Company News »

Foresight Energy LP Announces Full-Year and Fourth Quarter 2014 Results

Business Wire
Share on StockTwits
Published on

Foresight Energy LP (NYSE:FELP) , today reported financial and operating results for the year ended December 31, 2014, setting new records for coal production, sales volumes, coal sales revenue and Adjusted EBITDA. Coal sales revenue for the year grew to $1.1 billion, up 16% from 2013, contributing to record Adjusted EBITDA of $404.5 million and record net income attributable to controlling interests of $135.2 million, or $1.04 per Full-Year Earnings per Unit. FELP’s full-year results were negatively impacted by a fourth quarter prepaid royalty impairment charge of $34.7 million, or $0.27 per Full-Year Earnings per Unit, but benefited by $57.1 million, or $0.44 per Full-Year Earnings per Unit, in unrealized gains on coal derivative contracts.

For the quarter ended December 31, 2014, FELP also set records for coal sales revenue and Adjusted EBITDA. The increased production from FELP’s second longwall mine at its Sugar Camp complex drove record coal sales revenue of $300.0 million and Adjusted EBITDA of $112.5 million, an increase over the prior year fourth quarter of 12% and 13%, respectively. FELP reported net income attributable to controlling interests of $29.1 million, or $0.22 per unit, for the fourth quarter 2014, which was impacted by the aforementioned $34.7 million, or $0.27 per unit, prepaid royalty impairment and $23.4 million, or $0.18 per unit, in unrealized gains on coal derivative contracts.

FELP also announced that the Board of Directors of its general partner approved a quarterly cash distribution for the fourth quarter 2014 of $0.36 per unit, (an annualized rate of $1.44 per unit). The distribution represents an increase of 2.9% from the third quarter 2014 distribution of $0.35 per unit. The distribution is payable on February 27, 2015 for unitholders of record on February 16, 2015.

“We are pleased to report record results for 2014, including new records for coal production, sales volumes, coal sales revenue and Adjusted EBITDA,” said Michael Beyer, President and Chief Executive Officer. “The results reflect the continued strong operating performance of our mining operations, which includes the three most productive underground coal mines in the United States in 2014, as reported by MSHA and measured by clean tons produced per man hour worked. Our teams at the mines and throughout the organization continue to perform at the highest levels driving exceptional results and growth in a very challenging market. We thank them for their effort and dedication.”

Consolidated Financial Results

Year Ended December 31, 2014 Compared to Year Ended December 31, 2013

The start-up of the second longwall at our Sugar Camp complex in June 2014 and a higher committed sales position drove record coal sales revenue and record sales volumes during the year ended December 31, 2014. The increase in coal sales revenue of $152.0 million from the prior year was offset by a $1.17 per ton, or 2%, decrease in coal sales realization per ton caused by a lower mix of international shipments as well as a small decline in the average realization per ton on both international and domestic sales.

Our cost of coal produced increased $89.0 million, or 25% from the prior year, due to higher sales volumes as noted above, as well as a $1.34 increase in the cost per ton. The increase in our cost per ton was driven by increased production costs at our Sugar Camp and Hillsboro operations. The impact at our Sugar Camp complex during this period was due to the introduction of additional continuous miner development units and higher water handling costs, including those associated with the reverse osmosis system we installed during the year. Our Hillsboro mine was unfavorably impacted during 2014 by an underground fire which halted production for most of August and resulted in direct incremental costs of $2.5 million.

Transportation costs increased $28.2 million, or 14%, during the year ended December 31, 2014 due to increased sales volumes and higher charges for shortfalls on minimum contractual throughput volumes. On a per ton basis, our transportation costs were favorably impacted by a lower percentage of our sales going to international markets during 2014.

Adjusted EBITDA increased $42.2 million, or 12%, to $404.5 million for the year ended December 31, 2014 due primarily to the 3.5 million ton increase in sales volumes compared to the prior year, offset by lower coal sales realization and higher production costs.

Three Months Ended December 31, 2014 Compared to Three Months Ended December 31, 2013

Record coal sales revenue of $300.0 million for the three months ended December 31, 2014 was up 12% compared to the prior year. The increase in sales volumes to 5.9 million tons was driven by the start-up of the second longwall at our Sugar Camp complex in June 2014.

Cost of coal produced increased $21.8 million, or 21%, compared to the fourth quarter of 2013 due to higher sales volumes and a $1.66 increase in cost per ton. The increase in cost per ton was driven by the introduction of additional continuous miner development units at our Sugar Camp complex and increased subsidence, repairs and maintenance costs at our Hillsboro mine.

Adjusted EBITDA increased $12.9 million, or 13%, from the fourth quarter of 2013 to $112.5 million driven by the 14% increase in sales volumes, offset by higher production costs and higher selling, general and administrative expenses.

Liquidity and Financing

As of December 31, 2014, FELP had $199.4 million of liquidity comprised of $25.4 million in cash and $174.0 million of availability for borrowings under its revolving credit facility. During the fourth quarter, FELP secured permanent financing on a set of longwall shields with a $55 million capital lease. On January 13, 2015, FELP entered into a receivables securitization program with capacity of $70 million, which will provide additional liquidity and reduce our average borrowing costs. The $112 million of proceeds from both transactions were used to pay down a portion of the outstanding amounts under the revolving credit facility.

Outlook

For 2015, FELP is providing the following guidance for its operating and investment activities:

Sales Volumes – During 2015, sales volumes are currently estimated to be between 22.8 and 25.2 million tons. FELP has current commitments for 20.8 million tons for 2015.

Adjusted EBITDA – FELP currently expects to generate Adjusted EBITDA in a range of $385 to $425 million, comparable to 2014 results at the midpoint.

Capital Expenditures – Total 2015 capital expenditures are estimated to be between $115 and $130 million, including maintenance capital estimates of $80 to $90 million for distributable cash flow purposes.

Safe Harbor Provisions Regarding Forward-Looking Statements

This press release contains “forward-looking” statements within the meaning of the federal securities laws. These statements contain words such as “possible,” “intend,” “will,” “if” and “expect” and can be impacted by numerous factors, including risks relating to the securities markets generally, the impact of adverse market conditions affecting business of the Partnership, adverse changes in laws including with respect to tax and regulatory matters and other risks. There can be no assurance that actual results will not differ from those expected by management of the Partnership. The Partnership undertakes no obligation to update or revise such forward-looking statements to reflect events or circumstances that occur, or which FELP becomes aware of, after the date hereof.

Non-GAAP Financial Measures

Adjusted EBITDA, distributable cash flow (“DCF”) and Full-Year Earnings per Unit are non-GAAP supplemental financial measures that management and external users of FELP’s consolidated financial statements, such as industry analysts, investors, lenders and rating agencies, may use to assess:

o

the Partnership’s operating performance as compared to other publicly traded partnerships, without regard to historical cost basis or, in the case of Adjusted EBITDA, financing methods;

o

the ability of the Partnership’s assets to generate sufficient cash flow to make distributions to its unitholders;

o

the Partnership’s ability to incur and service debt and fund capital expenditures; and

o

the viability of acquisitions and other capital expenditure projects and the returns on investment of various expansion and growth opportunities.

We define Adjusted EBITDA as net income attributable to controlling interests before interest, income taxes, depreciation, depletion, amortization and accretion. Adjusted EBITDA is also adjusted for equity-based compensation, unrealized gains or losses on derivatives, early debt extinguishment costs and material nonrecurring or other items which may not reflect the trend of future results. We define DCF as Adjusted EBITDA less cash interest expense, net and estimated maintenance capital expenditures. We define Full-Year Earnings per Unit as net income attributable to controlling interests for the year ended December 31, 2014 divided by the total outstanding units of the Partnership.

We believe that the presentation of Adjusted EBITDA and DCF provides useful information to investors in assessing its financial condition and results of operations. Adjusted EBITDA and DCF should not be considered alternatives to net income, operating income, cash from operations or any other measure of financial performance or liquidity presented in accordance with U.S. GAAP, nor should Adjusted EBITDA and DCF be considered alternatives to operating surplus, adjusted operating surplus or other definitions in its partnership agreement. Adjusted EBITDA and DCF have important limitations as analytical tools because they exclude some but not all items that affect net income and net cash provided by operating activities. Neither Adjusted EBITDA nor DCF will be impacted by changes in working capital balances that are reflected in operating cash flow. Additionally, because Adjusted EBITDA and DCF may be defined differently by other companies in the industry, the Partnership’s definition of Adjusted EBITDA and DCF may not be comparable to similarly titled measures of other companies, thereby diminishing their utility. For a reconciliation of these non-GAAP measures to their most directly comparable GAAP financial measures, please see the table below.

About Foresight Energy LP

Foresight Energy LP is a leading producer and marketer of thermal coal controlling over 3 billion tons of coal reserves in the Illinois Basin. Foresight currently operates four mining complexes (Williamson, Sugar Camp, Hillsboro and Macoupin), with four longwall systems. Foresight’s operations are strategically located near multiple rail and river transportation access points, providing transportation cost certainty and flexibility to direct shipments to the domestic and international markets.

Foresight Energy LP
Unaudited Consolidated Statements of Operations
For the Three Months Ended
December 31,
For the Year Ended
December 31,
2014 2013 2014 2013
(In Thousands, Except per Unit Data)
Coal sales $ 300,040 $ 268,021 $ 1,109,404 $ 957,412
Costs and expenses:
Cost of coal produced (excluding depreciation, depletion and amortization) 126,841 105,035 449,905 360,861
Cost of coal purchased 5,560 18,232 2,163
Transportation 61,369 58,851 226,029 197,839
Depreciation, depletion and amortization 45,137 46,150 167,039 161,216
Accretion on asset retirement obligations 405 382 1,621 1,527
Impairment of prepaid royalties 34,700 34,700
Selling, general and administrative 7,047 3,307 33,679 32,291
Gain on coal derivatives (34,911 ) (512 ) (76,330 ) (2,392 )
Other operating income, net (1,113 ) (544 ) (2,527 ) (280 )
Operating income 55,005 55,352 257,056 204,187
Other expenses:
Loss on early extinguishment of debt 18 4,979 77,773
Interest expense, net 24,874 30,371 113,030 115,897
Net income 30,131 24,963 139,047 10,517
Less: net income attributable to noncontrolling interests 1,075 1,226 3,847 2,236
Net income attributable to controlling interests 29,056 $ 23,737 135,200 $ 8,281
Less: predecessor net income attributable to controlling interests prior to initial public offering 65,008
Net income subsequent to initial public offering attributable to limited partner units (June 23, 2014 through December 31, 2014) $ 29,056 $ 70,192
Net income subsequent to initial public offering available to limited partner units – basic and diluted:
Common units $ 14,534 $ 35,154
Subordinated units $ 14,522 $ 35,038
Net income subsequent to initial public offering per limited partner unit – basic and diluted:
Common units $ 0.22 $ 0.54
Subordinated units $ 0.22 $ 0.54
Weighted average limited partner units outstanding – basic and diluted:
Common units 64,795 64,790
Subordinated units 64,739 64,739
Foresight Energy LP
Unaudited Consolidated Balance Sheets
December 31,
2014
December 31,
2013
(In Thousands)
Assets
Current assets:
Cash and cash equivalents $ 25,406 $ 23,284
Accounts receivable 80,763 58,987
Due from affiliates 574 368
Inventories 92,402 71,290
Prepaid expenses 2,134 3,028
Prepaid royalties 8,380 6,330
Deferred longwall costs 23,224 14,265
Coal derivative assets 36,080 1,976
Other current assets 6,302 6,568
Total current assets 275,265 186,096
Property, plant, equipment and development, net 1,473,063 1,414,074
Prepaid royalties 59,967 73,242
Coal derivative assets 24,957 912
Other assets 31,970 35,847
Total assets $ 1,865,222 $ 1,710,171
Liabilities and partners’ capital (deficit)
Current liabilities:
Current portion of long-term debt and capital lease obligations $ 44,143 $ 70,034
Accrued interest 25,136 27,645
Accounts payable 59,937 50,155
Accrued expenses and other current liabilities 37,602 37,515
Due to affiliates 15,878 9,572
Total current liabilities 182,696 194,921
Long-term debt and capital lease obligations 1,316,528 1,449,179
Sale-leaseback financing arrangements 193,434 193,434
Asset retirement obligations 31,373 20,416
Other long-term liabilities 5,508 337
Total liabilities 1,729,539 1,858,287
Limited partners’ capital (deficit):
Common unitholders (64,831 units outstanding as of December 31, 2014) 238,925
Subordinated unitholders (64,739 units outstanding as of December 31, 2014) (111,169 )
Total limited partners’ capital 127,756
Predecessor members’ deficit (157,356 )
Noncontrolling interests 7,927 9,240
Total partners’ capital (deficit) 135,683 (148,116 )
Total liabilities and partners’ capital (deficit) $ 1,865,222 $ 1,710,171
Foresight Energy LP
Unaudited Consolidated Statements of Cash Flows
For the Year Ended December 31,
2014 2013 2012
(In Thousands)
Cash flows from operating activities
Net income $ 139,047 $ 10,517 $ 125,671
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization 167,039 161,216 124,552
Amortization of debt issuance costs and debt premium/discount 7,022 7,574 8,235
Equity-based compensation 4,749 4,632
Unrealized gain on coal derivatives (57,126 ) (2,453 ) (534 )
Impairment of prepaid royalties 34,700
Non-cash loss on early extinguishment of debt 4,681 5,625
Other (5,248 ) 3,417 5,934
Changes in operating assets and liabilities:
Accounts receivable (21,776 ) 9,533 (36,463 )
Due from/to affiliates, net 6,117 (1,190 ) (7,593 )
Inventories (13,893 ) 12,095 (19,397 )
Prepaid expenses and other current assets (7,799 ) (6,323 ) 3,808
Prepaid royalties (23,475 ) (17,064 ) (29,646 )
Coal derivative assets and liabilities (1,891 ) (499 )
Accounts payable 9,628 1,449 2,057
Accrued interest (2,509 ) (2,695 ) 12,149
Accrued expenses and other current liabilities 1,166 4,847 17,233
Deferred revenue (3,907 )
Other (4,392 ) (2,616 ) (947 )
Net cash provided by operating activities 236,040 179,526 209,691
Cash flows from investing activities
Investment in property, plant, equipment and development (229,251 ) (210,726 ) (209,937 )
Acquisition of an affiliate (3,822 )
Proceeds from sale of equipment 1,619 465 2,898
Settlement of certain coal derivatives 7,345 986
Net cash used in investing activities (224,109 ) (209,275 ) (207,039 )
Cash flows from financing activities
Net increase (decrease) in borrowings under revolving credit facility 60,500 23,000 (88,000 )
Proceeds from other long-term debt 85,620 1,072,772 264,007
Payments on other long-term debt and capital lease obligations (307,607 ) (634,863 ) (19,663 )
Payments on short-term debt (6,627 )
Proceeds from sale-leaseback financing arrangement 49,950
Distributions paid (169,723 ) (411,891 ) (219,405 )
Proceeds from issuance of common units (net of underwriters’ discount) 329,875
Initial public offering costs paid (other than underwriters’ discount) (7,206 ) (144 ) (3,079 )
Debt issuance costs paid (297 ) (23,729 ) (3,708 )
Other (971 )
Net cash (used in) provided by financing activities (9,809 ) 25,145 (26,525 )
Net increase (decrease) in cash and cash equivalents 2,122 (4,604 ) (23,873 )
Cash and cash equivalents, beginning of period 23,284 27,888 51,761
Cash and cash equivalents, end of period $ 25,406 $ 23,284 $ 27,888
Reconciliation of GAAP Net Income Attributable to Controlling Interests to Adjusted EBITDA and DCF:
Three Months Ended Year Ended

Three Months
Ended

December 31,

2014

December 31,

2013

December 31,

2014

December 31,

2013

September 30,

2014

(In Thousands)
Net income attributable to controlling interests $ 29,056 $ 23,737 $ 135,200 $ 8,281 $ 45,366
Interest expense, net 24,874 30,371 113,030 115,897 28,202
Depreciation, depletion and amortization 45,137 46,150 167,039 161,216 45,953
Accretion on asset retirement obligations 405 382 1,621 1,527 405
Impairment of prepaid royalties 34,700 34,700
Equity-based compensation 1,767 5,024 1,077
Unrealized gain on coal derivatives (23,415 ) (1,025 ) (57,126 ) (2,453 ) (16,001 )
Loss on early extinguishment of debt 18 4,979 77,773
Adjusted EBITDA 112,524 $ 99,633 $ 404,467 $ 362,241 105,002
Less: estimated maintenance capital expenditures(1) 19,300 19,300
Less: cash interest expense, net(2) 23,239 26,547
Distributable cash flow $ 69,985 $ 59,155
(1) – Amount represents the average estimated quarterly maintenance capital expenditures required to maintain our assets over the long-term.
(2) – Cash interest expense is calculated as GAAP interest expense for the period excluding the amortization expense recorded during the period for deferred debt issuance costs and debt discounts.
Operating Metrics
Three Months Ended Year Ended

Three Months
Ended

December 31,

2014

December 31,

2013

December 31,

2014

December 31,

2013

September 30,

2014

(In Thousands, Except Per Ton Data)
Produced tons sold 5,775 5,173 21,634 18,548 5,744
Purchased tons sold 115 410 41 277
Total tons sold 5,890 5,173 22,044 18,589 6,021
Tons produced 5,691 4,171 22,547 17,991 6,218
Coal sales realization per ton sold (1) $ 50.94 $ 51.81 $ 50.33 $ 51.50 $ 49.82
Cash cost per ton sold (2) $ 21.96 $ 20.30 $ 20.80 $ 19.46 $ 21.51
(1) – Coal sales realization per ton is defined as coal sales divided by total tons sold.
(2) – Cash cost per ton sold is defined as cost of coal produced (excluding depreciation, depletion and amortization) divided by produced tons sold.

Share on StockTwits