable, and other expense (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 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 operating expenses, the most comparable GAAP financial measure, to consolidated Segment Adjusted EBITDA Expense:
Three Months Ended
Nine Months Ended
September 30,
September 30,
2023
2022
2023
2022
(in thousands)
Operating expenses (excluding depreciation, depletion and amortization)
$
339,099
$
330,694
$
1,012,224
$
909,567
Outside coal purchases
11,530
—
15,739
151
Other expense (income)
(223)
(193)
173
(1,339)
Segment Adjusted EBITDA Expense
$
350,406
$
330,501
$
1,028,136
$
908,379
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Liquidity and Capital Resources
Liquidity
We have historically satisfied our working capital requirements and funded our capital expenditures, investments, contractual obligations 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, contractual obligations, commitments and distribution payments. Nevertheless, our ability to satisfy our working capital requirements and additional investments, to satisfy our contractual obligations, 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 both 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 cash flow results, current cash position, anticipated future cash flows and sources of financing that we expect to have available, we anticipate being in compliance with the covenants of the Credit Agreement and expect to have sufficient liquidity to fund our operations and growth strategies. However, to the extent operating cash flow or access to and cost of financing sources are materially different than expected, future covenant compliance or 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, 2022.
Oil & Gas Acquisitions — As of September 30, 2023, we have purchased oil & gas mineral interests for $10.0 million and $13.9 million for the three and nine months ended September 30, 2023, respectively, with cash on hand. Future oil & gas mineral interest acquisitions are expected to be funded with cash on hand or cash generated from operations.
On February 22, 2023, we closed on the JC Resources Acquisition for $72.3 million, which was funded with cash on hand.
Please read "Item 1. Financial Statements (Unaudited) – Note 2 – Acquisitions" of this Quarterly Report on Form 10-Q for additional information about the Acquisition Agreement and the JC Resources Acquisition.
On August 22, 2023, we purchased $25.0 million of Series D Preferred Stock from Ascend with cash on hand.
On September 8, 2023, we purchased $24.6 million of Series E Preferred Stock from Infinitum with cash on hand.
Please read "Item 1. Financial Statements (Unaudited) – Note 9 – Equity Investments" of this Quarterly Report on Form 10-Q for additional information about the Ascend and Infinitum investments.
Credit Facility — On January 13, 2023, Alliance Coal, as borrower, entered into a Credit Agreement (the "Credit Agreement") with various financial institutions. The Credit Agreement provides for a $425 million revolving credit facility, which includes a sublimit of $15.0 million for swingline borrowings and permits the issuance of letters of credit of up to the full amount of $425 million (the "Revolving Credit Facility"), and for a term loan in an aggregate principal amount of $75 million (the "Term Loan"). The Credit Agreement matures on March 9, 2027, at which time the aggregate outstanding principal amount of all Revolving Credit Facility advances and all Term Loan advances are required to be repaid in full. The Credit Agreement will instead mature on January 30, 2025, if on that date our Senior Notes are still outstanding and Alliance Coal does not have liquidity of at least $200 million. Interest is payable quarterly, with principal of the Term Loan due in quarterly installments equal to 6.25% of the original principal amount of the Term Loan beginning with the quarter ending June 30, 2023, and the balance payable at maturity. The Revolving Credit Facility replaces the $459.5 million revolving credit facility, which included a sublimit of $125.0 million for the issuance of letters of credit and a sublimit of $15.0 million for swingline borrowings, extended to the Intermediate Partnership under its Fifth Amended and Restated Credit Agreement, dated as of March 9, 2020 that would have expired on March 9, 2024. The Credit Agreement is guaranteed by ARLP and certain of its subsidiaries, including the Intermediate Partnership and most of the direct and indirect subsidiaries of Alliance Coal (the "Subsidiary Guarantors"). The Credit Agreement also is secured by substantially all of the assets of the Subsidiary Guarantors and Alliance Coal. For additional information on the Credit Agreement, please see " Item 1. Financial Statements (Unaudited) – Note 6 – Long-Term Debt."
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Accounts Receivable Securitization — In January 2023, we extended the term of our $60.0 million accounts receivable securitization facility (the "Securitization Facility") from January 2023 to January 2024. For additional information on the Securitization Facility, please see "Item 1. Financial Statements (Unaudited) – Note 6 – Long-Term Debt."
Unit Repurchase Program — In May 2018, the Board of Directors approved the establishment of a unit repurchase program authorizing us to repurchase up to $100 million of ARLP common units. In January 2023, the Board of Directors authorized a $93.5 million increase to the unit repurchase program, which had $6.5 million of available capacity as of December 31, 2022. 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 nine months ended September 30, 2023, we repurchased and retired 929,842 units at an average price of $20.90 for an aggregate purchase price of $19.4 million. The timing of any future unit repurchases and the ultimate number of units to be purchased will depend on several factors, including business and market conditions, our future financial performance, and other capital priorities. 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 the unit repurchase program.
Repurchase or Redemption of Senior Notes — During the nine months ended September 30, 2023, we repurchased or redeemed $115.4 million of our 7.5% senior notes due 2025. At September 30, 2023, the aggregate principal amount of our outstanding 7.5% senior notes due 2025 was $284.6 million. We expect to continue making additional purchases or redemptions with available cash flows and/or additional borrowings.
Shelf Registration Statement — We currently have an effective universal shelf Registration Statement on Form S-3 that provides for the registration and sale of an unspecified amount of our equity or debt securities. We may over time, and subject to market conditions, in one or more offerings, offer and sell any of the securities described in the prospectus.
Cash Flows
Cash provided by operating activities was $735.4 million for the 2023 Period compared to $556.2 million for the 2022 Period. The increase in cash provided by operating activities was primarily due to an increase in net income adjusted for non-cash items and favorable working capital changes related primarily to trade receivables, accounts payable and workers' compensation accruals. These increases were partially offset by unfavorable working capital changes related primarily to inventories, accrued taxes other than income taxes, as well as miscellaneous other changes compared to the 2022 Period.
Net cash used in investing activities was $444.5 million for the 2023 Period compared to $247.5 million for the 2022 Period. The increase in cash used in investing activities was primarily attributable to increases in capital expenditures, changes in accounts payable and accrued liabilities, purchases of equity securities and acquisitions of oil & gas reserves including the JC Resources Acquisition. These increases were partially offset by decreased equity method investments. Please read "Item 1. Financial Statements (Unaudited) - Note 2 – Acquisitions" of this Quarterly Report on Form 10-Q for additional information about the JC Resources Acquisition and other oil & gas reserve acquisitions.
Net cash used in financing activities was $389.7 million for the 2023 Period compared to $152.6 million for the 2022 Period. The increase in cash used in financing activities was primarily attributable to increased cash distributions paid to unitholders, the repurchase and redemption of senior notes during the 2023 Period, debt issuance costs, settlements under deferred compensation plans and the purchase of units under the unit repurchase program. These increases were partially offset by increased long-term borrowings.
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Cash Requirements
Management anticipates having sufficient cash flow to meet 2023 cash requirements, including capital expenditures, scheduled payments on long-term debt, lease obligations, asset retirement obligation costs and workers' compensation and pneumoconiosis costs, with our September 30, 2023 cash and cash equivalents of $197.2 million, cash flows from operations, or borrowings under our Revolving Credit Facility and Securitization Facility, if necessary. We currently project average estimated annual maintenance capital expenditures over the next five years of approximately $7.05 per ton produced. Our anticipated total capital expenditures, including maintenance capital expenditures, for 2023 are estimated in a range of $390.0 million to $440.0 million. We will continue to have significant cash 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
See "Item 1. Financial Statements (Unaudited)—Note 6 – Long-Term Debt" of this Quarterly Report on Form 10-Q for a discussion of our long-term debt obligations.
We also have an agreement with a bank to provide additional letters of credit in the amount of $5.0 million to maintain surety bonds to secure certain asset retirement obligations and our obligations for workers' compensation benefits. On September 30, 2023, we had $5.0 million in letters of credit outstanding under this agreement.
Related-Party Transactions
We have related-party transactions and activities with Mr. Craft, MGP and their respective affiliates as well as other related parties. These related-party transactions and activities relate principally to (1) coal mineral leases with The Joseph W. Craft III Foundation and The Kathleen S. Craft Foundation, (2) the use of aircraft, and (3) the purchase of oil & gas mineral interests from JC Resources LP, an entity owned by Mr. Craft. Please read "Item 1. Financial Statements (Unaudited) – Note 2 – Acquisitions" of this Quarterly Report on Form 10-Q for more information on the purchase of oil & gas mineral interests. We also have related-party transactions with (a) WKY CoalPlay, LLC regarding three mineral leases, and (b) with entities in which we hold equity investments. For more information regarding our investments, please read "Item 1. Financial Statements (Unaudited) — Note 9 – Equity Investments" of this Quarterly Report on Form 10-Q. Please read our Annual Report on Form 10-K for the year ended December 31, 2022, "Item 8. Financial Statements and Supplementary Data — Note 22 – Related-Party Transactions" for additional information concerning related-party transactions.
Text extracted from the filing as submitted to EDGAR. Formatting, tables and exhibits are simplified for reading; the original document is authoritative for anything you rely on.