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2 months ago
Alliance Resource Partners, L.P. Reports First Quarter Financial and Operating Results; Declares Quarterly Cash Distribution of $0.60 Per Unit; and Updates 2026 GuidanceApril 27, 2026 7:00 AM
Business Wire
2026 Quarter Highlights
Total revenue of $516.0 million, net income of $9.1 million, and Adjusted EBITDA of $155.0 million
2026 expected coal sales volumes over 95% committed and priced at the midpoint of 2026 guidance
Record oil & gas royalty revenues and volumes, up 14.6% and 16.1%, respectively, year-over-year
Completed $16.2 million in oil & gas mineral interest acquisitions during the 2026 Quarter
Total and net leverage ratios as of March 31, 2026, were 0.73 times and 0.69 times, respectively
Declares quarterly cash distribution of $0.60 per unit, or $2.40 per unit annualized
Alliance Resource Partners, L.P. (NASDAQ: ARLP) ("ARLP" or the "Partnership") today reported financial and operating results for the quarter ended March 31, 2026 (the "2026 Quarter"). This release includes comparisons of results to the quarter ended March 31, 2025 (the "2025 Quarter") and to the quarter ended December 31, 2025 (the "Sequential Quarter"). All references in the text of this release to "net income" refer to "net income attributable to ARLP." For a definition of Adjusted EBITDA and Segment Adjusted EBITDA Expense and related reconciliations to comparable GAAP financial measures, please see the end of this release.
Total revenues decreased 4.5% to $516.0 million for the 2026 Quarter compared to $540.5 million for the 2025 Quarter primarily due to lower coal sales pricing, partially offset by record oil & gas royalty revenues and higher coal sales volumes. Net income for the 2026 Quarter was $9.1 million, or $0.07 per basic and diluted limited partner unit, compared to $74.0 million, or $0.57 per basic and diluted limited partner unit, for the 2025 Quarter. Net income was impacted by lower coal sales and higher depreciation, as well as an $11.6 million decrease in the fair value of our digital assets and a $37.8 million non-cash asset impairment charge in the 2026 Quarter due to ceasing longwall production and uncertainty regarding future operations at our Mettiki mine. Adjusted EBITDA decreased 3.1% to $155.0 million in the 2026 Quarter compared to $159.9 million in the 2025 Quarter.
Compared to the Sequential Quarter, total revenues decreased by 3.6% due to lower coal sales volumes and prices, partially offset by higher oil & gas royalty revenues. Net income decreased by 89.0% compared to the Sequential Quarter primarily due to lower production and lower coal sales volumes from our Hamilton mine as a result of a planned extended longwall move during the 2026 Quarter that led to higher per ton operating expenses. In addition, increased depreciation, non-cash asset impairment charges at Mettiki and lower investment income contributed to lower net income in the 2026 Quarter. Adjusted EBITDA for the 2026 Quarter decreased by 18.9% compared to the Sequential Quarter primarily due to higher costs at Hamilton and Mettiki.
CEO Commentary
"Most of our coal operations performed better than expected during the quarter, however meaningful weather-related shipment disruptions relating to Winter Storm Fern delayed sales volumes for the quarter," said Joseph W. Craft III, Chairman, President and Chief Executive Officer. "In the Illinois Basin, increased productivity at River View and Gibson South helped offset some of the impact of the planned extended longwall move at Hamilton. In Appalachia, Tunnel Ridge had production gains of approximately 28% compared to both the 2025 Quarter and the Sequential Quarter, while results at Mettiki reflected lower production and a non-cash impairment associated with ceasing longwall production and uncertainty regarding future operations as previously discussed."
Mr. Craft added, "We delivered another record quarter in our oil & gas royalties segment, driven by increased production volumes and higher oil prices. Increased drilling and completion activity across our core basins continues to validate the quality of our mineral portfolio, and for the second consecutive quarter, we expanded our portfolio, completing $16.2 million in acquisitions during the quarter. These results underscore the durability of our asset base and reinforce our disciplined approach to allocating capital to attractive, long-lived mineral interests. We believe our oil and gas royalties portfolio enhances our cash flow stability and long-term optionality across commodity cycles."
Segment Results and Analysis (Unaudited)
% Change
2026 First
2025 First
Quarter /
2025 Fourth
% Change
(in millions, except per ton and per BOE data)
Quarter
Quarter
Quarter
Quarter
Sequential
Coal Operations (1)
Illinois Basin Coal Operations
Tons sold
6.068
6.042
0.4
%
6.451
(5.9
)
%
Coal sales price per ton sold
$
51.05
$
55.15
(7.4
)
%
$
50.83
0.4
%
Segment Adjusted EBITDA Expense per ton
$
35.20
$
34.75
1.3
%
$
34.04
3.4
%
Segment Adjusted EBITDA
$
99.2
$
126.2
(21.4
)
%
$
110.9
(10.6
)
%
Appalachia Coal Operations
Tons sold
1.792
1.729
3.6
%
1.660
8.0
%
Coal sales price per ton sold
$
74.51
$
78.24
(4.8
)
%
$
83.77
(11.1
)
%
Segment Adjusted EBITDA Expense per ton
$
62.19
$
69.73
(10.8
)
%
$
63.34
(1.8
)
%
Segment Adjusted EBITDA
$
26.2
$
15.6
67.9
%
$
34.6
(24.3
)
%
Total Coal Operations
Tons sold
7.860
7.771
1.1
%
8.111
(3.1
)
%
Coal sales price per ton sold
$
56.40
$
60.29
(6.5
)
%
$
57.57
(2.0
)
%
Segment Adjusted EBITDA Expense per ton
$
41.42
$
42.75
(3.1
)
%
$
40.24
2.9
%
Segment Adjusted EBITDA
$
125.1
$
140.2
(10.8
)
%
$
144.0
(13.2
)
%
Royalties (1)
Oil & Gas Royalties
BOE sold (2)
1.022
0.880
16.1
%
0.989
3.3
%
Oil percentage of BOE
43.5
%
43.7
%
(0.5
)
%
43.3
%
0.5
%
Average sales price per BOE (3)
$
40.47
$
41.00
(1.3
)
%
$
34.60
17.0
%
Segment Adjusted EBITDA Expense
$
6.0
$
5.7
4.2
%
$
4.1
44.9
%
Segment Adjusted EBITDA
$
34.6
$
29.9
15.8
%
$
30.0
15.2
%
Coal Royalties
Royalty tons sold
6.612
5.072
30.4
%
6.501
1.7
%
Revenue per royalty ton sold
$
2.89
$
3.11
(7.1
)
%
$
3.45
(16.2
)
%
Segment Adjusted EBITDA Expense
$
7.1
$
6.4
11.3
%
$
7.8
(9.2
)
%
Segment Adjusted EBITDA
$
12.3
$
9.4
30.6
%
$
14.6
(15.7
)
%
Total Royalties
Total royalty revenues
$
61.2
$
52.7
16.1
%
$
56.8
7.7
%
Segment Adjusted EBITDA Expense
$
13.1
$
12.1
8.0
%
$
12.0
9.4
%
Segment Adjusted EBITDA
$
46.9
$
39.3
19.3
%
$
44.6
5.1
%
Consolidated Total
Total revenues
$
516.0
$
540.5
(4.5
)
%
$
535.5
(3.6
)
%
Segment Adjusted EBITDA Expense
$
331.0
$
346.2
(4.4
)
%
$
332.4
(0.4
)
%
Segment Adjusted EBITDA
$
179.0
$
180.5
(0.8
)
%
$
211.9
(15.5
)
%
___________________________
(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.
(2)
Barrels of oil equivalent (“BOE”) for natural gas volumes are 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.
Coal Operations
Coal sales volumes decreased by 5.9% in the Illinois Basin compared to the Sequential Quarter due primarily to decreased tons sold from our Hamilton mine as a result of a planned extended longwall move during the 2026 Quarter. In Appalachia, tons sold increased by 3.6% and 8.0% compared to the 2025 Quarter and Sequential Quarter, respectively, primarily as a result of fewer production days in the prior periods at our Tunnel Ridge mine due to longwall moves. Coal sales price per ton sold decreased by 7.4% in the Illinois Basin compared to the 2025 Quarter as a result of the expiration of higher priced legacy contracts. In Appalachia, coal sales price per ton sold decreased by 4.8% and 11.1% compared to the 2025 Quarter and Sequential Quarter, respectively, primarily due to an increased sales mix of lower priced Tunnel Ridge sales volumes in the 2026 Quarter and reduced domestic sales price per ton. ARLP ended the 2026 Quarter with total coal inventory of 1.2 million tons, representing a decrease of 0.2 million tons and an increase of 0.1 million tons compared to the end of the 2025 Quarter and Sequential Quarter, respectively.
Segment Adjusted EBITDA Expense per ton in the Illinois Basin increased 3.4% compared to the Sequential Quarter due primarily to the planned extended longwall move at our Hamilton mine during the 2026 Quarter. In Appalachia, Segment Adjusted EBITDA Expense per ton for the 2026 Quarter decreased by 10.8% compared to the 2025 Quarter as a result of increased production at our Tunnel Ridge operation primarily as a result of fewer production days due to the longwall moves in the 2025 Quarter.
Royalties
Segment Adjusted EBITDA for the Oil & Gas Royalties segment increased to $34.6 million in the 2026 Quarter compared to $29.9 million and $30.0 million in the 2025 Quarter and Sequential Quarter, respectively, due to record oil & gas royalty volumes, which increased 16.1% and 3.3%, respectively, as a result of increased drilling and completion activities on our interests and acquisitions of additional oil & gas mineral interests. Improved commodity pricing also contributed to the increase in Segment Adjusted EBITDA compared to the Sequential Quarter.
Segment Adjusted EBITDA for the Coal Royalties segment increased to $12.3 million in the 2026 Quarter compared to $9.4 million in the 2025 Quarter due to higher royalty tons sold, primarily from Tunnel Ridge, partially offset by lower average royalty rates per ton received from the Partnership's mining subsidiaries. Compared to the Sequential Quarter, Segment Adjusted EBITDA for the Coal Royalties segment decreased 15.7%, primarily reflecting lower realized royalty rates per ton.
Balance Sheet and Liquidity
As of March 31, 2026, total debt and finance leases were outstanding in the amount of $507.7 million. The Partnership’s total and net leverage ratios were 0.73 times and 0.69 times debt to trailing twelve months Adjusted EBITDA, respectively, as of March 31, 2026. ARLP ended the 2026 Quarter with total liquidity of $431.2 million, which included $28.9 million of cash and cash equivalents and $402.3 million of borrowings available under its revolving credit and accounts receivable securitization facilities. In addition, ARLP held 618 bitcoins valued at $42.2 million as of March 31, 2026.
Distributions
ARLP announced today that the Board of Directors of ARLP’s general partner approved a cash distribution to unitholders for the 2026 Quarter of $0.60 per unit (an annualized rate of $2.40 per unit), payable on May 15, 2026, to all unitholders of record as of the close of trading on May 8, 2026.
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.
Outlook
"Looking ahead, contracting activity with domestic utility customers for 2026 has remained active, though the pace has varied as some customers continue to evaluate summer burn requirements," commented Mr. Craft. "During the quarter, the Iran conflict briefly reopened U.S. thermal coal export activity in early March, enabling us to enter into contracts for 1.8 million tons to be delivered in 2026 and 2027. In addition, we sold an additional 0.5 million tons to domestic customers, bringing our sales book to more than 95% committed and priced for 2026 assuming production comes in at the midpoint of our guidance range. Our remaining open position is concentrated in the second half of 2026, where additional commitments will depend on summer burn and customer requirements. More broadly, we continue to see a constructive demand backdrop as growing power demand, particularly from data centers, reinforces the importance of reliable baseload generation."
Mr. Craft continued, "We expect first quarter shipment disruptions tied to Winter Storm Fern and subsequent high-water conditions to be recovered over the balance of the year. In addition, once the planned longwall moves at Hamilton and Tunnel Ridge are completed in the second quarter, we do not expect any further longwall moves in 2026, which should improve operating visibility for the back half of the year."
Mr. Craft concluded, "Based on year-to-date outperformance of our oil & gas royalties, we are increasing our volume guidance for the segment. Recent strength and volatility in crude oil prices have increased the near-term outlook and, because our current portfolio is unhedged, changes in market prices are reflected directly in our realized pricing. If current market conditions persist, we would expect realized BOE prices to be higher than last year, contributing to stronger segment results."
ARLP is updating the following guidance for the full year ending December 31, 2026:
2026 Full Year Guidance
Coal Operations
Volumes (Million Short Tons)
Illinois Basin Sales Tons
26.00 — 27.00
Appalachia Sales Tons
7.75 — 8.25
Total Sales Tons
33.75 — 35.25
Committed & Priced Sales Tons
2026 — Domestic / Export / Total
30.5 / 2.5 / 33.0
2027 — Domestic / Export / Total
21.1 / 1.3 / 22.4
Coal Sales Price Per Ton Sold (1)
Illinois Basin
$50.00 — $52.00
Appalachia
$66.00 — $71.00
Total
$54.00 — $56.00
Segment Adjusted EBITDA Expense Per Ton Sold (2)
Illinois Basin
$33.00 — $35.00
Appalachia
$49.00 — $53.00
Total
$37.00 — $39.00
Royalties
Oil & Gas Royalties
Oil (000 Barrels)
1,600 — 1,700
Natural gas (000 MCF)
6,600 — 7,000
Liquids (000 Barrels)
875 — 925
Segment Adjusted EBITDA Expense (% of Oil & Gas Royalties Revenue)
~ 14.0%
Coal Royalties
Royalty tons sold (Million Short Tons)
30.0 — 30.8
Revenue per royalty ton sold
$3.00 — $3.20
Segment Adjusted EBITDA Expense per royalty ton sold
$1.10 — $1.20
Consolidated (Millions)
Depreciation, depletion and amortization
$315 — $325
General and administrative
$95 — $100
Net interest expense
$43 — $47
Income tax expense
$22 — $24
Total capital expenditures
$280 — $300
___________________________
(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, if applicable, and other income or expense as adjusted to remove certain items from operating expenses that we characterize as unrepresentative of our ongoing operations.
Conference Call
A conference call regarding ARLP’s 2026 Quarter financial results and updated 2026 guidance 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.
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 13759702.
About Alliance Resource Partners, L.P.
ARLP is a diversified natural resource company that is currently the second 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 positioning itself as a reliable energy partner for the future by pursuing opportunities that support the growth and development of energy-related technologies and 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.
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 and operational performance, coal and oil & gas consumption and expected future prices, our ability to increase or maintain unitholder distributions in future quarters, business plans and potential growth with respect to our energy and infrastructure investments, optimizing cash flows, reducing operating and capital expenditures, infrastructure projects at our existing properties, growth in domestic electricity demand, preserving liquidity and maintaining financial flexibility, and our future repurchases of units. 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, the cost and perceived benefits of other sources of electricity and fuels, such as oil & gas, nuclear energy, and renewable fuels and the retirement of coal-fired power plants in the U.S.; our ability to provide fuel for growth in domestic energy demand, should it materialize; 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; impacts of geopolitical events, including the conflicts in Ukraine and in the Middle East; actions of the major oil-producing countries with respect to oil production volumes and prices and the 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 the 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 and investments into the infrastructure of our operations and properties, including the timing of such investments coming online; 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 ventures; the success of our development and growth plans for our wholly owned subsidiary, Matrix Design Group, LLC, and our investments in emerging and other infrastructure and technology companies; dependence on significant customer contracts, and failure of customers to renew 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, and the results of central bank policy actions including interest rates, bank failures, and associated liquidity risks; the effects of and changes in taxes or tariffs and other trade measures adopted or threatened by the United States and foreign governments, including the imposition of or increase in tariffs on steel and/or other raw materials; legislation, regulations, and court decisions and interpretations thereof, both domestic and foreign, including those relating to the environment and the release of greenhouse gases, such as state legislation seeking to impose liability on a wide range of energy companies under greenhouse gas “superfund” laws, 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’ attention to sustainability 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 or tariffs; changes in our ability to recruit, hire and maintain labor; our ability to maintain satisfactory relations with our employees; increases in labor costs, including increases in the costs of health insurance, adverse changes in work rules, or cash payments or projections 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; 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, 2025, filed on February 26, 2026. Except as required by applicable securities laws, ARLP does not intend to update its forward-looking statements.
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
March 31,
2026
2025
Tons Sold
7,860
7,771
Tons Produced
7,984
8,457
Mineral Interest Volumes (BOE)
1,022
880
SALES AND OPERATING REVENUES:
Coal sales
$
443,282
$
468,511
Oil & gas royalties
41,341
36,084
Transportation revenues
8,643
10,200
Other revenues
22,751
25,673
Total revenues
516,017
540,468
EXPENSES:
Operating expenses (excluding depreciation, depletion and amortization)
341,298
339,436
Transportation expenses
8,643
10,200
Outside coal purchases
—
7,345
General and administrative
24,041
20,580
Depreciation, depletion and amortization
82,354
68,629
Asset impairments
37,820
—
Total operating expenses
494,156
446,190
INCOME FROM OPERATIONS
21,861
94,278
Interest expense, net
(11,744
)
(8,434
)
Interest income
318
867
Net income (loss) on equity method investments
4,286
(2,006
)
Change in fair value of digital assets
(11,629
)
(5,574
)
Other income
10,340
611
INCOME BEFORE INCOME TAXES
13,432
79,742
INCOME TAX EXPENSE
2,685
4,182
NET INCOME
10,747
75,560
LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTEREST
(1,653
)
(1,577
)
NET INCOME ATTRIBUTABLE TO ARLP
$
9,094
$
73,983
EARNINGS PER LIMITED PARTNER UNIT - BASIC AND DILUTED
$
0.07
$
0.57
WEIGHTED-AVERAGE NUMBER OF UNITS OUTSTANDING – BASIC AND DILUTED
128,538,284
128,265,338
ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(In thousands, except unit data)
(Unaudited)
March 31,
December 31,
2026
2025
ASSETS
CURRENT ASSETS:
Cash and cash equivalents
$
28,869
$
71,212
Trade receivables (net of allowance of $5,435 and $5,360, respectively)
166,573
129,686
Other receivables
1,079
1,992
Inventories, net
143,564
142,619
Advance royalties
10,410
10,496
Digital assets
42,210
51,834
Prepaid expenses and other assets
15,990
22,215
Total current assets
408,695
430,054
PROPERTY, PLANT AND EQUIPMENT:
Property, plant and equipment
4,412,583
4,502,648
Less accumulated depreciation, depletion and amortization
(2,264,329
)
(2,364,206
)
Total property, plant and equipment, net
2,148,254
2,138,442
OTHER ASSETS:
Advance royalties
77,652
72,412
Equity method investments
70,986
69,638
Equity securities
86,353
82,466
Operating lease right-of-use assets
14,332
17,065
Other long-term assets
49,436
43,711
Total other assets
298,759
285,292
TOTAL ASSETS
$
2,855,708
$
2,853,788
LIABILITIES AND PARTNERS' CAPITAL
CURRENT LIABILITIES:
Accounts payable
$
94,642
$
81,809
Accrued taxes other than income taxes
20,597
20,319
Accrued payroll and related expenses
34,265
31,244
Accrued interest
10,906
2,012
Workers' compensation and pneumoconiosis benefits
15,901
15,901
Other current liabilities
34,197
29,495
Current maturities, long-term debt, net
69,806
23,646
Total current liabilities
280,314
204,426
LONG-TERM LIABILITIES:
Long-term debt, excluding current maturities, net
426,116
427,137
Pneumoconiosis benefits
101,743
100,740
Workers' compensation
37,684
37,742
Asset retirement obligations
162,543
153,247
Long-term operating lease obligations
11,868
14,591
Deferred income tax liabilities
27,091
27,732
Other liabilities
26,054
27,951
Total long-term liabilities
793,099
789,140
Total liabilities
1,073,413
993,566
COMMITMENTS AND CONTINGENCIES
PARTNERS' CAPITAL:
ARLP Partners' Capital:
Limited Partners - Common Unitholders 128,658,801 and 128,428,024 units outstanding, respectively
1,772,237
1,843,627
Accumulated other comprehensive loss
(7,386
)
(1,026
)
Total ARLP Partners' Capital
1,764,851
1,842,601
Noncontrolling interest
17,444
17,621
Total Partners' Capital
1,782,295
1,860,222
TOTAL LIABILITIES AND PARTNERS' CAPITAL
$
2,855,708
$
2,853,788
ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(In thousands)
(Unaudited)
Three Months Ended
March 31,
2026
2025
CASH FLOWS FROM OPERATING ACTIVITIES
$
105,509
$
145,686
CASH FLOWS FROM INVESTING ACTIVITIES:
Property, plant and equipment:
Capital expenditures
(95,690
)
(86,776
)
Change in accounts payable and accrued liabilities
3,470
(6,196
)
Proceeds from sale of property, plant and equipment
278
241
Contributions to equity method investments
(586
)
(878
)
Oil & gas reserve business combinations
(14,525
)
—
Oil & gas reserve asset acquisitions
(1,724
)
(33
)
Other
945
580
Net cash used in investing activities
(107,832
)
(93,062
)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings under securitization facility
56,000
4,000
Payments under securitization facility
(11,000
)
(4,000
)
Payments on equipment financings
(3,387
)
(3,118
)
Borrowings under revolving credit facilities
17,000
—
Payments under revolving credit facilities
(17,000
)
—
Borrowing under long-term debt
5,903
—
Payments on long-term debt
(3,516
)
(3,516
)
Payments for purchase of units and tax withholdings related to settlements under deferred compensation plans
(4,142
)
(7,082
)
Distributions paid to Partners
(78,009
)
(90,891
)
Other
(1,862
)
(3,701
)
Net cash used in financing activities
(40,013
)
(108,308
)
Effect of exchange rate changes on cash and cash equivalents
(7
)
35
NET CHANGE IN CASH AND CASH EQUIVALENTS
(42,343
)
(55,649
)
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD
71,212
136,962
CASH AND CASH EQUIVALENTS AT END OF PERIOD
$
28,869
$
81,313
Reconciliation of Non-GAAP Financial Measures (Unaudited)
Reconciliation of GAAP “net income attributable to ARLP” to non-GAAP “EBITDA,” “Adjusted EBITDA,” “Distribution Coverage Ratio” 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 and Adjusted EBITDA is EBITDA adjusted for certain items that we characterize as unrepresentative of our ongoing operations. Distributable cash flow (“DCF”) is defined as Adjusted 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, Adjusted 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, Adjusted EBITDA, DCF and DCR may not be the same method used to compute similar measures reported by other companies, or EBITDA, Adjusted 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
Three Months Ended
March 31,
December 31,
2026
2025
2025
Net income attributable to ARLP
$
9,094
$
73,983
$
82,666
Depreciation, depletion and amortization
82,354
68,629
76,256
Interest expense, net
12,339
12,055
11,541
Capitalized interest
(913
)
(4,488
)
(1,157
)
Income tax expense
2,685
4,182
3,349
EBITDA
105,559
154,361
172,655
Asset impairments
37,820
—
—
Change in fair value of digital assets
11,629
5,574
15,375
Impairment loss on investments (1)
—
—
3,037
Adjusted EBITDA
155,008
159,935
191,067
Net loss (income) on equity method investments
(4,286
)
2,006
(20,031
)
Distributions from equity method investments
3,524
849
6,094
Interest expense, net
(12,339
)
(12,055
)
(11,541
)
Income tax expense
(2,685
)
(4,182
)
(3,349
)
Deferred income tax benefit (2)
(3,708
)
(861
)
(2,537
)
Estimated maintenance capital expenditures (3)
(57,724
)
(61,567
)
(59,616
)
Distributable Cash Flow
$
77,790
$
84,125
$
100,087
Distributions paid to partners
$
78,009
$
90,891
$
77,772
Distribution Coverage Ratio
1.00
0.93
1.29
___________________________
(1)
Impairment loss on investments represents a $3.0 million write-down in December 2025 related to an investment in convertible notes of a battery materials company.
(2)
Deferred income tax benefit is the amount of income tax 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 2026 planning horizon, average annual estimated maintenance capital expenditures are assumed to be $7.23 per ton produced compared to an estimated $7.28 per ton produced in 2025. 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
Three Months Ended
March 31,
December 31,
2026
2025
2025
Cash flows from operating activities
$
105,509
$
145,686
$
143,876
Capital expenditures
(95,690
)
(86,776
)
(44,759
)
Change in accounts payable and accrued liabilities
3,470
(6,196
)
(5,271
)
Free cash flow
$
13,289
$
52,714
$
93,846
Reconciliation of GAAP “Operating Expenses” to non-GAAP “Segment Adjusted EBITDA Expense” and Reconciliation of non-GAAP “Adjusted EBITDA” to non-GAAP “Segment Adjusted EBITDA” (in thousands).
Segment Adjusted EBITDA Expense is defined as operating expenses, coal purchases, if applicable, and other income or expense as adjusted to remove certain items from operating expenses that we characterize as unrepresentative of our ongoing operations. 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, LLC (“Alliance Coal”), which holds our coal mining operations and related support activities.
Three Months Ended
Three Months Ended
March 31,
December 31,
2026
2025
2025
Operating expense
$
341,298
$
339,436
$
328,193
Outside coal purchases
—
7,345
2,782
Other expense (income)
(10,340
)
(611
)
1,382
Segment Adjusted EBITDA Expense
330,958
346,170
332,357
Segment Adjusted EBITDA Expense – Non Coal Operations (1)
(5,430
)
(13,947
)
(5,991
)
Segment Adjusted EBITDA Expense – Coal Operations
$
325,528
$
332,223
$
326,366
___________________________
(1)
Non Coal Operations represent activity outside of Alliance Coal and primarily consist of Total Royalties, our investments in growth-oriented businesses and energy-related technologies, our investments in emerging energy and related infrastructure opportunities and various eliminations primarily between Alliance Coal and our Coal Royalty segment.
Segment Adjusted EBITDA is defined as Adjusted EBITDA adjusted for 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
Three Months Ended
March 31,
December 31,
2026
2025
2025
Adjusted EBITDA (See reconciliation to GAAP above)
$
155,008
$
159,935
$
191,067
General and administrative
24,041
20,580
20,786
Segment Adjusted EBITDA
179,049
180,515
211,853
Segment Adjusted EBITDA – Non Coal Operations (1)
(53,993
)
(40,310
)
(67,829
)
Segment Adjusted EBITDA – Coal Operations
$
125,056
$
140,205
$
144,024
___________________________
(1)
Non Coal Operations represent activity outside of Alliance Coal and primarily consist of Total Royalties, our investments in growth-oriented businesses and energy-related technologies, our investments in emerging energy and related infrastructure opportunities and various eliminations primarily between Alliance Coal and our Coal Royalty segment.
View source version on businesswire.com: https://www.businesswire.com/news/home/20260427222572/en/
Investor Relations Contact
Cary P. Marshall
Senior Vice President and Chief Financial Officer
918-295-7673
investorrelations@arlp.com
Original: Alliance Resource Partners, L.P. Reports First Quarter Financial and Operating Results; Declares Quarterly Cash Distribution of $0.60 Per Unit; and Updates 2026 Guidance
US Market News
5 months ago
Alliance Resource Partners, L.P. Announces Issuance of WARN Act Notice at Mettiki Coal (WV), LLCJanuary 29, 2026 4:15 PM
Business Wire
Alliance Resource Partners, L.P. (NASDAQ: ARLP) ("ARLP" or the "Partnership") announced today that its subsidiary, Mettiki Coal (WV), LLC (“Mettiki”), issued Worker Adjustment and Retraining Notification (“WARN”) Act notices to all employees of Mettiki’s Mountain View Mine near Tucker County, West Virginia.
"Mettiki has a long operating history, having been part of ARLP and its predecessor entities for nearly 50 years," said Joseph W. Craft, III, Chairman, President and Chief Executive Officer. "We recognize today’s announcement will affect families and communities that have supported this mine for generations, and that decision weighs heavily on us."
Mr. Craft continued, "Unfortunately, a series of planned and unplanned outages at a key customer’s plant negatively impacted their demand and our shipments in 2025. We have recently been informed that the plant expects additional outages during 2026 and based upon current demand projections and contractual commitments for 2026, they are not in a position to commit to purchase any additional tons from Mettiki for the foreseeable future. Due to the location of the mine and the low-volatile quality of coal the mine produces, Mettiki’s livelihood depends on this customer purchasing a minimum of one million tons per year for it to be viable under its existing operating plan. With no clear alternative customer to absorb production, issuing WARN Act notices became an unavoidable step. We remain committed to open communication with our employees and community partners as we move forward."
The Mettiki mine, an indirect wholly-owned subsidiary of ARLP, currently employs approximately two hundred employees. Mettiki’s full year coal sales and production volumes for 2025 was approximately 1.2 million tons, with 300 thousand tons shipped to the export metallurgical market and the balance to the key customer’s plant in question.
As of January 29, 2026, Mettiki expects to fulfill its existing contractual commitments, which are scheduled to conclude in March 2026, primarily from existing inventory. Production will immediately cease, giving Mettiki time to evaluate its options concerning the mine’s future and the exact timing for permanent closure. Mettiki employees not involved in the reduced production of coal will focus efforts on reclamation activities, as needed, throughout the Mountain View Mine.
The Partnership will reflect the anticipated impact of reduced sales volumes at Mettiki in its 2026 guidance, which is scheduled to be announced on February 2, 2026. For the year ended December 31, 2025, Segment Adjusted EBITDA less capital expenditures attributable to the operation was approximately $3.5 million. Additionally, the Partnership will evaluate any potential impairment related to this decision during the first quarter of 2026.
About Alliance Resource Partners, L.P.
ARLP is a diversified energy company that is currently the second 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 positioning itself as a reliable energy partner for the future by pursuing opportunities that support the growth and development 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.
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 and operational performance, coal and oil & gas consumption and expected future prices, our ability to increase or maintain 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, infrastructure projects at our existing properties, growth in domestic electricity demand, preserving liquidity and maintaining financial flexibility, our future repurchases of units, and the impact of recently announced tax legislation. 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, the cost and perceived benefits of other sources of electricity and fuels, such as oil & gas, nuclear energy, and renewable fuels and the planned retirement of coal-fired power plants in the U.S.; our ability to provide fuel for growth in domestic energy demand, should it materialize; 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 effects of a prolonged government shutdown; impacts of geopolitical events, including the conflicts in Ukraine and in the Middle East; 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 and operators, available liquidity and capital sources and broader economic disruptions; actions of the major oil-producing countries with respect to oil production volumes and prices and the 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 the 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 and investments into the infrastructure of our operations and properties, including the timing of such investments coming online; 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 and other 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, and the results of central bank policy actions including interest rates, 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, including the imposition of or increase in tariffs on steel and/or other raw materials; legislation, regulations, and court decisions and interpretations thereof, both domestic and foreign, including those relating to the environment and the release of greenhouse gases, such as the Environmental Protection Agency’s emissions regulations for coal-fired power plants, and state legislation seeking to impose liability on a wide range of energy companies under greenhouse gas “superfund” laws, 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’ 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, adverse changes in work rules, or cash payments or projections 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, 2024, filed on February 27, 2025, and ARLP’s Quarterly Reports on Form 10-Q for the quarters ended March 31, 2025, June 30, 2025 and September 30, 2025, filed on May 9, 2025, August 7, 2025 and November 7, 2025, respectively. Except as required by applicable securities laws, ARLP does not intend to update its forward-looking statements.
View source version on businesswire.com: https://www.businesswire.com/news/home/20260129644498/en/
Investor Relations Contact
Cary P. Marshall
Senior Vice President and Chief Financial Officer
918-295-7673
investorrelations@arlp.com
Original: Alliance Resource Partners, L.P. Announces Issuance of WARN Act Notice at Mettiki Coal (WV), LLC
swanlinbar
8 years ago
ARLP i think you are right but i did sell half my position & doubled down on ARB Arbor Realty Trust Reports First Quarter Results and Increases Quarterly Dividend 19% to $0.25 per Share
8:00 am ET May 4, 2018 (Globe Newswire) Print
Company Highlights:
-- GAAP net income of $0.42 per diluted common share; AFFO of $0.25, or $0.28 per diluted common share excluding a one-time, non-cash expense from the early repayment of debt
-- Declares a cash dividend on common stock of $0.25 per share, 19% higher than last quarter and our sixth increase in the past eight quarters
Agency Business
-- Segment income of $31.2 million
-- Loan originations of $1.05 billion
-- Servicing portfolio of $16.69 billion, up 3% from 4Q17
Structured Business
-- Segment income of $4.3 million
-- Portfolio growth of 5% on $314.2 million of loan originations
-- Issued $100.0 million of 5.625% senior notes due in 2023, a 175 basis point rate reduction from our 7.375% senior notes redeemed in April 2018
Arbor Realty Trust, Inc. (NYSE:ABR) today announced financial results for the first quarter ended March 31, 2018. Arbor reported net income for the quarter of $26.2 million, or $0.42 per diluted common share, compared to $15.6 million, or $0.30 per diluted common share for the quarter ended March 31, 2017. Adjusted funds from operations ("AFFO") for the quarter was $21.4 million, or $0.25 per diluted common share, compared to $24.7 million, or $0.33 per diluted common share for the quarter ended March 31, 2017.
Agency Business
Loan Origination Platform
Agency Loan Volume (in thousands)
Quarter Ended
March 31, December 31,
2018 2017
Fannie Mae $ 662,921 $ 712,661
Freddie Mac 308,151 441,901
FHA 60,738 -
CMBS/Conduit 16,233 -
Total Originations $ 1,048,043 $ 1,154,562
Total Loan Sales $ 1,062,437 $ 1,193,629
Total Loan Commitments $ 1,043,715 $ 1,162,961
For the quarter ended March 31, 2018, the Agency Business generated revenues of $54.4 million, compared to $53.7 million for the fourth quarter of 2017. Gain on sales, including fee-based services, net was $18.2 million for the quarter, reflecting a margin of 1.71% on loan sales, compared to $17.7 million and 1.48% for the fourth quarter of 2017. Income from mortgage servicing rights was $19.6 million for the quarter, reflecting a rate of 1.88% as a percentage of loan commitments, compared to $20.6 million and 1.77% for the fourth quarter of 2017.
At March 31, 2018, loans held-for-sale was $286.3 million which was primarily comprised of unpaid principal balances totaling $281.8 million, with financing associated with these loans totaling $281.3 million.
Fee-Based Servicing Portfolio
Our fee-based servicing portfolio totaled $16.69 billion at March 31, 2018, an increase of 3% from December 31, 2017, primarily a result of $1.05 billion of new loan originations, net of $548.1 million in portfolio runoff during the quarter. Servicing revenue, net was $9.5 million for the quarter and consists of servicing revenue of $21.4 million, net of amortization of mortgage servicing rights totaling $11.9 million.
Fee-Based Servicing Portfolio ($ in thousands)
As of March 31, 2018 As of December 31, 2017
UPB Wtd. Avg. Fee Wtd. Avg. Life (in years) UPB Wtd. Avg. Fee Wtd. Avg. Life (in years)
Fannie Mae $ 12,700,635 0.535% 7.2 $ 12,502,699 0.536% 6.9
Freddie Mac 3,397,535 0.304% 10.7 3,166,134 0.295% 10.5
FHA 591,836 0.162% 20.0 537,482 0.165% 19.6
Total $ 16,690,006 0.475% 8.4 $ 16,206,315 0.477% 8.1
Loans sold under the Fannie Mae program contain an obligation to partially guarantee the performance of the loan ("loss-sharing obligations"). At March 31, 2018, the Company's allowance for loss-sharing obligations was $31.1 million which consists of general loss sharing guaranty obligations of $30.3 million, representing 0.24% of the Fannie Mae servicing portfolio, and $0.8 million of loss-sharing obligations on specifically identified loans with losses determined to be probable and estimable.
Structured Business
Portfolio and Investment Activity
First quarter of 2018:
-- 19 new loan originations totaling $314.2 million, of which 18 were bridge loans for $271.7 million
-- Payoffs and pay downs on 20 loans totaling $190.6 million
-- Portfolio growth of 5% from 4Q17
At March 31, 2018, the loan and investment portfolio's unpaid principal balance, excluding loan loss reserves, was $2.78 billion, with a weighted average current interest pay rate of 6.57%, compared to $2.66 billion and 6.28% at December 31, 2017. Including certain fees earned and costs associated with the loan and investment portfolio, the weighted average current interest pay rate was 7.28% at March 31, 2018, compared to 6.99% at December 31, 2017. The increase in the average current interest pay rate was primarily due to an increase in LIBOR.
The average balance of the Company's loan and investment portfolio during the first quarter of 2018, excluding loan loss reserves, was $2.68 billion with a weighted average yield on these assets of 7.08%, compared to $2.31 billion and 6.94% for the fourth quarter of 2017.
At March 31, 2018, the Company's total loan loss reserves were $63.1 million on five loans with an aggregate carrying value before loan loss reserves of $163.9 million. The Company also had two non-performing loans with a carrying value of $29.1 million, net of related loan loss reserves of $7.4 million.
Financing Activity
The balance of debt that finances the Company's loan and investment portfolio at March 31, 2018 was $2.45 billion with a weighted average interest rate including fees of 5.09% as compared to $2.24 billion and a rate of 4.83% at December 31, 2017. The average balance of debt that finances the Company's loan and investment portfolio for the first quarter of 2018 was $2.30 billion, as compared to $1.90 billion for the fourth quarter of 2017. The average cost of borrowings for the first quarter was 5.33%, compared to 4.66% for the fourth quarter of 2017. The increase in average costs was primarily due to an increase in LIBOR as well as the acceleration of fees related to the early repayment of debt.
The Company is subject to various financial covenants and restrictions under the terms of its collateralized securitization vehicles and financing facilities. The Company believes it was in compliance with all financial covenants and restrictions as of March 31, 2018 and as of the most recent collateralized securitization vehicle determination dates in April 2018.
The Company paid $50.0 million in full satisfaction of the seller financing related to the acquisition of the Agency Business.
Capital Markets
The Company issued $100.0 million aggregate principal amount of 5.625% senior unsecured notes in a private placement, generating net proceeds of $97.8 million after deducting the underwriting discount and other offering expenses. The notes are due in May 2023 and can be redeemed by the Company at any time prior to April 1, 2023. The proceeds were used to fund the redemption in April 2018 of $97.9 million aggregate principal amount of the Company's 7.375% senior notes due in 2021.
Dividends
The Company announced today that its Board of Directors has declared a quarterly cash dividend of $0.25 per share of common stock for the quarter ended March 31, 2018, representing an increase of 19% over the prior quarter dividend of $0.21 per share. The dividend is payable on May 31, 2018 to common stockholders of record on May 15, 2018. The ex-dividend date is May 14, 2018.
The Company also announced today that its Board of Directors has declared cash dividends on the Company's Series A, Series B and Series C cumulative redeemable preferred stock reflecting accrued dividends from March 1, 2018 through May 31, 2018. The dividends are payable on May 31, 2018 to preferred stockholders of record on May 15, 2018. The Company will pay total dividends of $0.515625, $0.484375 and $0.53125 per share on the Series A, Series B and Series C preferred stock, respectively.
Earnings Conference Call
The Company will host a conference call today at 10:00 a.m. Eastern Time. A live webcast of the conference call will be available at www.arbor.com in the investor relations area of the website. Those without web access should access the call telephonically at least ten minutes prior to the conference call. The dial-in numbers are (866) 516-5034 for domestic callers and (678) 509-7613 for international callers. Please use participant passcode 6184718.
After the live webcast, the call will remain available on the Company's website through May 31, 2018. In addition, a telephonic replay of the call will be available until May 11, 2018. The replay dial-in numbers are (855) 859-2056 for domestic callers and (404) 537-3406 for international callers. Please use passcode 6184718.
About Arbor Realty Trust, Inc.
Arbor Realty Trust, Inc. (NYSE:ABR) is a real estate investment trust and national direct lender specializing in loan origination and servicing for multifamily, seniors housing, healthcare and other diverse commercial real estate assets. Arbor is a Top 10 Fannie Mae DUS Multifamily Lender by volume and a Top Fannie Mae Small Loan lender, a Freddie Mac Program Plus Seller/Servicer and a Top Freddie Mac Small Balance Loan Lender, a Fannie Mae and Freddie Mac Seniors Housing Lender, an FHA Multifamily Accelerated Processing (MAP)/LEAN Lender, a HUD-approved LIHTC Lender as well as a CMBS, bridge, mezzanine and preferred equity lender, consistently building on its reputation for service, quality and flexibility. With a fee-based servicing portfolio of over $16 billion, Arbor is a primary commercial loan servicer and special servicer rated by Standard & Poor's with an Above Average rating. Arbor is also on the Standard & Poor's Select Servicer List and is a primary commercial loan servicer and loan level special servicer rated by Fitch Ratings.
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