Foresight Energy LP Announces Third Quarter 2015 Results

Second paragraph, second sentence under Consolidated Financial Results of release dated Oct. 29, 2015 should read: The increase of $4.7 million from the third quarter of 2014 was driven by a $1.43 per ton increase in the cash cost per ton sold offset by a 2.7% decrease in sales volumes (instead of the increase of $4.7 million from the third quarter of 2014 was driven by a $2.38 per ton increase in the cash cost per ton sold offset by a 7.0% decrease in sales volumes).  

The corrected release reads:

Foresight Energy LP Announces Third Quarter 2015 Results

Third Quarter 2015 Highlights:

• Production of 4.9 million tons

• Sales volumes of 5.7 million tons resulting in total revenues of $253.1 million and Adjusted EBITDA of $91.1 million

• Disciplined capital spending resulting in $14.4 million spent during the quarter

• Increased 2016 committed position to 19.5 million tons
• Announced quarterly cash distribution of $0.17 per common unit

Foresight Energy LP (NYSE: FELP) today reported sales volumes of 5.7 million tons, total revenues of $253.1 million and Adjusted EBITDA of $91.1 million for the three months ended September 30, 2015. Net income attributable to limited partner units amounted to $8.1 million, or $0.06 per unit, which includes transition and reorganization costs of $5.0 million, or $0.04 per unit, related to the transaction with Murray Energy Corporation.

“The third quarter was significant for Foresight as we realized Adjusted EBITDA of $91.1 million in this very difficult coal environment," said Robert D. Moore, Foresight’s President and Chief Executive Officer. "We continue to make progress on the integration of Foresight and Murray’s operations and are evaluating additional synergy opportunities. Further, during the quarter we were able to increase our 2016 committed position to 19.5 million tons.”

Foresight also announced that the Board of Directors of its General Partner reduced its quarterly cash distribution to $0.17 per unit for common unitholders, while suspending its distribution on all subordinated units.

The Board of Directors’ decision to reduce the distribution reflects the difficult business environment for coal including, but not limited to, oversupply in virtually all domestic and international basins, intense competition from natural gas, and soft domestic utility demand. “The decision to cut the distribution reflects the Board’s disciplined long-term approach to creating value for unitholders and will allow Foresight to prudently manage its liquidity during this uncertain period,” said Christoper Cline, Founder and Chairman of the Board of Directors. “As the low-cost provider and most productive underground coal mining company, we believe Foresight is better positioned to navigate this difficult period in the coal markets.”

The distribution is payable on November 25, 2015 for common unitholders of record on November 13, 2015. According to the Partnership Agreement, the distribution to the common unitholders below the minimum quarterly distribution will result in an arrearage of $0.1675 per unit. Such arrearage will carry forward to future quarters and must be paid to common unitholders before Foresight can make any distributions from operating surplus to the subordinated unitholder. The subordinated units do not accrue arrearages.

Consolidated Financial Results

Three Months Ended September 30, 2015 Compared to Three Months Ended September 30, 2014

Total revenues were $253.1 million for the third quarter of 2015 compared to $300.0 million for the third quarter of 2014. Coal sales revenue decreased $48.8 million from the third quarter of 2014 due to a decline in coal sales realization per ton sold and a 5.2% decline in sales volumes. The decline in coal sales realization was due to a decrease in realization per ton on both domestic and international sales driven by weak coal market conditions as well as a lower mix of international shipments. Increased domestic shipments during the current year period partially offset the 0.7 million ton decrease in sales volumes to international markets from the year ago period. Total revenues for the third quarter of 2015 were favorably impacted by $1.9 million of other revenues related to the drop-down transactions completed with Murray Energy during the second quarter of 2015.

Cost of coal produced was $128.1 million for the third quarter of 2015 compared to $123.5 million for the third quarter of 2014. The increase of $4.7 million from the third quarter of 2014 was driven by a $1.43 per ton increase in the cash cost per ton sold offset by a 2.7% decrease in sales volumes. The increase in cash cost per ton sold during the current quarter was principally driven by the continued production outage at Hillsboro resulting from the combustion event at that operation and higher operating costs at Williamson. Partially offsetting the higher operating costs was the realization of synergies resulting from the Murray Energy transaction. While production was negatively impacted by the Hillsboro production outage, Foresight was able to satisfy all sales commitments during this period.

Transportation expense in the third quarter of 2015 declined by $20.0 million, compared to the third quarter 2014, to $34.4 million. The $3.02 per ton decline from the prior year period was the result of fewer tons sold into the international market.

Depreciation, depletion and amortization expense was $54.2 million for the third quarter of 2015 compared to $46.6 million for the third quarter of 2014. The increase of $7.6 million was primarily due to the reduction of inventory in the current year period that resulted in the recognition of depreciation, depletion and amortization that was capitalized into inventory.

Selling, general and administrative expenses were $4.8 million for the third quarter of 2015 compared to $6.4 million for the third quarter of 2014. The decrease of $1.6 million was primarily due to synergies from the Murray Energy transaction as a substantial portion of our general and administrative costs are now subject to a fixed quarterly fee of $3.5 million under the management services agreement with Murray Energy.

Transition and reorganization costs were $5.0 million for the third quarter of 2015. As part of the Murray Energy transaction, Foresight entered into a management services agreement with Murray Energy with the intent of optimizing and reorganizing certain corporate administrative functions and generating synergies between the two companies through the elimination of redundant headcount and duplicate general and administrative costs. The costs for the current period are comprised of retention compensation to certain employees during the transition period and termination benefits to employees whose positions were replaced during the current period by Murray Energy employees under the management services agreement. Included in these costs were $2.3 million of cash costs paid by Foresight Reserves, the controlling member of its general partner, which were recorded as capital contributions, $1.3 million of equity-based compensation for the accelerated vesting of certain equity awards and various other one-time charges related to the transaction.

Foresight recorded a gain on its commodity derivative contracts of $17.5 million for the third quarter of 2015 compared to a $19.0 million gain for the third quarter of 2014. The gains recorded during both periods were primarily due to a decrease in the API 2 coal index forward curve relative to prior periods. For the current quarter, Foresight realized a net gain of $10.9 million on commodity derivative contracts, as compared to a realized net gain of $3.0 million in the prior year period.

Adjusted EBITDA was $91.1 million for the third quarter of 2015 compared to $106.0 million for the third quarter of 2014. The decrease from the prior year quarter was due to lower coal sales volumes, lower realized prices and higher cash costs during the current year period partially offset by realized gains on commodity derivative contracts and lower selling, general and administrative costs driven by synergies with Murray Energy.

Liquidity and Financing

As of September 30, 2015, Foresight had $191.0 million of liquidity, comprised of $25.0 million in cash and $166.0 million of availability under its revolving credit facility. Using cash savings from the announced reduction in distributions, Foresight expects to improve liquidity and enhance its leverage.

Outlook

Foresight has updated its full-year earnings outlook to reflect results to date and to take into account year-to-date performance and the continued decline in the coal markets. Foresight’s focus continues to be on delivering value to investors by reducing overhead costs and identifying ways to streamline operations, further improving its cost structure. Considering the items mentioned above, Foresight is adjusting the previously issued fiscal year 2015 guidance for its operating and investment activities.

“In reaction to the current market conditions and taking into account the impact of synergies resulting from the transaction with Murray Energy, we are updating our guidance for 2015,” said Mr. Moore.

Sales Volumes – Guidance for sales volumes is reduced to 21.5 to 22.0 million tons from the previous range, which was between 22.5 and 23.2 million tons.

Adjusted EBITDA – As a result of a slight decrease in expected sales volumes, Foresight is tightening its Adjusted EBITDA guidance to a range of $375 to $385 million from the previous range of $385 to $400 million.

Capital Expenditures – Given the reduction in spending versus budget year-to-date, Foresight is reducing its capital expenditures guidance to be $90 to $100 million, including maintenance capital estimates of $70 to $75 million. The previous range was $105 to $110 million for total capital and $70 to $80 million for maintenance capital.

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, 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 the Partnership becomes aware of, after the date hereof.

Non-GAAP Financial Measures

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

• 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;
• the ability of the Partnership’s assets to generate sufficient cash flow to make distributions to its unitholders;
• the Partnership’s ability to incur and service debt and fund capital expenditures; and
• 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 (loss) 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, plus returns on our direct financing lease and contractual override arrangements.

We believe that the presentation of Adjusted EBITDA and DCF provides useful information to investors in assessing the Partnership’s financial condition and results of operations. Adjusted EBITDA and DCF should not be considered alternatives to net income, operating income, or any other measure of financial performance 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 the Partnership’s partnership agreement. Adjusted EBITDA and DCF have important limitations as analytical tools because they exclude some but not all items that affect net income. Additionally, because Adjusted EBITDA and DCF may be defined differently by other companies in the industry, and 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-U.S. GAAP measures to their most directly comparable U.S. GAAP financial measure, please see the table below.

This press release references forward-looking estimates of Adjusted EBITDA projected to be generated by the Partnership during 2015. A reconciliation of estimated 2015 Adjusted EBITDA to U.S. GAAP net income is not provided because U.S. GAAP net income for the projection period is not assessable. The Partnership’s net income is affected by unrealized gains and losses on commodity derivative contracts, which are not assessable at this time because they will be a function of prevailing market prices for coal in the future. The amount of such gains and losses could be significant, such that the amount of additional net income would vary substantially from the amount of projected Adjusted EBITDA.

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, and the Sitran river terminal on the Ohio River. 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 Condensed Consolidated Statements of Operations
		Three Months Ended								Nine Months Ended
		September 30,								September 30,
		2015				2014				2015				2014
		(In Thousands, Except per Unit Data)
Revenues
Coal sales		$	251,125			$	299,964			$	739,940			$	809,364
Other revenues			1,941				—				3,263				—
Total revenues			253,066				299,964				743,203				809,364
Costs and expenses:
Cost of coal produced (excluding depreciation, depletion and amortization)			128,195				123,535				360,769				323,064
Cost of coal purchased			5,055				11,940				7,063				12,672
Transportation			34,377				54,454				127,757				161,188
Depreciation, depletion and amortization			54,152				46,638				145,701				123,944
Accretion on asset retirement obligations			567				405				1,700				1,215
Selling, general and administrative			4,761				6,401				25,285				26,634
Transition and reorganization costs			5,037				—				17,288				—
Gain on commodity derivative contracts			(17,541	)			(18,990	)			(40,703	)			(41,419	)
Other operating loss (income), net			384				859				(13,872	)			(1,460	)
Operating income			38,079				74,722				112,215				203,526
Other expenses:
Loss on early extinguishment of debt			—				—				—				4,979
Interest expense, net			29,891				28,202				86,591				88,156
Net income			8,188				46,520				25,624				110,391
Less: net income attributable to noncontrolling interests			118				804				652				2,819
Net income attributable to controlling interests			8,070				45,716				24,972				107,572
Less: net income attributable to predecessor equity			—				350				23				66,436
Net income attributable to limited partner units		$	8,070			$	45,366			$	24,949			$	41,136
Net income subsequent to initial public offering available to limited partner units - basic and diluted:
Common units		$	4,041			$	22,691			$	12,486			$	20,619
Subordinated units		$	4,029			$	22,675			$	12,463			$	20,517
Net income subsequent to initial public offering per limited partner unit - basic and diluted:
Common units		$	0.06			$	0.35			$	0.19			$	0.32
Subordinated units		$	0.06			$	0.35			$	0.19			$	0.32
Weighted average limited partner units outstanding - basic and diluted:
Common units			65,156				64,786				65,067				64,786
Subordinated units			64,955				64,739				64,927				64,739

Foresight Energy LP
Unaudited Condensed Consolidated Balance Sheets
		September 30,				December 31,
		2015				2014
		(In Thousands)
Assets
Current assets:
Cash and cash equivalents		$	24,993			$	26,509
Accounts receivable			58,235				80,911
Due from affiliates			18,596				532
Financing receivables - affiliate			2,638				-
Inventories			89,104				92,075
Prepaid expenses			6,354				2,157
Prepaid royalties			3,957				8,380
Deferred longwall costs			26,012				23,224
Coal derivative assets			29,581				36,080
Other current assets			262				6,302
Total current assets			259,732				276,170
Property, plant, equipment and development, net			1,454,518				1,522,488
Due from affiliates			2,691				—
Financing receivables - affiliate			70,831				—
Prepaid royalties			66,210				59,967
Coal derivative assets			24,026				24,957
Other assets			29,415				32,070
Total assets		$	1,907,423			$	1,915,652
Liabilities and partners’ capital
Current liabilities:
Current portion of long-term debt and capital lease obligations		$	94,567			$	44,143
Accrued interest			10,685				25,136
Accounts payable			38,581				60,206
Accrued expenses and other current liabilities			35,427				37,820
Due to affiliates			6,481				15,107
Total current liabilities			185,741				182,412
Long-term debt and capital lease obligations			1,401,080				1,316,528
Sale-leaseback financing arrangements – affiliate			193,434				193,434
Asset retirement obligations			31,878				31,373
Other long-term liabilities			6,131				5,508
Total liabilities			1,818,264				1,729,255
Limited partners' capital (deficit):
Common unitholders (65,191 and 64,831 units outstanding as of September 30, 2015 and December 31, 2014, respectively)			221,446				238,925
Subordinated unitholders (64,955 and 64,739 units outstanding as of September 30, 2015 and December 31, 2014, respectively)			(130,569	)			(111,169	)
Total limited partners' capital			90,877				127,756
Predecessor equity			—				50,710
Noncontrolling interests			(1,718	)			7,931
Total partners' capital			89,159				186,397
Total liabilities and partners' capital		$	1,907,423			$	1,915,652

Foresight Energy LP
Unaudited Condensed Consolidated Statements of Cash Flows
		Nine Months Ended
		September 30,
		2015				2014
		(In Thousands)
Cash flows from operating activities
Net income		$	25,624			$	110,391
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization			145,701				123,944
Equity-based compensation			12,897				3,257
Unrealized losses (gains) on commodity derivative contracts and cumulative prior unrealized gains realized during the period			10,853				(33,711	)
Realized gains on commodity derivative contracts included in investing activities			(19,073	)			—
Transition and reorganization expenses paid by Foresight Reserves LP (affiliate)			8,031				—
Noncash loss on early extinguishment of debt			—				4,681
Other			6,822				7,546
Changes in operating assets and liabilities:
Accounts receivable			22,676				(33,655	)
Due from/to affiliates, net			(25,406	)			6,013
Inventories			(3,806	)			(18,929	)
Prepaid expenses and other current assets			2,265				(10,485	)
Prepaid royalties			(1,820	)			(3,443	)
Commodity derivative contract assets and liabilities, net			(2,447	)			(1,439	)
Accounts payable			(21,625	)			19,634
Accrued interest			(14,451	)			(10,667	)
Accrued expenses and other current liabilities			(4,085	)			5,164
Other			(2,390	)			(650	)
Net cash provided by operating activities			139,766				167,651
Cash flows from investing activities
Investment in property, plant, equipment and development			(69,502	)			(173,946	)
Investment in financing arrangements with Murray Energy (affiliate)			(75,000	)			—
Settlement of certain commodity derivative contracts			19,073				—
Return of investment on financing arrangements with Murray Energy (affiliate)			1,112				—
Acquisition of an affiliate			—				(3,822	)
Proceeds from sale of equipment			—				1,619
Net cash used in investing activities			(124,317	)			(176,149	)
Cash flows from financing activities
Net increase in borrowings under revolving credit facility			58,000				83,500
Net increase in borrowings under A/R securitization program			50,000				—
Proceeds from other long-term debt			59,325				29,719
Payments on other long-term debt and capital lease obligations			(33,274	)			(297,908	)
Payments on short-term debt			(2,010	)
Distributions paid			(144,748	)			(124,267	)
Proceeds from issuance of common units (net of underwriters' discount)			—				329,875
Initial public offering costs paid (other than underwriters' discount)			—				(6,976	)
Debt issuance costs paid			(2,751	)			(297	)
Other			(1,507	)			(551	)
Net cash (used in) provided by financing activities			(16,965	)			13,095
Net (decrease) increase in cash and cash equivalents			(1,516	)			4,597
Cash and cash equivalents, beginning of period			26,509				24,787
Cash and cash equivalents, end of period		$	24,993			$	29,384
Supplemental information and disclosures of non-cash financing activities:
Interest paid, net of amounts capitalized		$	96,050			$	93,437
Non-cash distribution		$	—			$	12,187
Non-cash capital contribution from Foresight Reserves LP (affiliate)		$	10,507			$	—
Short-term insurance financing		$	2,809			$	—

Reconciliation of U.S. GAAP Net Income (Loss) Attributable to Controlling Interests to Adjusted EBITDA and DCF:
		Three Months Ended												Nine Months Ended
		September 30,				September 30,								September 30,				September 30,
		2015				2014				June 30, 2015				2015				2014
		(In Thousands)
Net income (loss) attributable to controlling interests		$	8,070			$	45,716			$	(25,403	)		$	24,972			$	107,572
Interest expense, net			29,891				28,202				29,359				86,591				88,156
Depreciation, depletion and amortization			54,152				46,638				52,731				145,701				123,944
Accretion on asset retirement obligations			567				405				567				1,700				1,215
Transition and reorganization costs(1)			3,784				—				12,251				13,388				—
Loss on early extinguishment of debt			—				—				—				—				4,979
Equity-based compensation(1)			1,258				1,077				759				12,897				3,257
Unrealized (gain) loss on commodity derivative contracts and prior cumulative unrealized gains realized during the period			(6,616	)			(16,001	)			33,252				10,853				(33,711	)
Adjusted EBITDA			91,106				106,037				103,516				296,102			$	295,412
Less: estimated maintenance capital expenditures(2)			(17,000	)			(19,300	)			(18,000	)			(54,300	)
Less: cash interest expense, net(3)			(28,154	)			(28,760	)			(27,731	)			(81,598	)
Add: return of investment on financing arrangements(4)			628				—				903				1,531
Distributable cash flow		$	46,580			$	57,977			$	58,688			$	161,735
(1) - Equity-based compensation of $1,253 and $3,900 was recorded in transition and reorganization costs for the three and nine months ended September 30, 2015, respectively, and $2,647 for the three months ended June 30, 2015.
(2) - Amount represents the average estimated quarterly maintenance capital expenditures required to maintain our assets over the long-term.
(3) - Cash interest expense is calculated as U.S. GAAP interest expense for the period excluding the amortization expense recorded during the period for deferred debt issuance costs and debt discounts.
(4) - Return of investment on financing arrangements represents the scheduled principal repayments under the overriding royalty financing arrangement and direct financing lease with Murray Energy.

Operating Metrics
		Three Months Ended												Nine Months Ended
		September 30,				September 30,								September 30,				September 30,
		2015				2014				June 30, 2015				2015				2014
		(In Thousands, Except Per Ton Data)
Produced tons sold			5,588				5,744				5,589				16,278				15,859
Purchased tons sold			120				13				42				162				294
Total tons sold			5,708				6,021				5,631				16,440				16,153
Tons produced			4,884				6,218				4,700				16,193				16,856
Coal sales realization per ton sold(1)		$	44.00			$	49.82			$	44.38			$	45.01			$	50.11
Cash cost per ton sold(2)		$	22.94			$	21.51			$	21.83			$	22.16			$	20.37
Netback to mine realization per ton sold(3)		$	37.97			$	40.78			$	36.21			$	37.24			$	40.13
(1) - Coal sales realization per ton sold 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.
(3) - Netback to mine realization per ton sold is defined as coal sales less transportation expense divided by tons sold.

View source version on businesswire.com: http://www.businesswire.com/news/home/20151029005458/en/

Source: Business Wire (October 29, 2015 - 6:35 AM EDT)

News by QuoteMedia
www.quotemedia.com