Exhibit 99.1
PRESS RELEASE
ALLIANCE RESOURCE PARTNERS, L.P.
Reports Financial and Operating Results; Declares Quarterly Cash Distribution of $0.70 Per Unit; Completes $50 Million in New Ventures Investments; and Updates Guidance
2023 Quarter Highlights
| ● | Coal sales price realizations of $64.94 per ton sold, up 8.3% year-over-year |
| ● | Record oil & gas royalty volumes of 772 MBOE sold, up 28.2% year-over-year |
| ● | Completed two strategic new ventures investments, totaling approximately $50.0 million |
| ● | Declares a quarterly cash distribution of $0.70 per unit, or $2.80 per unit annualized, up 40.0% year-over-year |
| ● | Reduced outstanding senior notes by $54.6 million during the 2023 Quarter, resulting in total and net leverage ratio of 0.36 times and 0.17 times, respectively |
TULSA, OKLAHOMA, October 27, 2023 — Alliance Resource Partners, L.P. (NASDAQ: ARLP) ("ARLP" or the "Partnership") today reported financial and operating results for the quarter ended September 30, 2023 (the "2023 Quarter"). Total revenues in the 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. Net income for the 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, partially offset by higher interest income and lower income tax expense. EBITDA for the 2023 Quarter was $227.6 million compared to $253.8 million in the 2022 Quarter. (Unless otherwise noted, all references in the text of this release to "net income" refer to "net income attributable to ARLP.")
Compared to the quarter ended June 30, 2023 (the "Sequential Quarter"), total revenues in the 2023 Quarter decreased 0.8% primarily as a result of lower coal sales volumes of 8.5 million tons sold compared to 8.9 million tons sold in the Sequential Quarter, partially offset by higher average coal sales prices, which increased 3.2% to $64.94 per ton sold in the 2023 Quarter. Lower revenues and higher total operating expenses contributed to a reduction in net income and EBITDA of 9.5% and 8.7%, respectively, compared to the Sequential Quarter. (For a definition of EBITDA and related reconciliation to its comparable GAAP financial measure, please see the end of this release.)
Financial and operating results for the nine months ended September 30, 2023 (the "2023 Period") increased compared to the nine months ended September 30, 2022 (the "2022 Period"). Coal sales
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prices and coal sales revenues during the 2023 Period were higher by 16.8% and 14.8%, respectively, compared to the 2022 Period. Increased revenues and lower income tax expense were partially offset by higher total operating expenses in the 2023 Period, which resulted in higher net income and EBITDA by 39.4% and 14.1%, respectively, both as compared to the 2022 Period.
"Our well-contracted coal order book enabled us to navigate an otherwise challenging operating environment during the 2023 Quarter," commented Joseph W. Craft III, Chairman, President and Chief Executive Officer. "Our coal segment achieved higher realized pricing per ton sold relative to both the 2022 and Sequential Quarters, a theme that continues to favorably impact year-to-date results, particularly with regards to EBITDA and net income. However, we faced some difficult mining conditions in Appalachia at all three mines during the 2023 Quarter, which resulted in higher operating costs and fewer tons produced versus previous expectations."
Mr. Craft added, "Our Oil & Gas Royalties segment reported continued growth resulting in record production volumes, underscoring the success of recent acquisitions in core parts of the prolific Permian Basin. Although average realized pricing per BOE during the 2023 Quarter was lower compared to near record levels in the 2022 Quarter, our royalty portfolio is well-positioned to provide significant cash flow via hedge-free exposure to commodity price and cost-free organic growth."
Mr. Craft concluded, "We are excited to announce direct investments in Ascend Elements and Infinitum during the 2023 Quarter. These companies are led by proven management teams and possess innovative, commercial technologies that, in our view, will reshape their respective industries. Beyond our direct investments, we are actively engaged in discussions with both companies to explore additional strategic opportunities intended to unlock value and growth for our unitholders."
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Segment Results and Analysis
|
| | |
| | |
| % Change |
| | |
| |
| |
| | 2023 Third | | 2022 Third | | Quarter / | | 2023 Second | | % Change | |||||
(in millions, except per ton and per BOE data) | | Quarter | | Quarter | | Quarter | | Quarter | | Sequential | |||||
| | | | | | | | | | | | | | | |
Coal Operations (1) | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
Illinois Basin Coal Operations | | | | | | | | | | | | | | | |
Tons sold |
| | 6.049 |
| | 6.109 |
| (1.0) | % |
| | 6.066 |
| (0.3) | % |
Coal sales price per ton sold | | $ | 56.66 | | $ | 51.44 |
| 10.1 | % |
| $ | 54.70 |
| 3.6 | % |
Segment Adjusted EBITDA Expense per ton | | $ | 35.25 | | $ | 31.91 |
| 10.5 | % |
| $ | 35.39 |
| (0.4) | % |
Segment Adjusted EBITDA | | $ | 132.4 | | $ | 120.8 |
| 9.7 | % |
| $ | 119.6 |
| 10.8 | % |
| | | | | | | | | | | | | | | |
Appalachia Coal Operations | | | | | | | | | | | | | | | |
Tons sold | |
| 2.407 | |
| 3.076 |
| (21.7) | % |
|
| 2.838 |
| (15.2) | % |
Coal sales price per ton sold | | $ | 85.74 | | $ | 76.82 |
| 11.6 | % |
| $ | 80.52 |
| 6.5 | % |
Segment Adjusted EBITDA Expense per ton | | $ | 54.84 | | $ | 43.78 |
| 25.3 | % |
| $ | 42.04 |
| 30.4 | % |
Segment Adjusted EBITDA | | $ | 74.8 | | $ | 102.0 |
| (26.6) | % |
| $ | 109.6 |
| (31.7) | % |
| | | | | | | | | | | | | | | |
Total Coal Operations | | | | | | | | | | | | | | | |
Tons sold | |
| 8.456 | |
| 9.185 |
| (7.9) | % |
|
| 8.904 |
| (5.0) | % |
Coal sales price per ton sold | | $ | 64.94 | | $ | 59.94 |
| 8.3 | % |
| $ | 62.93 |
| 3.2 | % |
Segment Adjusted EBITDA Expense per ton | | $ | 41.19 | | $ | 36.20 |
| 13.8 | % |
| $ | 37.85 |
| 8.8 | % |
Segment Adjusted EBITDA | | $ | 204.3 | | $ | 220.1 |
| (7.1) | % |
| $ | 226.2 |
| (9.7) | % |
| | | | | | | | | | | | | | | |
Royalties (1) | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
Oil & Gas Royalties (4) | | | | | | | | | | | | | | | |
BOE sold (2) | |
| 0.772 | |
| 0.602 |
| 28.2 | % |
|
| 0.765 | | 0.9 | % |
Oil percentage of BOE | | | 43.9 | % | | 44.1 | % | (0.5) | % | | | 45.2 | % | (2.9) | % |
Average sales price per BOE (3) | | $ | 44.19 | | $ | 64.27 |
| (31.2) | % |
| $ | 43.27 |
| 2.1 | % |
Segment Adjusted EBITDA Expense | | $ | 3.9 | | $ | 3.9 |
| (1.3) | % |
| $ | 3.6 |
| 8.7 | % |
Segment Adjusted EBITDA | | $ | 31.4 | | $ | 39.4 |
| (20.4) | % |
| $ | 29.1 |
| 8.0 | % |
| | | | | | | | | | | | | | | |
Coal Royalties | | | | | | | | | | | | | | | |
Royalty tons sold | | | 4.993 |
| | 5.654 |
| (11.7) | % |
| | 5.118 |
| (2.4) | % |
Revenue per royalty ton sold | | $ | 3.36 | | $ | 2.96 |
| 13.5 | % |
| $ | 3.24 |
| 3.7 | % |
Segment Adjusted EBITDA Expense | | $ | 6.9 | | $ | 5.5 |
| 23.6 | % |
| $ | 5.6 |
| 22.4 | % |
Segment Adjusted EBITDA | | $ | 9.9 | | $ | 11.2 |
| (11.2) | % |
| $ | 11.0 |
| (9.6) | % |
| | | | | | | | | | | | | | | |
Total Royalties (4) | | | | | | | | | | | | | | | |
Total royalty revenues | | $ | 53.1 | | $ | 58.3 | | (9.0) | % | | $ | 50.0 | | 6.2 | % |
Segment Adjusted EBITDA Expense | | $ | 10.7 | | $ | 9.5 |
| 13.2 | % |
| $ | 9.2 |
| 17.1 | % |
Segment Adjusted EBITDA | | $ | 41.3 | | $ | 50.6 |
| (18.4) | % |
| $ | 40.0 |
| 3.1 | % |
| | | | | | | | | | | | | | | |
Consolidated Total (4)(5) | | | | | | | | | | | | | | | |
Total revenues | | $ | 636.5 | | $ | 632.5 | | 0.6 | % | | $ | 641.8 | | (0.8) | % |
Segment Adjusted EBITDA Expense | | $ | 350.4 | | $ | 330.5 |
| 6.0 | % |
| $ | 338.4 |
| 3.5 | % |
Segment Adjusted EBITDA | | $ | 247.7 | | $ | 275.2 |
| (10.0) | % |
| $ | 269.4 |
| (8.1) | % |
| (1) | For definitions of Segment Adjusted EBITDA Expense and Segment Adjusted EBITDA and related reconciliations to comparable GAAP financial measures, please see the end of this release. Segment Adjusted EBITDA Expense per ton is defined as Segment Adjusted EBITDA Expense – Coal Operations (as reflected in the reconciliation table at the end of this release) divided by total tons sold. Beginning in 2023, we redefined Total Coal Operations to reflect the activity of our wholly-owned subsidiary, Alliance Coal, LLC ("Alliance Coal"), which is the holding company for our coal mining operations. We have retrospectively adjusted Total Coal Operations for the 2022 Quarter to be on the same basis. |
| (2) | Barrels of oil equivalent ("BOE") for natural gas volumes is calculated on a 6:1 basis (6,000 cubic feet of natural gas to one barrel). |
| (3) | Average sales price per BOE is defined as oil & gas royalty revenues excluding lease bonus revenue divided by total BOE sold. |
| (4) | The 2022 Quarter has been recast to reflect the JC Resources Acquisition as though we, rather than JC Resources, acquired the mineral interests in 2019. |
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| (5) | Reflects total consolidated results, which include our other and corporate activities and eliminations in addition to the Illinois Basin Coal Operations, Appalachia Coal Operations, Oil & Gas Royalties and Coal Royalties reportable segments highlighted above. |
Coal Operations
ARLP's coal sales prices per ton increased in all regions compared to both the 2022 and Sequential Quarters. Improved domestic pricing, partially offset by lower export price realizations, drove coal sales prices higher by 10.1% and 3.6% in the Illinois Basin and 11.6% and 6.5% in Appalachia as compared to the 2022 and Sequential Quarters, respectively. Tons sold decreased by 21.7% and 15.2% in Appalachia compared to the 2022 and Sequential Quarters, respectively, due to reduced volumes across the region caused by 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. ARLP ended the 2023 Quarter with total coal inventory of 1.8 million tons, representing an increase of 0.5 million tons compared to the end of the 2022 Quarter and comparable to the end of the Sequential Quarter.
Segment Adjusted EBITDA Expense per ton for the 2023 Quarter increased by 10.5% in the Illinois Basin 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. Segment Adjusted EBITDA Expense per ton in Appalachia increased by 25.3% and 30.4% compared to the 2022 and Sequential Quarters, respectively, due primarily to lower production volumes, purchased coal and increased labor-related, roof support, maintenance and selling expenses per ton.
Royalties
Segment Adjusted EBITDA for the Oil & Gas Royalties segment decreased to $31.4 million in the 2023 Quarter compared to $39.4 million in the 2022 Quarter. The decrease was directly connected to 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. Compared to the Sequential Quarter, Segment Adjusted EBITDA increased by 8.0% due to higher prices and volumes. 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.
Segment Adjusted EBITDA for the Coal Royalties segment was $9.9 million for the 2023 Quarter, representing a decrease of $1.3 million and $1.1 million compared to the 2022 and Sequential Quarters, respectively, 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.
As of September 30, 2023, total debt and finance leases outstanding were $371.0 million, including $284.6 million in ARLP's 2025 senior notes. During the 2023 Quarter, ARLP redeemed $50.0 million and repurchased $4.6 million of its senior notes due May 1, 2025. The Partnership's total and net leverage ratio was 0.36 times and 0.17 times, respectively, as of September 30, 2023. ARLP ended the 2023 Quarter with total liquidity of $629.5 million, which included $197.2 million of cash and cash equivalents and $432.3 million of borrowings available under its revolving credit and accounts receivable securitization facilities.
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On October 25, 2023, the Board of Directors of ARLP’s general partner (the "Board") approved a cash distribution to unitholders for the 2023 Quarter of $0.70 per unit (an annualized rate of $2.80 per unit), payable on November 14, 2023, to all unitholders of record as of the close of trading on November 7, 2023. The announced distribution represents a 40.0% increase over the cash distribution of $0.50 per unit for the 2022 Quarter and is consistent with the Sequential Quarter cash distribution.
Strategic Investments
During the 2023 Quarter, ARLP invested approximately $50 million in two companies that align with the Partnership’s strategy to allocate a portion of excess cash flows into high-growth businesses where ARLP can leverage its core competencies to generate meaningful, risk-adjusted returns.
Ascend Elements, Inc. ("Ascend Elements")
As previously announced, on September 6, 2023, ARLP invested $25 million in Ascend Elements, a U.S.-based manufacturer and recycler of sustainable, engineered battery materials for electric vehicles, as part of its $460 million Series D funding round. This capital, combined with $480 million in total grants awarded by the Department of Energy, will advance construction of North America’s first commercial-scale manufacturing facility, located near Hopkinsville, Kentucky, producing cathode materials for electric vehicle batteries.
In close proximity to ARLP’s western Kentucky mining operations, when complete, the 1-million-square-foot manufacturing facility will produce enough cathode materials for 750,000 electric vehicles per year. ARLP intends to explore other strategic opportunities with Ascend Elements to expand investment in the battery recycling industry and leverage our unique operational expertise, geographic footprint, and strategic relationships in Kentucky and the surrounding battery-belt states to drive value creation for both companies.
Infinitum
During the 2023 Quarter, ARLP invested an additional $24.6 million in Infinitum, a Texas-based developer and manufacturer of high-efficiency electric motors, as part of their ongoing Series E equity raise. The incremental amount brings ARLP’s total investment in the company to approximately $67 million. Infinitum believes that its patented air core motors offer superior performance in half the weight and size, at a fraction of the carbon footprint of traditional motors, making them pound for pound the most efficient in the world.
In addition to the investment, ARLP’s wholly-owned subsidiary Matrix Design Group LLC ("Matrix") and Infinitum are actively evaluating opportunities to combine Matrix’s underground mining expertise with Infinitum’s technology to deliver much needed innovation to the growing global mining industry by improving the safety, efficiency, and performance of certain mining machinery.
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Outlook
"As we assess current market conditions, we have elected to slightly adjust our full year 2023 guidance for coal sales volumes and pricing, which will be highly dependent on logistics during the fourth quarter," commented Mr. Craft. "We expect Appalachia operating expense per ton sold to be 8-10% higher during the fourth quarter of 2023 as development for the new district at Mettiki is not expected to be complete until late November 2023 and Tunnel Ridge has a normally scheduled longwall move. The new longwall district at Mettiki allows us to develop longer panels that will increase production and reduce unit costs in 2024."
Mr. Craft closed, "As we look beyond 2023, we are encouraged by improving fundamentals for coal export demand based on recent trends in international benchmark pricing and emerging opportunities we see in the market. On the domestic front, we hold firm in our conviction that the reliability of our product is highly valued by our customers and the long-term potential for higher natural gas prices and growth in electric demand will sustain our projections for coal demand and lead to a slowing in the pre-mature closure of coal-fired power plants in the eastern U.S."
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ARLP is providing the following updated guidance for the 2023 full year:
| | | | | |
2023 Full Year Guidance | |||||
| | | | | |
Coal Operations | | | | | |
Volumes (Million Short Tons) | | | | | |
Illinois Basin Sales Tons | | | | | 24.5 — 24.8 |
Appalachia Sales Tons | | | | | 10.0 — 10.2 |
Total Sales Tons | | | | | 34.5 — 35.0 |
| | | | | |
Committed & Priced Sales Tons | | | | | |
| | | | | |
2023 — Domestic/Export/Total | | | | | 29.7/5.3/35.0 |
2024 — Domestic/Export/Total | | | | | 25.7/1.6/27.3 |
| | | | | |
Per Ton Estimates | | | | | |
Coal Sales Price per ton sold (1) | | | | | $64.50 — $66.00 |
Segment Adjusted EBITDA Expense per ton sold (2) | | | | | $39.50 — $40.50 |
| | | | | |
Royalties | | | | | |
Oil & Gas Royalties | | | | | |
Oil (000 Barrels) | | | | | 1,400 — 1,500 |
Natural gas (000 MCF) | | | | | 4,750 — 5,250 |
Liquids (000 Barrels) | | | | | 565 — 615 |
Segment Adjusted EBITDA Expense (% of Oil & Gas Royalties Revenue) | | | | | ~ 11.0% |
| | | | | |
Coal Royalties | | | | | |
Royalty tons sold (Million Short Tons) | | | | | 20.4 — 22.6 |
Revenue per royalty ton sold | | | | | $3.00 — $3.20 |
Segment Adjusted EBITDA Expense per royalty ton sold | | | | | $1.00 — $1.10 |
| | | | | |
Consolidated (Millions) | | | | | |
Depreciation, depletion and amortization | | | | | $270 — $280 |
General and administrative | | | | | $80 — $85 |
Net interest expense | | | | | $31 — $32 |
Income tax expense | | | | | $18 — $20 |
Total capital expenditures | | | | | $390 — $440 |
Growth capital expenditures | | | | | $40 — $50 |
Maintenance capital expenditures | | | | | $350 — $390 |
Acquisition of oil & gas royalties (3) | | | | | $100 — $110 |
| (1) | Sales price per ton is defined as total coal sales revenue divided by total tons sold. |
| (2) | Segment Adjusted EBITDA Expense is defined as operating expenses, coal purchases and other expenses. |
| (3) | Acquisition of oil & gas royalties reflects the $72.3 million acquisition from JC Resources LP plus anticipated ground game acquisitions. |
Conference Call
A conference call regarding ARLP's 2023 Quarter financial results is scheduled for today at 10:00 a.m. Eastern. To participate in the conference call, dial (877) 407-0784 and request to be connected to the Alliance Resource Partners, L.P. earnings conference call. International callers should dial (201) 689-8560 and request to be connected to the same call. Investors may also listen to the call via the "investors" section of ARLP's website at www.arlp.com.
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An audio replay of the conference call will be available for approximately one week. To access the audio replay, dial U.S. Toll Free (844) 512-2921; International Toll (412) 317-6671 and request to be connected to replay using access code 13741573.
Concurrent with this announcement, we are providing qualified notice to brokers and nominees that hold ARLP units on behalf of non-U.S. investors under Treasury Regulation Section 1.1446-4(b) and (d) and Treasury Regulation Section 1.1446(f)-4(c)(2)(iii). Brokers and nominees should treat one hundred percent (100%) of ARLP’s distributions to non-U.S. investors as being attributable to income that is effectively connected with a United States trade or business. In addition, brokers and nominees should treat one hundred percent (100%) of the distribution as being in excess of cumulative net income for purposes of determining the amount to withhold. Accordingly, ARLP’s distributions to non-U.S. investors are subject to federal income tax withholding at a rate equal to the highest applicable effective tax rate plus ten percent (10%). Nominees, and not ARLP, are treated as the withholding agents responsible for withholding on the distributions received by them on behalf of non-U.S. investors.
About Alliance Resource Partners, L.P.
ARLP is a diversified energy company that is currently the largest coal producer in the eastern United States, supplying reliable, affordable energy domestically and internationally to major utilities, metallurgical and industrial users. ARLP also generates operating and royalty income from mineral interests it owns in strategic coal and oil & gas producing regions in the United States. In addition, ARLP is evolving and positioning itself as a reliable energy partner for the future by pursuing opportunities that support the advancement of energy and related infrastructure.
News, unit prices and additional information about ARLP, including filings with the Securities and Exchange Commission ("SEC"), are available at www.arlp.com. For more information, contact the investor relations department of ARLP at (918) 295-7673 or via e-mail at investorrelations@arlp.com.
Investor Relations Contact
Cary P. Marshall
Senior Vice President and Chief Financial Officer
918-295-7673
investorrelations@arlp.com
***
The statements and projections used throughout this release are based on current expectations. These statements and projections are forward-looking, and actual results may differ materially. These projections do not include the potential impact of any mergers, acquisitions or other business combinations that may occur after the date of this release. We have included more information below regarding business risks that could affect our results.
FORWARD-LOOKING STATEMENTS: With the exception of historical matters, any matters discussed in this press release are forward-looking statements that involve risks and uncertainties that could cause actual results to differ materially from projected results. Those forward-looking statements include expectations with respect to our future financial performance, coal and oil & gas consumption and expected future prices, our ability to
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increase unitholder distributions in future quarters, business plans and potential growth with respect to our energy and infrastructure transition investments, optimizing cash flows, reducing operating and capital expenditures, preserving liquidity and maintaining financial flexibility, and our future repurchases of units and senior notes, among others. These risks to our ability to achieve these outcomes include, but are not limited to, the following: decline 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 and fuels, such as oil & gas, nuclear energy, and renewable fuels; changes in macroeconomic and market conditions and market volatility, and the impact of such changes and volatility on our financial position; changes in global economic and geo-political conditions or changes in industries in which our customers operate; changes in commodity prices, demand and availability which could affect our operating results and cash flows; the outcome or escalation of current hostilities in Ukraine and the Israel-Gaza conflict; the severity, magnitude and duration of any future pandemics and impacts of such pandemics and of businesses' and governments' responses to such pandemics on our operations and personnel, and on demand for coal, oil, and natural gas, the financial condition of our customers and suppliers, available liquidity and capital sources and broader economic disruptions; actions of the major oil-producing countries with respect to oil production volumes and prices could have direct and indirect impacts over the near and long term on oil & gas exploration and production operations at the properties in which we hold mineral interests; changes in competition in domestic and international coal markets and our ability to respond to such changes; potential shut-ins of production by operators of the properties in which we hold oil & gas mineral interests due to low commodity prices or the lack of downstream demand or storage capacity; risks associated with the expansion of our operations and properties; our ability to identify and complete acquisitions and to successfully integrate such acquisitions into our business and achieve the anticipated benefits therefrom; our ability to identify and invest in new energy and infrastructure transition ventures; the success of our development plans for our wholly owned subsidiary, Matrix Design Group, LLC, and our investments in emerging infrastructure and technology companies; dependence on significant customer contracts, including renewing existing contracts upon expiration; adjustments made in price, volume, or terms to existing coal supply agreements; the effects of and changes in trade, monetary and fiscal policies and laws; central bank policy actions, bank failures and associated liquidity risks; the effects of and changes in taxes or tariffs and other trade measures adopted by the United States and foreign governments; 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, hydraulic fracturing, 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; investors' and other stakeholders' increasing attention to environmental, social, and governance matters; 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; our productivity levels and margins earned on our coal sales; disruptions to oil & gas exploration and production operations at the properties in which we hold mineral interests; changes in equipment, raw material, service or labor costs or availability, including due to inflationary pressures; changes in our ability to recruit, hire and maintain 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
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associated with workers' compensation claims; increases in transportation costs and risk of transportation delays or interruptions; operational interruptions due to geologic, permitting, labor, weather, supply chain shortage of equipment or mine supplies, 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 mineral reserves and resources; uncertainties in estimating and replacing our oil & gas reserves; 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; uncertainties in the future of the electric vehicle industry and the market for EV charging stations; the impact of current and potential changes to federal or state tax rules and regulations, including 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; evolving cybersecurity risks, such as those involving unauthorized access, denial-of-service attacks, malicious software, data privacy breaches by employees, insiders or others with authorized access, cyber or phishing-attacks, ransomware, malware, social engineering, physical breaches, or other actions; and difficulty in making accurate assumptions and projections regarding future revenues and costs associated with equity investments in companies we do not control.
Additional information concerning these, and other factors can be found in ARLP's public periodic filings with the SEC, including ARLP's Annual Report on Form 10-K for the year ended December 31, 2022, filed on February 24, 2023, and ARLP's Quarterly Reports on Form 10-Q for the quarters ended March 31, 2023 and June 30, 2023, filed on May 9, 2023 and August 8, 2023, respectively. Except as required by applicable securities laws, ARLP does not intend to update its forward-looking statements.
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ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF INCOME AND OPERATING DATA
(In thousands, except unit and per unit data)
(Unaudited)
| | Three Months Ended | | Nine Months Ended | | ||||||||
| | September 30, | | September 30, | | ||||||||
| | 2023 |
| 2022* |
| 2023 |
| 2022* |
| ||||
| | | | | | | | | | | | | |
Tons Sold | | | 8,456 | | | 9,185 | | | 25,829 | | | 26,280 | |
Tons Produced | | | 8,356 | | | 8,988 | | | 26,997 | | | 27,044 | |
Mineral Interest Volumes (BOE) | | | 772 | | | 602 | | | 2,296 | | | 1,690 | |
| | | | | | | | | | | | | |
SALES AND OPERATING REVENUES: | | | | | | | | | | | | | |
Coal sales | | $ | 549,123 | | $ | 550,563 | | $ | 1,688,238 | | $ | 1,470,730 | |
Oil & gas royalties | | | 34,125 | | | 38,695 | | | 101,709 | | | 111,378 | |
Transportation revenues | |
| 34,964 | |
| 28,548 | |
| 95,729 | |
| 93,305 | |
Other revenues | |
| 18,309 | |
| 14,655 | |
| 55,603 | |
| 40,348 | |
Total revenues | |
| 636,521 | |
| 632,461 | |
| 1,941,279 | |
| 1,715,761 | |
| | | | | | | | | | | | | |
EXPENSES: | | | | | | | | | | | | | |
Operating expenses (excluding depreciation, depletion and amortization) | |
| 339,099 | |
| 330,694 | |
| 1,012,224 | |
| 909,567 | |
Transportation expenses | |
| 34,964 | |
| 28,548 | |
| 95,729 | |
| 93,305 | |
Outside coal purchases | |
| 11,530 | |
| — | |
| 15,739 | |
| 151 | |
General and administrative | |
| 20,097 | |
| 21,360 | |
| 61,312 | |
| 62,462 | |
Depreciation, depletion and amortization | |
| 65,393 | |
| 70,669 | |
| 199,582 | |
| 202,499 | |
Total operating expenses | |
| 471,083 | |
| 451,271 | |
| 1,384,586 | |
| 1,267,984 | |
| | | | | | | | | | | | | |
INCOME FROM OPERATIONS | |
| 165,438 | |
| 181,190 | |
| 556,693 | |
| 447,777 | |
| | | | | | | | | | | | | |
Interest expense, net | |
| (7,736) | |
| (9,245) | |
| (29,845) | |
| (28,304) | |
Interest income | |
| 2,669 | |
| 426 | |
| 8,084 | |
| 554 | |
Equity method investment income (loss) | |
| (1,842) | |
| 2,108 | |
| (3,784) | |
| 4,576 | |
Other income (expense) | |
| 223 | |
| 193 | |
| (173) | |
| 1,339 | |
INCOME BEFORE INCOME TAXES | |
| 158,752 | |
| 174,672 | |
| 530,975 | |
| 425,942 | |
| | | | | | | | | | | | | |
INCOME TAX EXPENSE | |
| 3,401 | |
| 6,600 | |
| 11,641 | |
| 55,646 | |
| | | | | | | | | | | | | |
NET INCOME | | | 155,351 | | | 168,072 | | | 519,334 | | | 370,296 | |
| | | | | | | | | | | | | |
LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTEREST | | | (1,652) | | | (364) | | | (4,660) | | | (977) | |
| | | | | | | | | | | | | |
NET INCOME ATTRIBUTABLE TO ARLP | | $ | 153,699 | | $ | 167,708 | | $ | 514,674 | | $ | 369,319 | |
| | | | | | | | | | | | | |
NET INCOME ATTRIBUTABLE TO ARLP | | | | | | | | | | | | | |
GENERAL PARTNER | | $ | — | | $ | 3,101 | | $ | 1,384 | | $ | 6,582 | |
LIMITED PARTNERS | | $ | 153,699 | | $ | 164,607 | | $ | 513,290 | | $ | 362,737 | |
| | | | | | | | | | | | | |
EARNINGS PER LIMITED PARTNER UNIT - BASIC AND DILUTED | | $ | 1.18 | | $ | 1.25 | | $ | 3.93 | | $ | 2.76 | |
| | | | | | | | | | | | | |
WEIGHTED-AVERAGE NUMBER OF UNITS OUTSTANDING – BASIC AND DILUTED | |
| 127,125,437 | |
| 127,195,219 | |
| 127,198,805 | |
| 127,195,219 | |
* Recast to reflect the JC Resources Acquisition as though we, rather than JC Resources, acquired the mineral interests in 2019.
Page 11 of 16
ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(In thousands, except unit data)
(Unaudited)
| | September 30, | | December 31, | | ||
| | 2023 |
| 2022* | | ||
ASSETS |
| | | | | |
|
CURRENT ASSETS: | | | | | | | |
Cash and cash equivalents | | $ | 197,243 | | $ | 296,023 | |
Trade receivables | |
| 220,138 | |
| 241,412 | |
Other receivables | |
| 13,854 | |
| 8,601 | |
Inventories, net | |
| 135,868 | |
| 77,326 | |
Advance royalties | |
| 5,824 | |
| 7,556 | |
Prepaid expenses and other assets |
|
| 14,962 |
|
| 26,675 | |
Total current assets | |
| 587,889 | |
| 657,593 | |
PROPERTY, PLANT AND EQUIPMENT: | | | | | | | |
Property, plant and equipment, at cost | |
| 4,133,738 | |
| 3,931,422 | |
Less accumulated depreciation, depletion and amortization | |
| (2,152,278) | |
| (2,050,754) | |
Total property, plant and equipment, net | |
| 1,981,460 | |
| 1,880,668 | |
OTHER ASSETS: | | | | | | | |
Advance royalties | |
| 73,798 | |
| 67,713 | |
Equity method investments | |
| 44,966 | |
| 49,371 | |
Equity securities | | | 92,541 | |
| 42,000 | |
Operating lease right-of-use assets | | | 17,249 | | | 14,950 | |
Other long-term assets | |
| 16,138 | |
| 15,726 | |
Total other assets | |
| 244,692 | |
| 189,760 | |
TOTAL ASSETS | | $ | 2,814,041 | | $ | 2,728,021 | |
| | | | | | | |
LIABILITIES AND PARTNERS' CAPITAL | | | | | | | |
CURRENT LIABILITIES: | | | | | | | |
Accounts payable | | $ | 116,819 | | $ | 95,122 | |
Accrued taxes other than income taxes | |
| 22,516 | |
| 22,967 | |
Accrued payroll and related expenses | |
| 40,803 | |
| 39,623 | |
Accrued interest | |
| 10,631 | |
| 5,000 | |
Workers' compensation and pneumoconiosis benefits | |
| 14,052 | |
| 14,099 | |
Other current liabilities | |
| 30,715 | |
| 53,790 | |
Current maturities, long-term debt, net | |
| 38,603 | |
| 24,970 | |
Total current liabilities | |
| 274,139 | |
| 255,571 | |
LONG-TERM LIABILITIES: | | | | | | | |
Long-term debt, excluding current maturities, net | |
| 321,208 | |
| 397,203 | |
Pneumoconiosis benefits | |
| 102,193 | |
| 100,089 | |
Accrued pension benefit | |
| 11,770 | |
| 12,553 | |
Workers' compensation | |
| 41,303 | |
| 39,551 | |
Asset retirement obligations | |
| 143,707 | |
| 142,254 | |
Long-term operating lease obligations | |
| 14,358 | |
| 12,132 | |
Deferred income tax liabilities | |
| 34,343 | |
| 35,814 | |
Other liabilities | |
| 18,092 | |
| 24,828 | |
Total long-term liabilities | |
| 686,974 | |
| 764,424 | |
Total liabilities | |
| 961,113 | |
| 1,019,995 | |
| | | | | | | |
COMMITMENTS AND CONTINGENCIES | | | | | | | |
| | | | | | | |
PARTNERS' CAPITAL: | | | | | | | |
ARLP Partners' Capital: | | | | | | | |
Limited Partners - Common Unitholders 127,125,437 and 127,195,219 units outstanding, respectively | |
| 1,867,721 | |
| 1,656,025 | |
General Partner's interest | |
| — | |
| 66,548 | |
Accumulated other comprehensive loss | |
| (39,365) | |
| (41,054) | |
Total ARLP Partners' Capital | |
| 1,828,356 | |
| 1,681,519 | |
Noncontrolling interest | | | 24,572 | | | 26,507 | |
Total Partners' Capital | | | 1,852,928 | | | 1,708,026 | |
TOTAL LIABILITIES AND PARTNERS' CAPITAL | | $ | 2,814,041 | | $ | 2,728,021 | |
* Recast to reflect the JC Resources Acquisition as though we, rather than JC Resources, acquired the mineral interests in 2019.
Page 12 of 16
ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(In thousands)
(Unaudited)
| | Nine Months Ended | | ||||
| | September 30, | | ||||
| | 2023 |
| 2022* | | ||
| | | | | | | |
CASH FLOWS FROM OPERATING ACTIVITIES | | $ | 735,411 | | $ | 556,206 | |
| | | | | | | |
CASH FLOWS FROM INVESTING ACTIVITIES: | | | | | | | |
Property, plant and equipment: | | | | | | | |
Capital expenditures | | | (295,356) | | | (221,286) | |
Change in accounts payable and accrued liabilities | | | (23,006) | | | 39,500 | |
Proceeds from sale of property, plant and equipment | |
| 3,436 | | | 5,006 | |
Contributions to equity method investments | | | (2,257) | | | (20,220) | |
Purchase of equity securities | | | (49,560) | | | (32,639) | |
JC Resources acquisition | | | (64,999) | | | — | |
Payments for acquisitions of businesses | | | — | | | (11,391) | |
Escrow deposit for oil & gas reserve acquisition | | | — | | | (4,150) | |
Oil & gas reserve acquisition | | | (13,902) | | | — | |
Other | | | 1,160 | | | (2,317) | |
Net cash used in investing activities | | | (444,484) | | | (247,497) | |
| | | | | | | |
CASH FLOWS FROM FINANCING ACTIVITIES: | | | | | | | |
Borrowings under securitization facility | | | — | | | 27,500 | |
Payments under securitization facility | | | — | | | (27,500) | |
Payments on equipment financings | | | (11,421) | | | (12,360) | |
Borrowing under long-term debt | | | 75,000 | | | — | |
Payments on long-term debt | | | (120,080) | | | — | |
Payments on finance lease obligations | | | (334) | | | (623) | |
Payment of debt issuance costs | | | (11,744) | | | — | |
Payments for purchases of units under unit repurchase program | | | (19,432) | | | — | |
Payments for tax withholdings related to settlements under deferred compensation plans | | | (10,334) | | | — | |
Excess purchase price over the contributed basis from JC Resources acquisition | | | (7,251) | | | — | |
Cash retained by JC Resources in acquisition | | | (2,933) | | | (7,652) | |
Distributions paid to Partners | | | (273,767) | | | (130,898) | |
Other | | | (7,411) | | | (1,108) | |
Net cash used in financing activities | | | (389,707) | | | (152,641) | |
| | | | | | | |
NET CHANGE IN CASH AND CASH EQUIVALENTS | | | (98,780) | | | 156,068 | |
| | | | | | | |
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD | | | 296,023 | | | 122,403 | |
| | | | | | | |
CASH AND CASH EQUIVALENTS AT END OF PERIOD | | $ | 197,243 | | $ | 278,471 | |
* Recast to reflect the JC Resources Acquisition as though we, rather than JC Resources, acquired the mineral interests in 2019.
Page 13 of 16
Reconciliation of Non-GAAP Financial Measures
Reconciliation of GAAP "net income attributable to ARLP" to non-GAAP "EBITDA" and "Distributable Cash Flow" (in thousands).
EBITDA is defined as net income attributable to ARLP before net interest expense, income taxes and depreciation, depletion and amortization. Distributable cash flow ("DCF") is defined as EBITDA excluding equity method investment earnings, interest expense (before capitalized interest), interest income, income taxes and estimated maintenance capital expenditures and adding distributions from equity method investments. Distribution coverage ratio ("DCR") is defined as DCF divided by distributions paid to partners.
Management believes that the presentation of such additional financial measures provides useful information to investors regarding our performance and results of operations because these measures, when used in conjunction with related GAAP financial measures, (i) provide additional information about our core operating performance and ability to generate and distribute cash flow, (ii) provide investors with the financial analytical framework upon which management bases financial, operational, compensation and planning decisions and (iii) present measurements that investors, rating agencies and debt holders have indicated are useful in assessing us and our results of operations.
EBITDA, DCF and DCR should not be considered as alternatives to net income attributable to ARLP, net income, income from operations, cash flows from operating activities or any other measure of financial performance presented in accordance with GAAP. EBITDA and DCF are not intended to represent cash flow and do not represent the measure of cash available for distribution. Our method of computing EBITDA, DCF and DCR may not be the same method used to compute similar measures reported by other companies, or EBITDA, DCF and DCR may be computed differently by us in different contexts (i.e., public reporting versus computation under financing agreements).
| | Three Months Ended | | Nine Months Ended | | Three Months Ended |
| |||||||||
| | September 30, | | September 30, | | June 30, |
| |||||||||
|
| 2023 |
| 2022 (1) |
| 2023 |
| 2022 (1) |
| 2023 |
| |||||
| | | | | | | | | | | | | | | | |
Net income attributable to ARLP | | $ | 153,699 | | $ | 167,708 | | $ | 514,674 | | $ | 369,319 | | $ | 169,790 | |
Depreciation, depletion and amortization | |
| 65,393 | |
| 70,669 | |
| 199,582 | |
| 202,499 | |
| 68,639 | |
Interest expense, net | |
| 6,876 | |
| 9,083 | |
| 26,193 | |
| 28,255 | |
| 8,024 | |
Capitalized interest | |
| (1,809) | |
| (264) | |
| (4,432) | |
| (505) | |
| (1,216) | |
Income tax expense | |
| 3,401 | |
| 6,600 | |
| 11,641 | |
| 55,646 | |
| 3,999 | |
EBITDA | |
| 227,560 | |
| 253,796 | |
| 747,658 | |
| 655,214 | |
| 249,236 | |
Equity method investment loss (income) | |
| 1,842 | | | (2,108) | |
| 3,784 | | | (4,576) | | | 1,994 | |
Distributions from equity method investments | | | 904 | | | 2,448 | | | 2,878 | | | 4,963 | | | 960 | |
Interest expense, net | |
| (6,876) | |
| (9,083) | |
| (26,193) | |
| (28,255) | |
| (8,024) | |
Income tax expense | |
| (3,401) | |
| (6,600) | |
| (11,641) | |
| (55,646) | |
| (3,999) | |
Deferred income tax expense (benefit) (2) | | | (2,400) | | | 269 | | | (2,981) | | | 37,275 | | | (209) | |
Estimated maintenance capital expenditures (3) | |
| (58,910) | |
| (50,872) | |
| (190,329) | |
| (153,069) | |
| (66,249) | |
Distributable Cash Flow | | $ | 158,719 | | $ | 187,850 | | $ | 523,176 | | $ | 455,906 | | $ | 173,709 | |
Distributions paid to partners | | $ | 90,899 | | $ | 52,338 | | $ | 273,767 | | $ | 130,898 | | $ | 90,930 | |
Distribution Coverage Ratio | |
| 1.75 | |
| 3.59 | |
| 1.91 | |
| 3.48 | |
| 1.91 | |
Page 14 of 16
| (1) | Recast to reflect the JC Resources Acquisition as though we, rather than JC Resources, acquired the mineral interests in 2019. |
| (2) | Deferred income tax expense (benefit) is the amount of income tax expense (benefit) during the period on temporary differences between the tax basis and financial reporting basis of recorded assets and liabilities. These differences generally arise in one period and reverse in subsequent periods to eventually offset each other and do not impact the amount of distributable cash flow available to be paid to partners. |
| (3) | Maintenance capital expenditures are those capital expenditures required to maintain, over the long-term, the existing infrastructure of our coal assets. We estimate maintenance capital expenditures on an annual basis based upon a five-year planning horizon. For the 2023 planning horizon, average annual estimated maintenance capital expenditures are assumed to be $7.05 per ton produced compared to an estimated $5.66 per ton produced in 2022. Our actual maintenance capital expenditures fluctuate depending on various factors, including maintenance schedules and timing of capital projects, among others. |
Reconciliation of GAAP "Cash flows from operating activities" to non-GAAP "Free cash flow" (in thousands).
Free cash flow is defined as cash flows from operating activities less capital expenditures and the change in accounts payable and accrued liabilities from purchases of property, plant and equipment. Free cash flow should not be considered as an alternative to cash flows from operating activities or any other measure of financial performance presented in accordance with GAAP. Our method of computing free cash flow may not be the same method used by other companies. Free cash flow is a supplemental liquidity measure used by our management to assess our ability to generate excess cash flow from our operations.
| | Three Months Ended | | Nine Months Ended | | Three Months Ended |
| |||||||||
| | September 30, | | September 30, | | June 30, |
| |||||||||
|
| 2023 |
| 2022 (1) |
| 2023 |
| 2022 (1) |
| 2023 |
| |||||
| | | | | | | | | | | | | | | | |
Cash flows from operating activities | | $ | 231,388 | | $ | 316,815 | | $ | 735,411 | | $ | 556,206 | | $ | 280,764 | |
Capital expenditures | | | (110,339) | | | (99,304) | | | (295,356) | | | (221,286) | | | (89,543) | |
Change in accounts payable and accrued liabilities | | | 2,624 | | | 30,549 | | | (23,006) | | | 39,500 | | | (37,740) | |
Free cash flow | | $ | 123,673 | | $ | 248,060 | | $ | 417,049 | | $ | 374,420 | | $ | 153,481 | |
| (1) | Recast to reflect the JC Resources Acquisition as though we, rather than JC Resources, acquired the mineral interests in 2019. |
Reconciliation of GAAP "Operating Expenses" to non-GAAP "Segment Adjusted EBITDA Expense" and Reconciliation of non-GAAP " EBITDA" to "Segment Adjusted EBITDA" (in thousands).
Segment Adjusted EBITDA Expense includes operating expenses, coal purchases, if applicable, and other income or expense. Transportation expenses are excluded as these expenses are passed on to our customers and, consequently, we do not realize any margin 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 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. Segment Adjusted EBITDA Expense – Coal Operations represents Segment Adjusted EBITDA Expense from our wholly-owned subsidiary, Alliance Coal, which holds our coal mining operations and related support activities.
Page 15 of 16
| | Three Months Ended | | Nine Months Ended | | Three Months Ended |
| |||||||||
| | September 30, | | September 30, | | June 30, |
| |||||||||
|
| 2023 |
| 2022 (1) |
| 2023 |
| 2022 (1) |
| 2023 |
| |||||
| | | | | | | | | | | | | | | | |
Operating expense | | $ | 339,099 | | $ | 330,694 | | $ | 1,012,224 | | $ | 909,567 | | $ | 334,402 | |
Outside coal purchases | |
| 11,530 | |
| — | |
| 15,739 | |
| 151 | |
| 4,209 | |
Other expense (income) | |
| (223) | |
| (193) | |
| 173 | |
| (1,339) | |
| (177) | |
Segment Adjusted EBITDA Expense | | | 350,406 | | | 330,501 | | | 1,028,136 | | | 908,379 | | | 338,434 | |
Segment Adjusted EBITDA Expense – Non Coal Operations (2) | | | (2,116) | | | 2,002 | | | (6,945) | | | (410) | | | (1,409) | |
Segment Adjusted EBITDA Expense – Coal Operations | | $ | 348,290 | | $ | 332,503 | | $ | 1,021,191 | | $ | 907,969 | | $ | 337,025 | |
| (1) | Recast to reflect the JC Resources Acquisition as though we, rather than JC Resources, acquired the mineral interests in 2019. |
| (2) | Non Coal Operations represent activity outside of Alliance Coal and primarily consist of Total Royalties, our investments in the advancement of energy and related infrastructure and various eliminations primarily between Alliance Coal and our Coal Royalty segment. |
Segment Adjusted EBITDA 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 – Coal Operations represents Segment Adjusted EBITDA from our wholly-owned subsidiary, Alliance Coal, which holds our coal mining operations and related support activities and allows management to focus primarily on the operating performance of our Illinois Basin and Appalachia segments.
| | Three Months Ended | | Nine Months Ended | | Three Months Ended |
| |||||||||
| | September 30, | | September 30, | | June 30, |
| |||||||||
|
| 2023 |
| 2022 (1) |
| 2023 |
| 2022 (1) | | 2023 |
| |||||
| | | | | | | | | | | | | | | | |
EBITDA (See reconciliation to GAAP above) | | $ | 227,560 | | $ | 253,796 | | $ | 747,658 | | $ | 655,214 | | $ | 249,236 | |
General and administrative | |
| 20,097 | |
| 21,360 | |
| 61,312 | |
| 62,462 | |
| 20,130 | |
Segment Adjusted EBITDA | | | 247,657 | | | 275,156 | | | 808,970 | | | 717,676 | | | 269,366 | |
Segment Adjusted EBITDA – Non Coal Operations (2) | | | (43,322) | | | (55,093) | | | (132,735) | | | (148,380) | | | (43,140) | |
Segment Adjusted EBITDA – Coal Operations | | $ | 204,335 | | $ | 220,063 | | $ | 676,235 | | $ | 569,296 | | $ | 226,226 | |
| (1) | Recast to reflect the JC Resources Acquisition as though we, rather than JC Resources, acquired the mineral interests in 2019. |
| (2) | Non Coal Operations represent activity outside of Alliance Coal and primarily consist of Total Royalties, our investments in the advancement of energy and related infrastructure and various eliminations primarily between Alliance Coal and our Coal Royalty segment. |
Page 16 of 16